HomeMy WebLinkAbout1.1 Application- Part TwoPROJECT FACILITIES
PIPELINE VALVE SETS, METERS, ETC.
EAST LATERAL PIPELINE & BAILEY COMPRESSOR STATION
The proposed twenty (20") inch and eight (8") inch East Lateral Pipelines will have
above ground valve sets associated to the pipelines, besides the proposed Bailey
Compressor Station. Associated valve sets for the 20" pipeline will include a Pig
Launcher and Receiver, and a valve set tie-in located in the center of the pipeline
where one of BBC's existing pipelines will tie-in to the 20". Additional tie-in points
may be required in the future to gather gas from new areas along the route but at
this time the location for those tie-ins are unknown.
All above ground valve sets will be located in areas agreed to by the affected
landowners and Bill Barrett Corporation. Valve sets will be protected by either
man made pipe guards or fenced to protect from contact by wildlife, livestock or
unauthorized persons. Valve sets will be installed to meet all API and DOT
specifications and codes. No valves will be located close to any existing structures or
facilities besides the Bailey Compressor Station.
Bill Barrett Corporation
SPILL PREVENTION, CONTROL, & COUNTERMEASURE PLAN
(SPCC PLAN)
(40 CFR, Part 112)
EAST MAMM CREEK FIELD, PICEANCE BASIN
GARFIELD COUNTY, COLORADO
ONSHORE PRODUCTION FACILITY
DATE OF PLAN: JANUARY 2007
PREVIOUS PLAN DATE(S): NOVEMBER 2004
Bill Barrett Corporation
SPILL PREVENTION, CONTROL, & COUNTERMEASURE PLAN
(SPCC PLAN)
(40 CFR, Part 112)
EAST MAMM CREEK FIELD, PICEANCE BASIN
GARFIELD COUNTY, COLORADO
ONSHORE PRODUCTION FACILITY.
DATE OF PLAN: JANUARY 2007
PREVIOUS PLAN DATE(S): NOVEMBER 2004
TABLE OF CONTENTS
REGULATORY CROSS-REFERENCE 1
1.0 SPCC PLAN GENERAL REQUIREMENTS 2
1.1. Management Approval (112.7) 2
1.2. Certification (112.3 d) 2
1.3. Record of Reviews / Amendments (112.5) 3
2.0 FACILITY DESCRIPTION, FACILITY CONFORMANCE, SPILL PREDICTION AND
CONTAINMENT 4
2.1 Facility Type and Location (112.7 a) 4
2.2 Facility Owner and Operator (112.7 a) 4
2.3 Designated Person Accountable for Oil Spill Prevention at Facility (112.7 1) 4
2.4 Description of Facility Operations (112.7 a, b) 4
2.5 Plan Implementation (112.7) 5
2.6 Facility Conformance 5
2.7 Spill Predictions, Volumes, Rates, and Control [112.7(b)] 6
2.8 Containment and/or Diversionary Structures 1112.7(c)1 8
3.0 INSPECTIONS PROCEDURES (112.7 E) 8
4.0 DISCHARGE PREVENTION AND RESPONSE TRAINING PROGRAM 8
4.1 Training Requirements 8
4.2 Spill Prevention Briefings 9
4.3 Additional Instruction 9
4.4 Instruction Procedures - 9
5.0 WRITTEN INSTRUCTION FOR CONTRACTORS. 9
5.1 Oil Drilling and Workover SPCC Plan 9
5.2 SPCC Plan Instructions for Contractors 10
6.0 OIL PRODUCTION FACILITY DRAINAGE [112.9(B)]• 10
6.1 Drainage of Rainwater from Facility 10
7.0 BULK STORAGE CONTAINERS/SECONDARY CONTAINMENT [112.9(C)] 11
7.1 Tank compatibility with its contents 11
7.2 Secondary containment 11
7.3 Container Inspection 12
7.4 Tank Battery Engineering 12
8.0 TRUCK LOADING/UNLOADING (112.7(A)(3)(II)] AND FACILITY TRANSFER
OPERATIONS, OIL PRODUCTION FACILITY [112.9(D)] 12
8.1 Truck Loading/Unloading 12
8.2 Inspection 13
8.3 Saltwater Disposal Facility Inspection 13
8.4 Flowline Maintenance 13
9.0 REPAIR, ALTERATION, RECONSTRUCTION OR CHANGE IN SERVICE
[112.7(1)] 14
10.0 REGULATORY CONFORMANCE AND EXCLUSIONS [112.7(J)] 14
10.1 Regulatory Conformance 14
10.2 Regulatory Exclusions 14
APPENDICES
APPENDIX A
APPENDIX B
MANPOWER,
APPENDIX C
APPENDIX D
APPENDIX E
APPENDIX F
APPENDIX G
- INDIVIDUAL SITE INFORMATION
- OIL SPILL CONTINGENCY PLAN AND WRITTEN COMMITMENT OF
EQUIPMENT, AND MATERIALS
- CONTACT INFORMATION AND SPILL REPORTING PROCEDURE
- SPILL REPORT FORM AND INSPECTION FORM
- TRAINING RECORD
- STORMWATER INSPECTION PROCEDURE AND DRAINAGE RECORD
- CERTIFICATION OF APPLICABILITY OF SUBSTANTIAL HARM CRITERIA
REGULATORY CROSS-REFERENCE
Regulatory
Citation
Description of Regulatory Requirement
Section
Number
§112.3 (d)(3)
Professional Engineer Certification
1.2
§1 12.5 (a),(c)
Plan Amendments and Certification .
1.3
§112.5(b)
Plan Review
1.3
§112.7
General Requirements - Management Approval
1.1
§112.7
General Requirements - Sequence or Cross -Reference
Cross -Reference
§112.7
General Requirements - Discussion of Facilities Not Yet Fully Operational
2.5, Appendix A
§112.7(a)(2)
Deviation from Requirements: Reasons, Methods, and Equivalent Protection
2.6, Appendix A
§ 112.7(a)(3)
Physical Layout and Facility Diagram
2.4, Appendix A
§112.7(a)(3)(i)
Container Capacity and Type of Oil
Appendix A
§ 112.7(a)(3)(ii)
Discharge Prevention Measures
2.7, 8.0, App. B
§112.7(a)(3)00
Discharge or Drainage Controls
2.7
§ 1 12.7(a)(3)(iv)
Countermeasures: Discover, Response, and Cleanup
Appendix B
§112.7(a)(3)(v)
Disposal: Legal Requirements
Appendix B
§I 12.7(a)(3)(vi)
Notification Phone Lists
Appendix C
§I 12.7(a)(4)
Discharge Notification Fonn
Appendix D
§112.7(a)(5)
Discharge Procedures Organized
Appendix B
§112.7(b)
Fault Analysis
2.7, Appendix B
§112.7(c)
Adequate Secondary Containment
Appendix A
§112.7(d)(1)
Contingency Planning
Appendix B
§112.7(d)(2)
Commitment of Resources
Appendix B
§112.7(e)
Inspections, Tests; and Records - Written Procedures
3.0
§112.7(e)
Inspections, Tests, and Records - Records of Inspections & Tests; Signatures
3.0
§112.7(e)
Inspections, Tests, and Records - Records Maintenance
3.0
§112.7(f)(1)
Personnel Training
4.0, Appendix E
§112.7(0(2)
Designated Person Accountable for Spill Prevention
2.3
§112.7(0(3)
SpiIl Prevention Briefings
4.0
§112.7(g)(1)
Security
NA
§l12.7(g)(2)
Flow and Drain Valves Secured
NA
§112.7(g)(3)
Pump Controls Locked Off; Facility Access Secured
NA
§112.7(g)(4)
Loading/Unloading Connections Sealed
NA
§ 112.7(g)(5)
Lighting Appropriate for Facility
NA
§1 12.7(h)
Tank Truck Loading/Unloading Rack
NA, 10.2
§112.7(i)
Brittle Fracture Evaluation
9.0
§ 112.7(j)
Conformance with State Requirements
10.1
§112.8(b)
Non -production facility drainage
NA, 10.2
§ 112.8(c)
Non -production facility bulk storage containers
NA, 10.2
§112.8(d)
Non -production facility transfer operations, pumping and facility process
NA, 10.2
§112.9(b)
Oil production facility drainage
6.0, Appendix F
§ 112.9(c)
Oil production facility bulk storage containers
7.0
§112.9(d)
Facility transfer operations, oil production facility
8.0
§112.10(b)
Mobile facilities
NA, 10.2
§112.10(c)
Secondary containment - catchment basins or diversion structures
NA, 10.2
§112.10(d)
Blowout prevention (BOP)
NA, 10.2
§112.11
Plan Requirements for offshore oil drilling, production, or workover Facilities
NA, 10.2
§112.12
SPCC plan requirements for onshore facilities (excluding production) (Animal
fats)
NA, 10.2
§112.13
SPCC plan requirements for onshore oil production facilities (Animal fats)
NA, 10,2
§112.14
SPCC plan requirements for onshore oil drilling facilities (Animal fats)
NA, 10.2
§112.15
SPCC plan requirements for offshore oil drilling facilities (Animal fats)
NA, 10.2
§ 112.20
Facility Response Plans / Certification of Applicability of Substantial Harm
Criteria
NA, 10.2,
Appendix G
SPCC Plan
Page 1
1.0 SPCC PLAN GENERAL REQUIREMENTS
1.1. Management Approval (112.7)
112.7 The Plan must have the full approval of management at a level of authority to
commit the necessary resources to fully implement the plan.
This SPCC Plan will be implemented as herein descpfled.
Signature
777A(?/({9141A/
Name
CI-SENNNfff
Title
ASSET LEADER
Date -
///z/ZOO `
1.2. Certification (112.3 d)
112.3(d) A licensed Professional Engineer must review and certify a Plan for it to be
effective to satisfy the requirements.
CERTIFICATION
I hereby certify that: i) I am familiar with the requirements of the SPCC Rule (40 CFR part 112), ii) I or my
agent has visited the facility, iii) this SPCC Plan has been prepared in accordance with good engineering
practice including consideration of applicable industry standards, and with the requirements of the SPCC
Rule, iv) procedures for the required inspections and testing have been established, and v) this SPCC
Plan is adequate for the facility.
(?rintet
Of
9is('e
Pro
TQ n Ter?
s'nal Engineer
Sign
�7
dfFe serec()'
Registration. No.:
fe;:Sional Engineer
3 3353
State:
SPCC Plan Page 2
Date:
Ccs
(Seal)
1.3. Record of Reviews / Amendments (112.5)
I have completed a review/evaluation of the SPCC Plan for this facility and will/will not (see below) amend
the Plan as a result. Technical amendments will be certified and signed by a Professional Engineer.
REVIEW
DATE AREA AMENDMENT IF APPLICABLE REVIEWER SIGN
Note: A complete copy of this plan will be maintained at the facility if it is normally attended at least four
hours per day or at the nearest field office if the facility is not so attended.112.3(e)(1). This Plan has been
prepared in accordance with Best Management Practices and may or may not be required under the
Guidance provided in 40 CFR 112. The date of this Plan represents the date this Plan was reviewed
using this format and does not imply that a previous SPCC Plan did not exist for the facilities addressed in
this Plan.
Date(s) of Previous Plan(s): August 2004
..,...... *****k.,**********************************************************************************
Distribute this form as follows:
One (1) copy - Field Copy of Company SPCC Plan
One (1) copy - Facility Operator - Denver
SPCC Plan Page 3
2.0 FACILITY DESCRIPTION, FACILITY CONFORMANCE, SPILL PREDICTION
AND CONTAINMENT
2.1 Facility Type and Location (112.7 a)
Facility: EAST MAMM CREEK FIELD
Type Facility: Onshore Oil/Gas Production Facility
State Identification: See site specific info
Reference Landmark: The field is located approximately 4 miles SOUTH OF SILT,
COLORADO in GARFIELD COUNTY, COLORADO.
County/Parish: GARFIELD State: COLORADO
2.2 Facility Owner and Operator (112.7 a)
Name and address of owner:
Name: BILL BARRETT CORP. (BBC)
Address: 1099 18TH STREET, SUITE 2300
DENVER, CO 80202
Telephone: 303-293-9100 FAX: 303-291-0420
Name and address of operator:
Name: BILL BARRETT CORP. (BBC)
Address: 1099 18TH STREET, SUITE 2300
DENVER, CO 80202
Telephone: 303-293-9100 FAX: 303-291-0420
2.3 Designated Person Accountable for Oil Spill Prevention at Facility (112.7 f)
Mr. MONTY SHED is the person accountable for discharge prevention and response at the facility(ies)
covered by this Plan and reports to the facility management.
2.4 Description of Facility Operations (112.7 a, b)
The EAST MAMM CREEK FIELD operated by BBC produces natural gas, oil or condensate and water
from well(s) located in the area. Production equipment separates the fluids and the fluids are stored in
tank(s) until removal for sale or disposal. Oil and water are removed by truck load -out or by pipeline.
Fluids are moved within the facility by pipeline.
SPCC Plan Page 4
This production facility(ies) receives, processes, and stores production 24 hours a day, 365.25 days a
year. The facility is not manned but an operator inspects the facility daily to weekly.
The area surrounding the field is grass and rangeland. There are residences in the field.
Individual tanks and production equipment at the facility are described in Appendix A. Drainage pathways
and distances to navigable waters are also described in Appendix A.
The following information, as appropriate, is included in the site diagrams and descriptions in Appendix A:
1. Containers (including aboveground storage tanks [ASTs], drums, separation and other
equipment) and their contents
2. Tanker truck loading and unloading areas
3. Buried or bunkered tanks
4. Drum and portable container storage areas
5. Piping
2.5 Plan Implementation (112.7)
Any additional facilities, procedures, methods, or equipment not yet fully operational shall be discussed
with the details of installation and start-up (40 CFR 112.7).
The sites are discussed individually in Appendix A. Any items not yet fully operational will be completed as
soon as practical, but no later than six months following the date of this plan. New individual sites shall
have spill prevention and control measures in place at the time production for the site begins.
2.6 Facility Conformance
The subject facilities are in conformance with 40 CFR 112 as amended on July 17, 2002, with the
following exceptions noted below. The reason for any nonconformance, including impracticable
containment or diversion measures, and the provided equivalent environmental protection measures are
also noted.
Conformance
Deviation
Reason for
Nonconformance
Equivalent Environmental Protection
Measures
Truck loading and unloading
Secondary containment for
All loading and unloading operations are
areas are not provided with a
loading and unloading areas
attended by the driver and conducted in
means of secondary
is not practicable.
accordance with DOT regulations. In
containment means of
Containment structures
addition, the operator has implemented an
secondary containment as
would interfere with normal
oil spill contingency plan and has provided
specified by 1 12.7(c).
operations and the collection
a written commitment of manpower
of stormwater would create
unsafe conditions.
(Appendix B).
SPCC Plan
Page 5
Separation equipment is not
Secondary containment for
The volume of oil stored in separation
provided with a means of
separation equipment is not
equipment is typically insufficient to reach
secondary containment as
practicable for the following
waters of the U.S. even in the event that
specified by 112.9(e)(2).
reasons:
the total capacity of the unit is released.
1) Dikes and trenches would
Any spills or accidental releases of oil from
interfere with site access for
separation equipment located outside of
normal operations.
diked areas are promptly cleaned up by the
2) Dikes and trenches can
operator. In addition, the operator has
trap explosive and toxic
implemented an oil spill contingency plan
gases creating a safety
and has provided a written commitment of
hazard.
manpower (Appendix B).
Drainage from undiked areas
Secondary containment for
Any spills or accidental releases of oil from
is not confined in a
undiked areas is not
flowlines, wellheads, or other equipment
catchment basin or holding
practicable. The collection
located outside of diked areas are promptly
pond as specified by
of stormwater would create
cleaned up by the operator. In addition,
112.9(c)(2).
unsafe conditions.
the operator has implemented an oil spill
contingency plan and has provided a
written commitment of manpower
(Appendix B).
2.7 Spill Predictions, Volumes, Rates, and Control [112.7(b)]
Failure modes, rates of flow, discharge quantities, and prevention measures for storage tanks, truck
loading/unloading, process units, and piping are presented below.
Expected maximum flow rates, flow directions, and maximum quantities for individual sites are listed in
Appendix A.
Bulk Storage Tank Leak or Failure
Failure Modes: Corrosion, vandalism, lightning strikes, valve or piping failure, overfilling.
II. Rate of Flow: Variable, depending upon the type, size and location of the tank failure. The
ambient temperature at the time of the release may affect the viscosity of the oil and thereby impact the
rate of flow. Flow rates for corrosion failure are typically low, ranging from less than a gallon per day to a
gallon per hour. Flows resulting from valve and piping failures or vandalism typically range from a gallon
per hour up to the tank contents per hour. Lightning strikes may result in a release that is essentially
instantaneous.
III. Discharge Quantity: Variable depending upon the type and location of the failure. The total
quantity discharged would not exceed the working capacity of the largest tank.
IV. Preventative Measures: Storage tanks are constructed in accordance with API industry
standards. Materials used in constructing the tanks are compatible with the substances stored. Where
practicable, earthen berms or other diversionary structures are utilized to control any released fluids.
Compacted natural clay/loam bases and berms with gravel armor or concrete are utilized for containment
in the event of a release from and of this type equipment. The containment areas are constructed to
contain a minimum of 100% of the single largest container within the containment structure plus freeboard
for precipitation. Tanks are appropriately sized to minimize the risk of overfilling.
Tanker Truck Loading and Unloading Operations
SPCC Plan Page 6
Failure Modes: Piping or valve failure, tank failure, overflow, and human error.
II. Rate of Flow: Variable depending upon the type, size and exact location of the failure, and the
amount of oil in the tanker truck and storage tank. The ambient temperature at the time of the release
may affect the viscosity of the oil and thereby impact the rate of flow. Flow rates resulting from piping and
valve failures can range from 1 gallon per hour up to the tank contents in less than one hour. The flow
rate for tank truck overflows typically will not exceed 5 to 10 bbls per minute. Tank failures may result in
releases that are essentially instantaneous.
IH. Discharge Quantity: Variable depending upon the type and location of the failure. The total
quantity discharged would not exceed the working capacity of the largest tank.
IV. Preventative Measures: Oil production is removed from the facility by truck. Tanker truck loading
and unloading operations are conducted in accordance with United States Department of Transportation
regulations (49 CFR 177). All loading operations are attended by the truck driver. No smoking or open
flames are allowed in the vicinity of the storage tanks and loading area. Following the completion of
loading operations, the transfer line is disconnected and all valves and outlets on the tanker truck and the
storage tank are visually inspected for leakage prior to vehicle departure.
Process Unit Failure (Separator/Heater Treater/Gun Barrel)
Failure Modes: Process vessels may rupture or associated lines, valves and gauges may fail or
leak. Leaks from corrosion or at valves and connections. If pressure relief valves dump to a flare or vent,
this may result in a release.
II. Rate of Flow: Variable, depending upon the mode and extent of the failure. The maximum
expected rate of flow from a process unit failure is the oil production rate of the well plus any additional
fluid volume contained in the vessel above the elevation of the rupture.
III. Discharge Quantity: Variable, depending on the type of failure and the length of time that the
failure went undetected.
VI. Preventative Measures: Process units are constructed in accordance with API and ASME industry
standards. Where practicable, earthen berms or other diversionary structures are utilized to control any
released fluids.
Piping Failure
Failure Modes: Both aboveground and buried pipelines may rupture or corrode and leak.
Associated flanges, screwed connections, valves and gauges are also subject to corrosion and may fail or
leak. Piping may be damaged from construction activities. At the wellhead, there may be leaks at the
stuffing box, valves, and connections.
II. Rate of Flow: Variable, depending on the size and location of the piping -related failure. The
maximum potential rate of flow is not expected to exceed the oil production rate.
III. Discharge Quantity: Variable depending upon the type and extent of the failure and the length of
time that the failure went undetected.
IV. Prevention Measures: Flowlines to the tank battery are steel and/or poly pipe. Flowlines are
typically buried and secondary containment is not practicable. Corrosion inhibitor is utilized to prevent
SPCC Plan Page 7
corrosion. During pipeline excavation projects pipelines are inspected for signs of excessive corrosion or
stress. Personnel routinely perform visual inspections of aboveground piping and buried flowline right-of-
ways to detect leaks and/or failures. Lines are repaired or replaced as appropriate if leaks, failures,
excessive corrosion or stress are indicated.
2.8 Containment and/or Diversionary Structures [112.7(c)]
The aboveground storage tanks have berms for secondary containment. Secondary containment for truck
loading/unloading area, separation equipment, and piping is not practicable in many instances. See
Appendix A for site-specific information. See Appendix B for the oil spill contingency plan. Contact
information for company personnel, cleanup and other contractors, and government regulatory agencies is
included in Appendix C. The central depot for spill response equipment is the Field Office. Granular
absorbent material, pads, booms, shovels, brooms, earthmoving equipment for spill containment, and
empty drums are available for dispatch from this site. Oil transport trucks, including contract oil haulers,
carry spill control kits.
3.0 INSPECTIONS PROCEDURES (112.7 e)
The pumper will informally inspect the production equipment in his area on each visit (daily to weekly).
A formal inspection of the production equipment will be conducted, documented, and signed by the
operator at least annually.
The following will be used as a guide for the informal and formal inspections. Note condition of any piece
of equipment, storage tank or drum, and other items that could lead to a spill or adversely effect the
operations or safety of the facility.
An example site inspection checklist is included in Appendix D. Annual facility inspection records are kept
on file for a minimum of three years.
A record of inspections and drainage events will be recorded in the remarks section of the Lease
Inspection Forms.
4.0 DISCHARGE PREVENTION AND RESPONSE TRAINING PROGRAM
At a minimum train your oil handling personnel in the operation and maintenance of equipment to prevent
discharges; discharge procedures protocols; applicable pollution control laws, rules, and regulations;
general facility operations; and the contents of the SPCC Plan. 112.7(1) (1)
Schedule and conduct discharge prevention briefing for your oil handling personnel at least once a year to
assure adequate understanding of the SPCC Plan for the facility. 112.7(/) (3)
4.1 Training Requirements
Personnel will be instructed in the operation and maintenance of equipment used at this facility to prevent
discharges of oil and in applicable pollution control laws, rules, and regulations. Training will be conducted
for all personnel, and training will be given to new employees on an annual basis at a minimum. A training
record form is presented in Appendix E.
SPCC Plan Page 8
4.2 Spill Prevention Briefings
Spill prevention briefings will be conducted annually to assure adequate understanding of the SPCC Plan.
These briefings will include discussions of:
1. Known spill events or failures
2. Malfunctioning components
3. Recently developed precautionary measures
4.3 Additional Instruction
Instruction will also be given in:
1. Spill prevention procedures
2. Operation and maintenance of equipment to prevent oil discharges
3. Applicable pollution control laws, rules, and regulations
4.4 Instruction Procedures
The procedures that will be employed for instruction are:
Normally briefing and training will be conducted in conjunction with area safety meetings.
5.0 WRITTEN INSTRUCTION FOR CONTRACTORS:
Written instructions discussing duties and obligations to prevent pollution, including SPCC plans, are
prepared by individual contractors as applicable for servicing a well or systems appurtenant to a well or
pressure vessels are outlined below. These instruction outlines below are only a guide for BBC personnel.
This SPCC Plan is available to all contractors at the PARACHUTE CO office.
5.1 Oil Drilling and Workover SPCC Plan
1. Blowout preventer (BOP) assembly and well control system will be installed before drilling below
any casing string. When working over a well a BOP and well control system will be used when
required.
2. BOP will be capable of controlling any expected pressures and will be tested.
3. Casing and BOP installations will conform to state regulations.
4. Drip pans and other devices will be used to prevent ground pollution.
5. Tanks and pits will be properly inspected and maintained to prevent leakage.
SPCC Plan Page 9
6. Contractor is responsible for keeping area and equipment in good order and is to be held
responsible for same.
7. In the event of a,spill of effluent substances, the contractor shall notify company personnel
immediately so that control and cleanup operations may be put into effect.
8. A company representative should be present at times when abnormal conditions are encountered
or expected to assist contractor in maintaining control of well.
5.2 SPCC Plan Instructions for Contractors
The BBC area that you will conduct your operations is in compliance with current EPA SPCC Regulations.
It shall be the contractor's responsibility to properly instruct their personnel as to their obligation to prevent
any pollution. These instructions shall be in accordance with the regulations prescribed by the EPA.
The equipment used in this operation shall be in proper working condition, size and quality to adequately
perform the operation, and equipped with drip pans and other pollution devices to prevent ground
pollution.
You will not, under any circumstances, dispose of pollutants onto the ground or into any drainage or
containment devices without prior approval of a company representative.
You shall instruct your personnel to be alert at all times to prevent damage to equipment in your work
area.
If at any time that your personnel determine that a spill may occur or has occurred, you are instructed to
notify a company representative so that he can be present for instructions and assistance.
On completion of your operation, you shall return the area to its original condition.
6.0 OIL PRODUCTION FACILITY DRAINAGE [112.9(b)]:
6.1 Drainage of Rainwater from Facility
112.9(b)(1) At tank batteries and separation and treating areas where there is a reasonable
possibility of a discharge as described in § 112.1(b), close and seal at all times drains of
dikes or drains of equivalent measures required under § 112.7(c)(1), except when draining
uncontaminated rainwater. Prior to drainage, you must inspect the diked area and take
action as provided in § 112.8(c)(3)(ii), (iii), and (iv). You must remove accumulated oil on the
rainwater and return it to storage or dispose of it in accordance with legally approved
methods.
(2) Inspect at regularly scheduled intervals field drainage systems (such as drainage ditches
or road ditches), and oil traps, sumps, or skimmers, for an accumulation of oil that may have
resulted from any small discharge. You must promptly remove any accumulations of oil.
SPCC Plan Page 10
a. Drainage from diked storage areas is controlled as follows:
112.9(b)(1)
The containment areas are inspected several times per week when operating personnel visit the site. Any
accumulation of oil resulting from a discharge is promptly removed.
No drainage from containment areas should be required. Water accumulated in the bermed areas will be
inspected to insure compliance with applicable water quality standards and will not create a harmful
discharge as defined in 40 CFR part 110.3 which includes oil that causes a film or sheen upon or
discoloration of the surface of the water. If necessary, fluids within the containment area will be recovered
and placed back into the production system or taken to an approved disposal site. Personnel must record
any drainage events, including date, hydrocarbons present, and volume drained.
A Stormwater Inspection Procedure and Drainage Record Form is presented in Appendix F.
b. Drainage from undiked areas is controlled as follows:
112.9(b) (2)
Hydrocarbon storage vessels are located within bermed areas to prevent spills into undiked areas.
Field drainage dikes and road ditches will be inspected for accumulation of oil or oil contaminated soil.
7M BULK STORAGE CONTAINERS/SECONDARY CONTAINMENT [112.9(c)]
7.1 Tank compatibility with its contents:
112.9(c)(1) Not use a container for the storage of oil unless its material and construction are
compatible with the material stored and the conditions of storage.
The ASTs onsite are constructed of welded steel in accordance with API standards. The tanks are
specifically designed to hold oil and/or water and the materials of construction are compatible with the
contents.
7.2 Secondary containment:
112.9(c)(2) Provide all tank battery, separation, and treating facility installations with a
secondary means of containment for the entire capacity of the largest single container and
sufficient freeboard to contain precipitation. You must safely confine drainage from undiked
areas in a catchment basin or holding pond.
The permanent secondary containment has been designed to hold the entire contents of the largest tank
with sufficient freeboard to allow for precipitation. The gas/liquid separator and associated piping do not
have secondary containment, but the facility is covered by an oil spill contingency plan and a commitment
of manpower, equipment, and materials.
SPCC Plan Page 11
7.3 Container Inspection
112.9(c)(3) Periodically and upon a regular schedule visually inspect each container of oil
for deterioration and maintenance needs, including the foundation and support of each
container that is on or above the surface of the ground.
Personnel view and informally inspect aboveground storage tanks several times per week as part of their
routine maintenance schedule. Aboveground storage tanks, secondary containment and associated
equipment are formally inspected on an annual basis. During these inspections, the outside of each tank
is observed for evidence of deterioration, leaks which might cause a spill, or accumulation of oil inside
diked areas. These annual facility inspections are documented. A sample facility inspection form is
presented in Appendix D.
7.4 Tank Battery Engineering
112.9(c) (4) Engineer or update new and old tank battery installations in accordance with
good engineering practice to prevent discharges. You must provide at least one of the
following:
(i) Container capacity adequate to assure that a container will not overfill if a
pumper/gauger is delayed in making regularly scheduled rounds.
(ii) Overflow equalizing lines between containers so that a full container can overflow to
an adjacent container.
(iii) Vacuum protection adequate to prevent container collapse during a pipeline run or
other transfer of oil from the container.
(iv) High level sensors to generate and transmit an alarm signal to the computer where
the facility is subject to a computer production control system.
Tank capacities are such that greater than 30 days is required for the tank capacities to be reached. Tank
capacity is monitored at least once per week, weather and road conditions permitting, as part of the facility
operating report.
8.0 TRUCK LOADING/UNLOADING [112.7(a)(3)(ii)] AND FACILITY TRANSFER
OPERATIONS, OIL PRODUCTION FACILITY [112.9(d)]
8.1 Truck Loading/Unloading
112.7(a)(3) Describe in your Plan ... (ii)Discharge prevention measures including
procedures for routine handling of products (loading, unloading, and facility transfers, etc.);
112.7(h) applies only to tank car and tank truck loading/unloading racks. Because the facility does not
have a loading/unloading rack, section 112.7(h) is not applicable. The following measures will be
implemented:
SPCC Plan Page 12
Oil production is removed from the facility by truck. Tanker truck loading and unloading operations are
conducted in accordance with United States Department of Transportation regulations (49 CFR 177). All
loading operations are attended by the truck driver. No smoking or open flames are allowed in the vicinity
of the storage tanks and loading area. Following the completion of loading operations, the transfer line is
disconnected and all valves and outlets on the tanker truck and the storage tank are visually inspected for
leakage prior to vehicle departure.
8.2 Inspection
112.9(d) (1) Periodically and upon a regular schedule inspect all aboveground valves and
piping associated with transfer operations for the general condition of flange joints, valve glands and
bodies, drip pans, pipe supports, pumping well polish rod stuffing boxes, bleeder and gauge valves,
and other such items.
Pipelines are 2 -inch diameter lines or less with a maximum length of a few hundred feet. All piping
associated with transfer operations is coated to prevent corrosion.
Personnel view and informally inspect aboveground valves and piping several times per week as part of
their routine maintenance schedule. Any deficiencies or equipment failures are reported to the field
supervisor and corrected promptly. Aboveground valves and piping are formally inspected on an annual
basis. These annual facility inspections are documented on the facility inspection form shown in Appendix
D. Buried piping is not uncovered for inspections, but if uncovered for any reason, the piping and
associated equipment is examined for evidence of corrosion. If unacceptable corrosion is discovered,
additional examination and corrective action, including pipe replacement, is performed.
8.3 Saltwater Disposal Facility Inspection
112.9(d) (2) Inspect saltwater (oil field brine) disposal facilities often, particularly following a
sudden change in atmospheric temperature, to detect possible system upsets capable of causing a
discharge.
This section is not applicable because this site is not a saltwater disposal facility.
8.4 Flowline Maintenance
112.9(d) (3) Have a program of flowline maintenance to prevent discharges from each
flowline.
Personnel view and informally inspect aboveground valves and piping several times per week as part of
their routine maintenance schedule. Any deficiencies or equipment failures are reported to the field
supervisor and corrected promptly. Aboveground valves and piping are formally inspected on an annual
basis. These annual facility inspections are documented on the facility inspection form shown in Appendix
D. Buried piping is not uncovered for inspections, but if uncovered for any reason, the piping and
associated equipment is examined for evidence of corrosion. If unacceptable corrosion is discovered,
additional examination and corrective action, including pipe replacement, is performed.
SPCC Plan Page 13
9.0 REPAIR, ALTERATION, RECONSTRUCTION OR CHANGE IN SERVICE
[112.7(i)]
112.7(i) If a field -constructed aboveground container undergoes a repair, alteration,
reconstruction, or a change in service that might affect the risk of a discharge or failure due
to brittle fracture or other catastrophe, or has discharged oil or failed due to brittle fracture
failure or other catastrophe, evaluate the container for risk of discharge or failure due to
brittle fracture or other catastrophe, and as necessary, take appropriate action.
If an AST undergoes a repair, alteration, reconstruction, or change in service, it will be evaluated for the
risk of discharge or failure due to brittle fracture or other catastrophe. Qualified contractors and personnel
will perform all repair, alteration, and/or reconstruction activities according to accepted industry practices
and regulations.
10.0 REGULATORY CONFORMANCE AND EXCLUSIONS [112.70)]
112.70) In addition to the minimal prevention standards listed under this section, include in
your Plan a complete discussion of conformance with the applicable requirements and other
effective discharge prevention and containment procedures listed in this part or any
applicable more stringent State rules, regulations, and guidelines.
10.1 Regulatory Conformance
The subject properties are not subject to any state -regulated discharge prevention and containment
requirements beyond those specified by federal regulation. State notification procedures are included
under the notification section.
10.2 Regulatory Exclusions
The subject properties are classified as onshore production facilities which store only petroleum based
oils. Furthermore, the properties are not expected to cause substantial harm to the environment as
demonstrated by the completed Certification of Applicability of Substantial Harm Criteria form contained in
Appendix G. As such, the subject properties are excluded from the following regulations:
Subpart B - Requirements for Petroleum Oils and Non -Petroleum Oils except Animal Fats ...
40 CFR 117(g) Security (excluding production facilities)
40 CFR 117(h) Loading/unloading rack (site does not have loading/unloading RACK)
40 CFR 112.8 SPCC plan requirements for onshore facilities (excluding production)
40 CFR 112.10 SPCC plan requirements for onshore drilling & workover facilities
40 CFR 112.11 SPCC plan requirements for offshore oil facilities
Subpart C - Requirements for Animal Fats and Oils, Greases, Fish and Marine Oils....
40 CFR 112.12 SPCC plan requirements for onshore facilities (excluding production)
40 CFR 112.13 SPCC plan requirements for onshore oil production facilities
40 CFR 112.14 SPCC plan requirements for onshore oil drilling facilities
40 CFR 112.15 SPCC plan requirements for offshore oil drilling facilities
SPCC Plan Page 14
Subpart D - Response Requirements
40 CFR 112.20 Facility response plans
40 CFR 112.21 Facility response training and drills/exercises
SPCC Plan Page 15
APPENDIX A
INDIVIDUAL SITE INFORMATION
f4 rcitct{it To SPcc Puck
SPCC Plan
AC�R��DfX,6
APPENDIX B
OIL SPILL CONTINGENCY PLANS AND WRITTEN COMMITMENT OF MANPOWER, EQUIPMENT,
AND MATERIALS
SPCC Plan
BBC OIL SPILL CONTINGENCY PLANS AND
WRITTEN COMMITMENT OF MANPOWER, EQUIPMENT, AND MATERIALS
Secondary containment or diversionary structures are impracticable for portions of this facility for the
following reasons (attach additional pages if necessary):
All aboveground oil storage tanks at this facility are contained within diked areas.
Secondary Containment for line treaters, separation units, oil loading areas, and underground flowlines
may be impracticable at this facility for the following reasons:
1) All line treaters and separation vessels at newly constructed batteries are ASME coded flow-
through process vessels and are NOT oil storage vessels.
2) Secondary containment diking around fired line treaters may represent a safety hazard
3) The most likely type release from line treaters or separation units is a pressure release from the
"pop-off" valve discharging gas rather than crude oil.
4) A safe and effective dike system would be difficult to design and impracticable to construct for
loading areas, line treaters, separation vessels, and flowlines.
5) Underground flowlines typically operate at much less than their rated pressure.
6) Extensive diking and/or drainage trenches would interfere with site access for normal operations
and also with current surface land uses. Extensive diking and/or trenching may represent a physical
hazard as well as an impediment to emergency response equipment and personnel.
A spill contingency plan is in effect for this facility in the event of an oil spill. YES
An oil spill contingency plan is attached. YES
A written commitment of manpower is attached to the spill contingency plan. YES
SPCC Plan Page B-1
BBC
OIL SPILL CONTROL AND CONTINGENCY PLAN
FORWARD
Constant vigilance and a personal dedication to protection of the environment should be the goal of every
BBC employee. Every safeguard should be taken to prevent the accidental discharge of oil to soil or water,
and immediate response to oil spills is every employee's responsibility. Preventive action is our best
measure to hold oil discharges to a minimum and reduce the potential pollution danger. The following
contingency plan forms the basis to meet this challenge.
This alert procedure becomes effective immediately upon the observance of or hearing of an oil spill from
any company facilities. Any employee observing or receiving knowledge of an oil spill must immediately
take actions to minimize injuries and damage and notify the designated person. Make sure all steps taken
are in accordance with good safety practices. The priority in all circumstances will be to protect life.
***********************************************
SPCC Plan Page B-2
BILL BARRETT CORP.
OIL SPILL CONTROL AND CONTINGENCY PLAN
PURPOSE
Establish procedures to minimize damage caused by pollution from an accidental oil discharge.
II. GENERAL
A. Operating personnel will become familiar with these procedures and take corrective action in the
event of an oil spill.
B. As a preventive measure, be alert for and eliminate potential pollution hazards.
III. RESPONSE PROCEDURES
A. Upon detecting an oil spill, the person making the discovery should:
1. Determine the source of the leak.
2. Attempt to stop the source of the leak, if it can be done safely.
3. Notify the responsible person and the EH&S Dept. that an oil spill has occurred, and alert
the foreman of corrective action taken or required.
B. For minor spill events not endangering surface or ground water, the Production Foreman shall:
1. Contact the EH&S Dept.
2. Direct safe clean-up of the oil spill.
3. Arrange for necessary repairs.
C. For major spills and spills which endanger surface or ground water, the Production Foreman shall:
1. Mobilize Environmental Emergency Response Equipment and Contractors
2. Contact the EH&S Dept.
3. Direct safe clean-up and arrange for additional equipment, material and manpower as
needed.
4. Arrange for necessary repairs.
D. Containment, Cleanup and Restoration
The general procedures outlined below will normally be followed for spills in most areas. Only approach a
spill if you are certain it is SAFE to do so. If you are not sure it is safe wait for additional personnel and/or
equipment.
1. Land Oil Spill
a. Construct earthen berms or shallow catchment pits with the appropriate
equipment to contain the oil.
b. Remove any free oil with absorbent materials or vacuum trucks
c. Affected soils will either be treated or transported to an approved disposal facility.
d. Dispose of all oil -soaked materials (e.g. hay, absorbent cloths or booms) in an
approved manner.
e. Restore the land area, as nearly as possible, to original conditions.
2. Surface Water Oil Spill
SPCC Plan Page B-3
a. If possible, construct an earthen dam downstream of the oil spill (river or stream
spills only).
b. Allow water past the dam using an underflow pipe, if possible.
c. If it is impractical to build an earthen dam, place an oil -absorbent boom
downstream or outside of the extent of the oil spill area.
d. If possible, construct a backstop downstream of the dam/boom using fence posts
and some type of fencing material. Place a boom in the backstop to absorb residual
traces of oil on the water surface.
e. Remove any free oil from the water surface between the dam/boom and spill
using absorbents or a vacuum truck.
f. Physically clean the bank areas to prevent any residual oil from entering the
water.
g. Dispose of all oil -soaked materials (e.g. hay, absorbent cloths or booms) in an
approved manner.
h. Restore the land area, as nearly as possible, to original conditions.
IV. MANPOWER AND EQUIPMENT AVAILABILITY
A. Company Personnel
In the event of an oil spill, all employees will be utilized as necessary for containment and clean-
up.
The company personnel used to respond to an oil spill at the site are identified in Appendix C.
They will provide oversight in the containment, removal, and remediation of any spilled material.
They will also assist and supervise in the maintenance of site security to insure only authorized
persons are allowed within the site area during response operations.
Company Equipment
1. Cars and pickup trucks equipped with mobile telephones are available for transportation
and communications.
2. Pickups are equipped with shovels and hand tools for use in minor spills. Hazard tape is
available to identify exclusion areas. Pickups are also equipped with fire extinguishers.
3. An inventory of absorbent pads and blankets are not maintained on-site but they are
available at the central office location.
C. Contract Personnel and Equipment Available for Response.
Contract personnel may be used to respond to an oil spill if company personnel are insufficient.
Contractors are identified in Appendix C.
D. Emergency Telephone Numbers
See Appendix C.
V. SPILL/LEAK REPORTING
The following guidelines will be used by personnel for reporting a spill/leak.
A) All spills and leaks of E&P waste, crude oil, or drilling fluids shall be remediated immediately (as
per State rules & regulations). All spills and leaks of E&P waste, crude oil, or drilling fluids of 1 bbl or
more into soil or any volume of E&P waste, crude oil, or drilling fluid contacting surface water (flowing or
SPCC Plan Page B-4
not), ground water, or drainages must be reported to the EH&S Dept. verbally immediately [see attached
phone reporting instructions].
All spills and leaks of any "HAZARDOUS WASTE" shall be immediately reported to the EH&S Dept. If you
are unsure whether you have any "HAZARDOUS WASTE" call the EH&S Department.
B) The following information, at a minimum, is required for all verbal and written spill/leak reports to
the EH&S Dept.
1) Name and number of well.
2) Legal map coordinates to the spill/leak site.
3) Road directions from the closest town.
4) Estimated loss of fluids (oil/condensate/water/drilling mud/other)
5) Did the spill/leak contact or endanger surface or ground water (including intermittent
drainages)?
6) Did the spill/leak contact or endanger crop land or other off-site property?
7) What remedial actions have been initiated or completed?
C) Keep detailed notes and documentation (names, dates/times, etc.) of all activities and reports
completed (including verbal reports). Note the full names of all people contacted.
D) The EH&S Dept. is responsible for completing the required verbal and written reports to the State
and other designated agencies as appropriate. If the EH&S Dept. is not available the appropriate
Production Department personnel or the Legal Department will complete the necessary reports.
E) The Regulatory Agency reporting requirements and criteria for spills/leaks are as follows:
All Regulatory Agency contacts will be made by the EH&S or Legal Dept. or other authorized
personnel as listed above.
- NOTE: The internal reporting is required for all spills/leaks as listed above.
Reporting
Which Spills Must be Reported
(1) Spills that may reach waters of the state and cause a sheen. If the petroleum release is a
harmful quantity (enough to cause a sheen on the water, violate water quality standards, or cause
sludge or emulsion to be deposited below water level) and reaches waters of the state (which
include surface water, ground water and dry gullies or storm sewers leading to surface water), it
must be reported immediately to the National Response Center or US Environmental Protection
Agency. (40 CFR 110.6) Such spills will also be treated as a "major undesirable event" — see (3)
below.
(2) Spills that may pollute waters of the State. Any person who spills or discharges any oil or
other substance which may cause the pollution of the waters of the state shall immediately notify
the COLORADO DEPT. OF PUBLIC HEALTH AND ENVIRONMENT (CDPHE) of the material
spilled or discharged, any containment procedures undertaken, and a proposed procedure for
cleanup and disposal. Such spills will also be treated as a "major undesirable event" — see (3)
below.
(3) Spills exceeding 5 barrels, additional requirements for spills exceeding 20 barrels.
Reporting to COLORADO OIL AND GAS CONSERVATION COMMISSION (COGCC)
SPCC Plan Page B-5
a. Immediate notification for "major undesirable events." Spills/releases in which more than 20
barrels of liquid which are not fully contained on location by a wall, berm or dike shall be
reported verbally to the COGCC as soon as practical, but not later than 24 hours after
discovery. A written report shall also be submitted within 5 days following the conclusion of a
major undesirable event, see c. below.
b. Written notification for "minor undesirable events." Spills/releases of oil, condensate, and
E&P waste or produced fluid exceeding FIVE (5) barrels but less than one hundred (20)
barrels shall be reported to the COGCC as soon as practical. A written report shall be
submitted within 5 days following conclusion of a minor undesirable event, see c. below.
c. A complete written report of minor and major incidents shall be filed on Form 9.
• The date and time of occurrence and, if immediate notification was required, the date and
time the occurrence was reported to the COGCC,
• The location where the incident occurred described by section, township, range, and
county,
• The specific nature and cause of the incident.
• A description of the resultant damage.
• The action taken, the length of time required for control or containment of the incident,
and the length of time required for subsequent cleanup.
• An estimate of the volumes discharged and the volumes not recovered.
• The cause of death if any fatal injuries occurred.
The spill is on BLM land, and is greater than 10 bbls and less than 100 bbls.
Contact: EH&S Dept. must send a written report to the BLM within 15 days.
The spill is on BLM land, and is greater than 100 bbls.
Contact: BLM within 24 hours. EI-I&S Dept. must send a follow-up letter to the BLM.
Regulatory Agency Contact Information:
1. National Response Center
Washington, DC
1-800-424-8802 (24 hour phone)
or
US Environmental Protection Agency
Region VIII Response Center
One Denver Place - Suite 500
999 18th Street
Denver, Colorado 80202-2405
303-293-1788 (24 hour phone)
2. COGCC
1120 Lincoln St., Ste. 801
Denver, CO 80203
Attn: BOB CHESSON
COGCC
Jaime Adkins
Northwest Area Engineer
53 Promontory Place
Parachute, CO 81635
3. COLO. DEPT. OF PUBLIC HEALTH & ENVIRONMENT
WQCD
4300 CHERRY CREEK DRIVE S.
DENVER, CO 80246-1530
SPCC Plan Page B-6
Bureau of Land Management (BLM), GLENWOOD, CO
2425 S. GRAND AVE. STE. 101
GLENWOOD SPGS, CO 81601
(970-247-5234
Report Contents:
When contacting these agencies, the following information will be provided:
• Responsible company/person, including mailing address and telephone number;
• Name of person reporting the release;
• Date and time of release;
• Legal description of release location;
• Type of substance;
• Amount of substance released;
• Waterway affected, including amount reaching water;
• Cause of release;
• Action taken to control, contain and remove release; and
• Other pertinent information specific to the release.
VI. REGULATORY AND MEDIA PERSONNEL
A) Regulatory Personnel
1) Company personnel are expected to cooperate with government regulatory agency
personnel (OSHA, EPA, State agency(ies), County, etc.) requesting a site inspection or
investigation. The EH&S Dept. or Operations Manager (as noted above) should be contacted
immediately if regulatory personnel request a site inspection or investigation.
2) The credentials and identification of all regulatory personnel on site should be reviewed
and noted prior to admission to a company operated site.
3) Specific technical questions and requests for information should be referred to the EH&S
Dept. or Production Department personnel as appropriate.
B) Media Personnel
1) No media personnel are permitted within the secured "exclusion zone" perimeter of a
company operated site. All requests for entry should be referred to the EH&S Dept. or Production
Department personnel as appropriate.
2) Specific questions and requests for information from any media personnel should be
referred to the EH&S Dept., Legal Dept., or Production Department personnel as appropriate.
VII. SAFETY PRECAUTIONS
A) No smoking shall be permitted within 150 feet of free product, condensate or sources of natural
gas.
8) Explosion and fire hazards shall be assessed prior to the operation of motorized equipment in the
spill area.
C) The clean-up area is defined by OSHA as a construction site and personal protective equipment
including hard hats (if overhead work), protective foot wear and eye protection must be worn in this area.
This requirement also applies to contractors.
D) All excavations shall comply with the requirements of 29 CFR 1926 Subpart P.
E) A Confined Space Entry Permit shall be completed prior to entry into an excavation to facilitate
pipeline repairs. The contractor making the repairs shall be responsible for 100% COMPLIANCE with
SPCC Plan Page B-7
OSHA's Permit Required Confined Space Program. A Contractor foreman or the Safety Technician will
function as the Entry Supervisor.
F) Due to the ignitability of crude oil, condensate and natural gas, the spill area shall be treated as a
potentially hazardous response area and as such shall be properly secured to prevent entry by
unauthorized personnel.
VIII. PLANS FOR PROTECTION OF ENVIRONMENTALLY SENSITIVE AREAS
If oil were to impact adjacent drainages or creeks, oil absorbent booms and pads, which are available
through the field office, will be place across the creek bed to prevent migration downstream.
IX. DISCHARGE SPILL PREVENTION MEASURES AND RESPONSE
112.7(a)(3)0i) Discharge prevention measures including procedures for routine handling
of products (loading and unloading and facility transfers).
The following directions are to be used to prevent spills and respond to a spill.
A. Crude Oil Handling Errors
Close surveillance will be maintained during periods of oil transfer to prevent spills from occurring. Valves
and connections will be checked to insure they do not leak.
B. Tank Overfill
Shut in wells connected to tank battery.
Turn off all ignition sources, i.e., heater -treaters, etc.
C. Tank Failure
Shut in wells connected to tank battery.
Turn off all ignition sources, i.e., heater -treaters, etc.
D. Flowline Rupture or Leak
Shut in well connected to flowline at the well and at the production header.
E. Equipment Leaks or Failure
Shut in wells and valves necessary to isolate equipment.
X. ANALYSIS OF SPILLS
All spills will be analyzed according to standard company procedure as outlined below.
A. Parts and Equipment Failures (Spill Failures Only)
1. Description of part or type of equipment
2. Cause of failure (Be descriptive)
3. Length of Service
4. Recommendation, if any.
Human Errors
1. Location
2. Equipment or part being serviced
3. Result of error
4. Was the person familiar with this type of work?
5. Remarks (Avoidable or unavoidable error)
SPCC Plan Page B-8
Actions will be taken as needed to make corrections to equipment or changes in operation procedures
and training on the analysis of spills.
Xl. SPILL HISTORY
Ttiis section provides a historical record of spills at the facility. the information provided here will
be used in training programs and in facility planning to prevent future spills from occurring at the facility.
1. Date: Volume: Cause:
Corrective action taken:
Plans for preventing recurrence:
2. Date: Volume: Cause:
Corrective action taken:
Plans for preventing recurrence:
3. Date:
Volume:
Cause:
Corrective action taken:
Plans for preventing recurrence:
SPCC Plan
Page B-9
APPENDIX C
CONTACT INFORMATION
SPILL REPORTING PROCEDURE
SPCC Plan
BBC CONTACT LIST
OFFICE
MOBILE
HOME
BBC
Scot Donato —EHS
303-312-8191
303-549-7739
303-733-0130
Duane Zavadil-EHS
303-312-8128
303-638-1265
303-660-1145 -Glenda
Dominic Bazile-Ops
303-312-8101
303-810-4875
303-617r9987 —Judy M.
Hollis Bairrington-Ops
303-312-8179
303-345-1299
Francis Barron -Atty
303-312-8515
303-520-7411.
303-
Dave Scobel-Constr
303-312-8115
303-324-6135
303-
Torp Staniforth - Construction .
3(17258-790,1,,j
Q7258-7901 .-
Monty Shed
Monty
307-237-1522
307-262-1511
307-856-6196
GONThAGtOR5'
Doug Henderer-B&A (Air-Remed)
303-781-8211
303-809-2427
Gary Gates-CCI (air)
720-480-0887
Mel Coonrod-EIS (remed) UT
800-641-2927
435-650-3814
Mike Brady - MBC (construction)
970-285-9508
970-250-8188
Cordilleras (remed)
(307) 721-8951
Custom Envir Svcs-Jerry Marks
303-423-9949
800-310-7445 (24 hr)
Nelco Contractors-Price, UT
435-637-3495
R6GIIL1'A;(~O Y /jG`aor al
COGCC
970-985-9000
303-894-2100
CDPHE
303-692-2000
BLM
970.247-5234
v; a {r:s2
WON ps xt 6.
6�Qa;Y ��«`�7�V�2,..d_ �t
j
'M1�(��1
/y�, i &.Y�nCgr agog
�>Y��14Yi�)II�Yq..y!�UU�L�7.^.U��{.Vr'SC2fe���CR
g�2
SPCC Plan
BBC Office Personnel Phone List
Employee; pirect;D{al No,=
Amber Lucero 303-312-8155
Angie McCrea 303-312-8138
Ashley Tanabe 303-312-8143
Bill Barrett 303-312-8107
Bill Crawford 303-312-8135
Bill Mitchell 303-312-8158
Bob Howard *303-312-8104
Bobbie Herbst 303-312-8182
Brad Thomas 303-312-8532
Brian O'Shea 303-312-8150
Carl Paulson 303-312-8186
Charlene Jacob 303-312-8171
Cheryl Edelen 303-312-8159
Chris Bairrington 303-312-8511
Christine Pickart 303-312-8124
Christy Cost
Clare Domingue
Cindy White
Cortney Cagle
Curtis Ditzell
Dan Berberick
Dan Thomas
Dave Macosko
Dave Sanchez
Dave Scobel
Dominic Spencer
Duane Zavadil
Ed Long
Ed Weber
Francis Barron
Frank Farnham
Frank Keller
Fred Barrett
Greg Hinds
Hollis Bairrington
Hunt Walker
Jane Francis
Jane Rerecich
Jim Felton
Jim Kinser
Jim McKinney
Joan Lucero
Jodee Dancek
John Ohlmann
John Shepard
Justin Dowe
Kate Johnston
Kathy Lee
Ken Parrott
Kevin Bittel
Kevin Finnegan
Kim Smith
SPCC Plan
303-312-8175
303-312-8512
303-312-8152
303-312-8169
303-312-8149
303-312-8177
303-312-8133
303-312-8137
303-312-8161
303-312-8115
303-312-8143
303-312-8128
303-312-8144
303-312-8127
303-312-8515
303-312-8115
303-312-8105
303-312-8108
303-312-8119
303-312-8179
303-312-8102
303-312-8121
303-312-8136
303-312-8103
303-312-8163
303-312-8190
303-312-8176
303-312-8180
303-312-8154
303-312-8167
303-312-8178
303-312-8521
303-312-8106
303-312-8140
303-312-8189
303-312-8125
303-312-8185
get! #>
n/a
303-908-1867
n/a
303-588-5185
720-394-4207
n/a
*303-884-3709
n/a
303-210-1767
303-898-9292
n/a
n/a
*303-748-3572
303-877-5239
n/a
303-594-0603
n/a
303-570-8944
*720-939-3769
303-808-8840
n/a
*303-921-4117
303-868-2351
n/a
303-877-5236
303-638-1265
720-635-2125
n/a
303-520-7411
303-929-1177
303-809-9226
303-887-5430
303-717-2496
303-345-1299
*303-884-2982
n/a
303-726-6989
303-881-0840
303-886-4954
n/a
n/a
n/a
n/a
303-877-2952
303-506-7779
n/a
303-886-6655
720-201-4466
n/a
303-808-9566
303-882-3812
Employge , ,
Kim Vickery
Kristen Vanderloos
Kurt Reinecke
Lance Masoner
Leanne Hayes
Leslie Breault
Lisa Fagiano
Lisa Siotos
Lynn Connelly
Lynn Boone Henry
Megan Trask
Mike Fitzmaurice
Mildred Bell
Mindy Hollingshead
Nancy Bickford
Nezhone
Bandmann
Nick Curran
Pam Wolf
Pat Kundert
Patty Adair
Pete Keller
Peter Moreland
Ray Pempengco
Reb. Van Blaricom
Ron Morgenstern
Rosemary Diener
Roy Roux
Russ Koeniger
Scot Donato
Sharon Barrett
Sharon Crumb
Sherry Bingham
Steve Reinert
Sue Eich
Tab McGinley
Te Weber
Ted Enterline
Terrie Perry
Tom Tyree
Tracy Galloway
Travis Johnson
Troy Schindler
DENVER
CAVE GULCH
GILLETTE
NINE MILE
CANYON
Direct'4ial•
Not., . ;
303-312.8109
303-312-8174
303-312-81 13
303-312-8510
303-312-8162
303-312-8527
303-312-8145
303-312-8100
303-312-8112
303-312-8132
303-312-8131
303-312-8172
303-312-8528
303-312-8151
303-312-8153
303-312-8134
303-312-8516
303-312-8188
303-312-8116
303-312-8520
303-312-8141
303-312-8183
303-312-8122
303-312-8148
303-312-8187
303-312-8111
303-312-8166
303-312-8191
303-312-8134
303-312-8160
303-312-8518
303-312-8146
303-312-8147
303-312-8129
303-312-8173
303-312-8531
303-312-8523
303-312-8181
303-312-8165
303-312-8522
303-312-8156
303-293-9100
307-237-1522
307-685-4322
435-725-3515
Cell #<
303-810-1654
n/a
*303-884-2483
n/a
303-906-6496
n/a
n/a
n/a
n/a
303-921-0786
303-829-4581
n/a
n/a
n/a
*303-910-7487
n/a
n/a
303-886-0839
303-324-7694
n/a
303-808-5316
n/a
303-888-2561
303-915-3736
n/a
*303-884-2245
303-807-7128
303-549-7739
n/a
n/a
n/a
*303-929-7131
n/a
720-371-6473
n/a
303-249-3815
n/a
303-594-8794
720-335-2408
n/a
303-249-8511
303-291-0420
307-472-6251
435-725-3519
APPENDIX C
PERSONNEL AND EQUIPMENT AVAILABLE FOR RESPONSE
Designated Person Accountable for Oil Spill at Facility .
1. MONTY SHED
On -the -Scene Coordinator
Work
970-285-9061
Mobile
307-262-1511
Home
2. JESSE MERRY
Alternate On -the -Scene Coordinator
Work
970-285-9061
Mobile
970-230-0436
Spill Management Team
MONTY SHED
On -the -Scene Coordinator
Office
Operations
Office
Logistics
Office
Field Communications
Office
JIM FELTON
Media Spokesperson
Office
303-312-8103
SCOT DONATO
Regulatory & Environmental Evaluation
Office
303-312-8191
Company Personnel
1.
Title -pumper
2.
Title -pumper
3.
Title -pumper
Company Spill Control Equipment
Materials kept on hand include absorbent booms and pads at the BAILEY Compressor Station.
Contract Personnel and Equipment Available for Response
SEE PERSONNEL LIST IN SECTION 9.7.
1. Lease Crews
Location
Office
Location
Office
2. Environmental Consultant Services
Office
Contract Equipment
1. Dirt Work (Backhoe's, Dozers, and Trucks)
Location
Office
Location
Office
2. Vacuum Truck Service
Location
Office
Location
Office
SPCC Plan
SPCC Plan
External Alert Procedures
The following non -company agencies will be notified if a reportable spill is observed.
Federal Response Agency
National Response Center
800-424-8802
Environmental Protection Agency (EPA) Region VIII Response Center
303-293-1788 (24 hour phone)
Bureau of Land Management (BLM)
970-947-5234
State Response Agency
The following will be notified as needed.
Local Emergency Planning Committee
Fire Department
911
Law Enforcement
911
Local Police Department
911
Highway Patrol
911
Sheriff
911
Medical
Ambulance / Emergency Medical Service (EMS)
911
Hospital
911
The notification will include:
a. Exact address and phone number of the facility
b. The spill date and time
c. The type of material spilled
d. Estimates of the total quantity spilled
e. Estimates of the quantity spilled into navigable waters (if applicable)
f. The source and cause of the spill
g. A description of the affected medium (air, water, and soil)
h. Any damages or injuries caused by the spill
i. Actions being used to stop, remove, and mitigate the effects of the discharge
j. Whether an evacuation may be needed.
k. Names of individuals and/or organizations who have also been contacted.
SPCC Plan
APPENDIX D
SPILL REPORT FORM
INSPECTION FORM
SPCC Plan
BBC SPILL REPORT FORM
INITIAL NOTIFICATION MUST NOT BE DELAYED PENDING COLLECTION OF ALL INFORMATION
A. REPORTING PARTY: Name
Phone ( ) Position
Address
City State Zip Code
B. INCIDENT DESCRIPTION
Source and/or Cause of Incident
Date Time
Incident Address/Location
Nearest City Distance from City
Storage Tank Container Type - Above Ground (Y/N) Below Ground (Y/N)
Unknown
Tank Capacity Facility Capacity
Latitude Degrees Longitude Degrees
C. MATERIALS RELEASED
Discharged Quantity Unit of Measure Discharged Material Quantity in Water
D. RESPONSE ACTION
Actions taken to correct or mitigate incident.
E. IMPACT
Number of Injuries Number of Fatalities
Were there Evacuations (Y/N/U) Number Evacuated
Was there any Damage (Y/N/U) Damage in Dollars
SPCC Plan
Additional Information
F. AGENCY CONTACT RECORD AND PRIORITIZED CALL LIST
Individual or Agency
Date
Time
Person Contacted
Caller
Nati Response Center,
800-424-8802
EPA Region VIII,
303-293-1788
Company 2 Office
State Agency
Other
SPCC Plan
LEASE INSPECTION
Facility/Field Name:
Battery Name/Number:
EQUIPMENT
MONTH
1. Storage Tanks (Check for Leaks and excessive
corrosion)
Shell Deck
Vacuum Vents
Foundation and Supports
Valves
2. Emergency Pits
Accumulation of Fluids
3. Saltwater Disposal Systems
Tanks
Pumps
4. Separation Equipment
Treater
Separator
Piping Valves
Safety Devices
Drip Pans And Sumps
5. Facility Transfer Operations
Aboveground Valves
Lines
Pump
Containment Vessel
6. Containment
Condition of Walls
Fluid Accumulation
7. Location
Condition
Spills
Washout
(continued)
SPCC Plan
LEASE INSPECTION
Facility/Field Name:
Battery Name/Number:
EQUIPMENT
MONTH
8. Well
Wellhead Valve or Connection Leak
Well Cellar - water or Oil Accumulation
Wellhead Connection
Pumping Units
Stuffing Box & Tee
Engine
General Conditions of Area
High/Low Pressure Valves
9. Flowlines
Connections and Valves
Flowlines
Corrosion Protection
10. 55 Gallon Drums and Bulk Containers
Proper Labeling
Corrosion
Dents
Note area where corrective actions are required with a check and submit a report on the problem
areas to the company's main office.
Month:
Additional Remarks or Remedial Actions Taken:
This report dated:
Month:
Additional Remarks or Remedial Actions Taken:
By:
This report dated: By:
Month:
Additional Remarks or Remedial Actions Taken:
This report dated: By:
SPCC Plan
(3) Bill Barrett Car
pnr3tionn
ANNUAL SPCC INSPECTION REPORT
STORAGE BATTERY INSPECTED -Include name of battery & legal location also list all assoc. well
names:
Item Status
Satisfactory Unsatisfactory
1) Wellheads
2) Oil Storage Tanks
3) Flowlines
4) Treaters/Separators
5) Secondary Containment Berms
6) Other
Description of Unsatisfactory Items Date of
(incl. condition and recommendations) Corrective Action
Attach additional information if necessary.
INSPECTOR NAME (Print) INSPECTOR SIGNATURE
APPROVED BY: Area Foreman/Mgr. INSPECTION DATE
Dept.
SPCC Plan
File form with EH&S
APPENDIX E
TRAINING RECORD
SPCC Plan
SPCC Training Record Form
Trainer:
Date:
Page
of
Training
Agenda:
Attach copies of handouts.
Name
Signature
Company
Job Title
SPCC Plan
APPENDIX F
STORMWATER INSPECTION PROCEDURE AND DRAINAGE RECORD
SPCC Plan
STORMWATER INSPECTION PROCEDURE AND DRAINAGE RECORD
Earthen berms, containment rings, and other containment structures are inspected on a regular basis for
accumulations of oil and precipitation. These inspections are not typically documented. Generally,
drainage from containment structures is not conducted. Minor accumulations of precipitation are allowed
to evaporate. Large accumulations of fluids may be removed by vacuum truck and either returned to a
separation vessel for processing or transported to a permitted recovery/disposal facility.
In the unlikely event that drainage events are conducted, the accumulated stormwater is visually
inspected for contamination from oil. NO oil is released from or pumped from within the berm onto
the ground or into a water course. Drainage or pumping does not occur until the fluids have been
inspected for oil. Draining only occurs with constant visual supervision of the drain outlet, and only
after determining that the water is indeed fresh. Draining ceases at the first sign of an oil sheen and
the remaining fluid is removed and properly treated or disposed. The foreman in charge of the
facility operations is consulted before any berm is drained or purged.
As required by law, any time that stormwater is discharged from the dike, a record of the inspection,
discharge and oil removal is to be maintained. The following is the discharge record:
Date of
Discharge
Oil Sheen
Present
Inspector's
Signature
Comments
SPCC Plan
APPENDIX A
INDIVIDUAL SITE INFORMATION
SPCC Plan
A.1. BAILEY COMPRESSOR STATION
SESE 22-T6S-R92W, GARFIELD COUNTY, COLORADO
Drainage Pathways. Direction of flow away from site: GENERAL NORTHERN DIRECTION.
Flow is toward NORTH IN EPHEMERAL DRAINAGE AND ULTIMATELY DRY HOLLOW CREEK TO
NORTH AND WEST OF FACILITY APPROXIMATELY 1.5 miles AWAY.
See site-specific diagram.
Plan Implementation (112.7)
Any additional facilities, procedures, methods, or equipment not yet fully operational shall be discussed
with the details of installation and start-up (40 CFR 112.7).
6 COMPESSORS, 2 DEHYDRATORS, ABOVEGROUND TANKS (SEE BELOW)
Any items not yet fully operational will be completed as soon as practical, but no later than six months
following the date of this plan. New individual sites shall have spill prevention and control measures in
place at the time production for the site begins.
Table 1
Storage Capacity and Potential Discharge
NO. OF
UNITS
EQUIPMENT
CONTENTS
CONSTRUCTION
MATERIAL
TOTAL
CAPACITY
(bbls)
CONTAINMENT
CAPACITY
(bbls)
4
TANK
CONDENSATE/OIL
STEEL
500
930
1
TANK
WATER
STEEL
500
930
(gals)
(gals)
1
TANK
LUBE OIL
STEEL
500
550
1
TANK
USED OIL
STEEL
500
550
55 -Gallon drums and small bulk storage containers for lube oils and chemicals may be present at the
facility at various times. These storage containers are small and internal corrosion poses minimal risk of
failure. They are inspected daily to weekly. 55 gallon drums at tank battery should be placed inside the
secondary containment.
Facility Diagram is attached.
SPCC Plan
P18020285 STATION PIPING FINAL V4.0WG, 8/27/2007 4:09:01 PM
I
i. JS .. _Imo'".. rear— , _
�,1r�
E,m
\KAU._
`` 3g 56935'4TE 639:9
�-9g -
y
- -
F-8.3
El. 9D4111‘k
_I
1
a.
a
INERAT�•
&42
t4;JkI
\
���
ik
rot
.
3904
seg
7044' .
, ' ,�j
to
SIo�76rtiANV
gti4 1
\\,[ttireio
Spfz
,P
Iti;/�j.•�
3612'5
/,'"'
'
i7
w
-- 500 IA l
� \; 4
�''
' , �a` —6_ .0
,1
,1
I
eupiE
,1 p�
�;
,
a
SHOPSe
ICE xisting
'18.
rot 4„ 4�
;. *
_
�'.
\Ali
if
parrilillibyriallIEW
SO
d
, �l-. CONT
CTOR(S). S
I
I
pr
��kI,
®•
DEHY
SKID
hrtY
I
9
N
—�
M0
4,�
N6µ
4, w
0 20 50 100 FEET
�
I :\SALES
GA
V
/ ro•
)
\
NSice
h`
/
2
G\
,c��. d
!�\..�q�
`
Nr
.`
-
5936
93
.
EI.
h
>8.8
31,2'
new
r.'rnripri Cro,ind
of Corner Stokes
= .5.9191-}
942
' UINTAH.
ENGINEERING
& LANVD
SURVEYING
OM
REFERENCE DRAWINGS
REV
REVISIONS
DATE
PRPRCTMAWR
CLIENT REFERENCE BILL BARRETT CORPORATION
PRELISSUED R
t,prD+
BAUMBERG, ASSOCIATES,ncR INC.'''
DRAWING STATUS
WEED PER ME. EM E MSIRTuvuw20285
PEWEE, PER NE. EWER wunD,m
1/25/0+
MON
Ew
BAILEY
m
amm
m nom: limy/am , � COMPRESSOR STATION
am..�,�
.. p M
"`°"""`FOP PLOT PLAN
n.E: E E E w�.RLw.p,RE .wmama
nnn..WS+. rMom .m....IR
.m
A
BILL BARRETT CORPORATION....Rw.Rw.
GARFIELD COUNTY, COLORADO
A
R...
_ rc
m.vrUT.,E.
A
�M®RP T rata+
SCALE: 1.-40'
ORM. NO.: 2028500-20-100
171
REV.®
CONSTRUCTION SCHEDULE
Bailey Compressor Station & East Lateral Pipeline
CONSTRUCTION SCHEDULE:
Construction activities are scheduled to commence upon approval of permit
application, land owners Right -of Way (ROW) agreements and associated permits
with a completion date of approximately 20 weeks later.
Construction will begin with pipeline ROW clearing and assuming a reasonable
construction kick off date, expedient construction progress, limited weather-related
delays, and winter stipulations, the reclamation and restoration of the ROW to
include re -seeding should be completed within 30 days of completion of project and
or the first available planting and growing season. Construction activities will only
occur between the hours of 7 am and 5 pm, six days a week (usually Monday to
Saturday) except for during hydrostatic testing which will run for an approximate
24 hour period and in some cases where crews may be required to work a seven (7)
day week depending on need for pipeline.
I"t\NestWater Engineering
' Environmental Consulting Services
2516 FORESIGHT CIRCLE, #1 GRAND JUNCTION, COLORADO 81505 (970) 241-7076 FAX: (970)241-7097
January 21, 2008
-e//,11,1lVfr 2_,
110,D;-,04/4.7,
i
00
Mr. Cody Smith,
Wagon Wheel Consulting :t . /-;
111 East Third Street, Suite 213
Rifle, CO 81650
Via Email: cody@wagonwheelconsulting.com
sdonato@billbarrettcorp.com
RE: Sensitive Plants Species
East Lateral Loop Pipeline and Bailey Compressor Station
Mr. Smith:
This letter report addresses the request of Garfield County to include sensitive plant species in
the assessment of the Bill Barrett Corporation (BBC) projects south of the town of Silt,
Colorado.
WestWater biologists previously prepared two reports entitled "East Lateral Loop Pipeline &
Bailey Compressor Station Integrated Vegetation & Noxious Weed Management Report" and
"East Lateral Loop Pipeline & Bailey Compressor Station Wildlife Assessment and Management
Report" in October, 2007. WestWater biologists routinely perform surveys for sensitive plant
species while performing other biological surveys for a proposed project. However, unless
specifically requested to provide a report concerning the issue of interest, in this case sensitive
plants, the reports do not include details on survey findings.
For the purposes of this letter report, sensitive species are considered to be those included on the
Endangered Species Act (ESA) list and ones recognized as sensitive by BLM.
No ESA listed plants have been previously found in the project area vicinity, and no habitat for
such species is believed to be present. No ESA listed plants were observed during WestWater's
surveys.
BLM sensitive plant species potentially present in the vicinity of the proposed pipeline and
compressor station are: (1) Penstemon harringtoni (Harrington's beardtongue) (2) Astragalus
debequaeus (DeBeque milkvetch), and (3) Astragalus naturitensis (Naturita milkvetch). A brief
description of typical habitat for these species in the project area follows.
(1) Harrington's beardtongue habitat is sagebrush at 6400 feet elevation and higher.
Sagebrush covers the compressor site which reaches 5930 feet elevation at its upper end.
This site was searched on September 24, 2007. At this date a plant as robust as P.
harringtonii would have been visible, although in a dried state. No penstemon plants
were detected.
1
(2) DeBeque milkvetch grows on fine textured soil in and around pinyon juniper woodlands
at elevations common to the project. The plant has not been found east of Rifle,
Colorado and was not observed during project surveys.
(3) Naturita milkvetch is found on shallow soils over rock outcrop terrain in and around
pinyon juniper woodlands at elevations within the range of those of the project. This
plant also has not been found east of Rifle, and was not observed during project surveys.
The above information was corroborated with the Colorado Natural Heritage Program database
and the experience of WestWater biologists in the project area.
In summary, our analysis leads us to conclude that there are no sensitive plant issues with the
existing BBC well sites or the East Lateral Loop Pipeline and Bailey Compressor Station project.
There is no evidence that any of these species are likely present along the proposed pipeline or
on the proposed compressor site.
Please feel free to contact our office with any questions concerning these reports or if we can be
of service in any way.
Sincerely,
Principal Environment Scientist
2
Grand River Institute 4-
P.O. Box 3543 4, Grand Junction, CO 81502 4. 970/245-7868 FAX 970/245-6317
31 December 2007
Bill Barrett Corporation
1099 18th St., Ste. 2300
Denver, Colorado 80202
Attn: Matt Barber
oNiNNviavorlicrling
002 L 0 Ndr
TI P�7
Re: Archaeological Assessment for the proposed Bailey Compressor Station Pipeline in Garfield
County, Colorado
Dear Matt:
I have reviewed the map for the proposed Bailey Compressor Station Pipeline in
Garfield County, Colorado. The areas of construction activity are in T. 6 S., R. 91 W. Sections
29, 30, and 31; and, T. 6 S., R. 92 W. Sections 22, 23, 26, and 27; 6th P.M. The new pipeline
will follow an existing corridor in which two pipelines have been previously constructed, and
will generally cross agricultural lands that have also been surface disturbed.
A files search of the general area was conducted through the Colorado Historical
Society's Compass Website. Fourteen cultural resources survey projects have been completed
in the immediate vicinity of the proposed pipeline with the result of the recording of only two
sites. Both sites occur within about 0.5 mile of the proposed project area; however, they are
over 0.25 mile from the impact area and will not be directly affected. Of the two, 5GF251 (a
prehistoric open camp) has been evaluated as not eligible, and 5GF304 ( a prehistoric rock art
site) has been field evaluated as eligible for listing on the National Register of Historic Places.
Based on these findings, the occurrence of additional significant cultural resources in the impact
area of the proposed new pipeline is considered low.
A list of the projects that have been completed within about 0.5 mile of the proposed
pipeline is attached. Please call me if you have any questions or need additional information.
Sincerely,
Carl E. Conner
Director
Attachment
:• Cultural Resources Consulting :•
List of project previously conducted within about 0.5 mile of the proposed Bailey
Compressor Station Pipeline in Garfield County, Colorado
ID: MC.R.R24
TITLE: CULTURAL RESOURCES INVENTORY OF THE WEST DIVIDE IN GARFIELD AND
MESA COUNTIES, COLORADO
AUTHOR: LAPOINT, HALCYON
DATE: 05/01/1979
CONTRACTOR: COLORADO STATE UNIVERSITY, LABORATORY OF PUBLIC ARCHEOLOGY
ID: MC.LM.R320
TITLE: ROCK ART IN GLENWOOD SPRINGS RESOURCE AREA
AUTHOR: COLE SALLY J
DATE: 01/01/1932
CONTRACTOR: BLM GLENWOOD SPRINGS RESOURCE AREA
ID: MC.LM.R95
TITLE: AN ANALYSIS OF THE PREHISTORIC AND HISTORIC ROCK ART OF WEST -CENTRAL
COLORADO. CULTURAL RESOURCE SERIES #21
AUTHOR: COLE, SALLY J.
DATE: 01/01/1987
CONTRACTOR: SALLY COLE FOR THE BUREAU OF LAND MANAGEMENT
ID: MC.LM.R16
TITLE: A CULTURAL RESOURCE INVENTORY OF NORTHERN GEOPHYSICAL SEISMIC
EXPLORATIONS NEAR BATTLEMENT MESA, MESA AND GARFIELD COUNTIES,
COLORADO (S#1092)
AUTHOR: METCALF, MICHAEL D.
DATE: 10/01/1989
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS, INC. FOR NORTHERN
GEOPHYSICAL SEISMIC EXPLORATIONS INC.
ID: GF.FS.NR53
TITLE: CULTURAL RESOURCES INVENTORY REPORT ON THE BLM PORTION OF THE
PROPOSED TIMBERLAND RESOURCES PIPELINE IN GARFIELD COUNTY, COLORADO
AUTHOR: CONNER, CARL E.
DATE: 10/06/1993
CONTRACTOR: GRAND RIVER INSTITUTE
ID: GF.LM.R60
TITLE: A CLASS III CULTURAL RESOURCES INVENTORY OF PORTIONS OF NASSAU
RESOURCES' PROPOSED RIFLE PIPELINES 1 & 2 IN GARFIELD COUNTY, COLORADO
(S#1234)
AUTHOR: SHIELDS, WM. LANE
DATE: 06/01/1993
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR NASSAU RESOURCES,
INC.
ATTACHMENT, PAGE 2
ID: GF.LM.R95
TITLE: VESSELS OIL AND GAS CO. GIBSON GULCH #15-29 WELL AND ACCESS, GARFIELD
COUNTY, COLORADO (S#8296-3)
AUTHOR: BRECHTEL, JAMES M.
DATE: 05/07/1996
CONTRACTOR: JAMES M. BRECHTEL CONSULTING ARCHAEOLOGIST FOR VESSELS OIL
AND GAS CO.
ID: OF.LM.NR427
TITLE: VESSELS OIL AND GAS DALEY #1 TO JOLLEY #1 6 INCH PIPELINE, GARFIELD
COUNTY, COLORADO
AUTHOR: BRECHTEL, JAMES M.
DATE: 04/13/1995
CONTRACTOR: CONSULTING ARCHAEOLOGIST
ID: GF.LM.NR447
TITLE: VESSELS OIL & GAS CO. GIBSON GULCH UNIT 13-28 ACCESS ROAD, GARFIELD
COUNTY, COLORADO
AUTHOR: BRECHTEL, JAMES M.
DATE: 09/05/1995
CONTRACTOR: CONSULTING ARCHAEOLOGIST
ID: GF.LM.R262
TITLE: CLASS III CULTURAL RESOURCE INVENTORY FOR THE CALPINE NATURAL GAS
COMPANY'S GIBSON GULCH PROSPECT 2-D SEISMIC LINE IN GARFIELD COUNTY,
COLORADO
AUTHOR: BROGAN, JOHN M.
DATE: 10/01/2003
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR CALPINE NATURAL GAS
COMPANY
ID: GF.LM.NR703
TITLE: CALPINE GIBSON GULCH 2D SEISMIC PROJECT: CLASS III CULTURAL RESOURCE
INVENTORY OF APPROXIMATELY ONE-QUARTER MILE OF SEISMIC LINE, GARFIELD
COUNTY, COLORADO
AUTHOR: O'BRIEN, PATRICK
DATE: 04/21/2004
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR CALPINE SEISMIC, INC.
ID: GF.LM.R296
TITLE: REPORT ON THE PREHISTORIC SITE ASSESSMENT OF 5GF304 IN GARFIELD
COUNTY, COLORADO (GRI NO. 2506)
AUTHOR: BARRETT, BILL
DATE: 04/04/2005
CONTRACTOR: GRAND RIVER INSTITUTE FOR BILL BARRETT CORPORATION
ATTACHMENT, PAGE 3
ID: GF.LM.R306
TITLE: CLASS III CULTURAL RESOURCE INVENTORY REPORT FOR ELEVEN PROPOSED
WELL LOCATIONS AND RELATED NEW ACCESS ROAD AND PIPELINE ROUTES IN
GARFIELD COUNTY, COLORADO FOR BILL BARRETT CORPORATION (GRI NO. 2543)(BLM
1105-15)
AUTHOR: MARTIN, CURTIS, CARL E. CONNER AND NICOLE DARNELL
DATE: 07/06/2005
CONTRACTOR: GRAND RIVER INSTITUTE FOR BILL BARRETT CORPORATION
ID: GF.LM.R378
TITLE: CLASS III CULTURAL RESOURCE INVENTORY FOR THE PROPOSED PLATZER
33B-27-692 WELL LOCATION AND RELATED SHORT NEW ACCESS IN GARFIELD COUNTY,
COLORADO FOR BILL BARRETT CORPORATION (GRI NO. 2645)(BLM GSFO# 1106-10)
AUTHOR: CONNER, CARL E.
DATE: 04/28/2006
CONTRACTOR: GRAND RIVER INSTITUTE
0..• 4 0Ii7J 01,1,:13, 110
January 10, 2008
Mr. Matt Barber
Bill Barrett Corporation
1099 18th Street
Suite 2300
Denver, CO 80202
JAN 1 4 2008
RE: Development Plan Review Requirements; initial Sensitive Area Survey information, Bailey
Compressor Pipeline Project
Dear Mr. Barber,
On behalf of Bill Barrett Corporation (BBC), O&G Environmental Consulting (O&G) was
requested to perform an initial information gathering and search concerning the requirements for
a Development Plan to be submitted to Board of County Commissioners, Garfield County. The
Development Plan is for the construction of the Bailey Compressor Pipeline, located entirely
within Garfield County. This initial information gathering is in response to Garfield County
regulation 9.07, Development Plan Review for Pipelines, specifically 9.07.04(10) Sensitive Area
Study.
BBC requested that O&G conduct file surveys and make informal contact with appropriate
agencies to ascertain if there are sensitive area issues along the proposed pipeline route not
previously mitigated or identified. Although the Bailey Compressor Pipeline is entirely on
private land, it is planned adjacent to some federal/ BLM lands. As a courtesy and as a source of
the most accurate and recent information concerning federal and state endangered species and
sensitive resources, O&G informally consulted with BLM and USFWS staff biologist.
Section 10, of the County Regulations requires addressing the following information in the
Development Plan. "List the types and an -as of concern along the pipeline right-of-way, such as;
sensitive plant populations, cultural, archeological, paleontological resources and wetlands
identified during pre -construction environmental surveys, if applicable."
Information provided herein is based on file searches, the route map provided by BBC and
inforrnal consultation with BLM and USFWS specialist. Exact and formal consultation would
require on -ground site surveys by qualified biologist.
Areas of Concern: Following information reviewed and inforrnal consultation with the USFWS
and BLM Resource Specialist, indications are that there are no areas of concern along the
proposed route. The route crosses pinon-juniper areas dominated by upland grasslands, all on
private land.
420,
{ 4r i
11 Inverness Way South • Englewood, Colorado 80112
tel 720-529-9777 • fax 720-529-9798 • www.ogenvironmental,com
Sensitive Plant Populations: Based on discussions and with the USFWS Biologist Creed
Clayton, who has knowledge of the area and is responsible for USFWS (and DOW) consultation
for the Glenwood Springs BLM Energy Office, indicated that he was not aware of sensitive plant
population issues along the proposed route. He did request that if endangered species were
encountered, that the USFWS would be consulted as a courtesy.
Mammal and Raptor Species: Consultation with federal resource specialist indicates that the
habitat associated with the pipeline is conducive to the Lynx; however there have been no
sightings in that specific area. USFWS request that raptor nest not be disturbed or destroyed
during pipeline construction. BBC indicated that they would be employing best management
practices and voluntary contact the USFWS if these situations occur.
Cultural, Archeological, and Paleontological Resources: Bill Barrett Corporation has indicated
that all aspects of cultural resources compliance have been addressed.
Wetlands: Project and National Wetland Inventory Maps do not indicate the specific presence or
identification of wetlands along the project route; however this can only be verified by site
inspection. According to BBC, it is their intent to bore under all potential jurisdictional
wetlands.
O&G consulted with BLM Biologist, Creed Clayton, Glenwood Springs Energy Office, and Rick
Kruger, USFWS, Grand Junction, concerning all area of concern issues, including endangered
species and Colorado River endangered fish species. There does not appear to be critical issues
or areas of concern associated with the proceeding of this project, according to conversations
with both Glenwood and Grand Junction BLM/USFWS field offices.
We greatly appreciate the opportunity to provide the information requested. Should you have
any questions concerning this information provided, please contact me at (720) 529-9777.
Sincerely,
David B. Herrington
Senior Scientist
O&G Environmental Consulting
bit
r
11 Inverness Way South • Englewood, Colorado 80112
tel 720-529-9777 • fax 720-529-9798 • www.ogenvironmental.com
Grand River Institute -:-
P.O. Box 3543 •: Grand Junction, CO 81502 •: 970/245-7868 FAX 9701245-6317 <.•
31 December 2007
Bill Barrett Corporation
1099 18th St., Ste. 2300
Denver, Colorado 80202
Attn: Matt Barber
Re: Archaeological Assessment for the proposed Bailey Compressor Station Pipeline in Garfield
County, Colorado
Dear Matt:
I have reviewed the map for the proposed Bailey Compressor Station Pipeline in
Garfield County, Colorado. The areas of construction activity are in T. 6 S., R. 91 W. Sections
29, 30, and 31; and, T. 6 S., R. 92 W. Sections 22, 23, 26, and 27; 6th P.M. The new pipeline
will follow an existing corridor in which two pipelines have been previously constructed, and
will generally cross agricultural lands that have also been surface disturbed.
A files search of the general area was conducted through the Colorado Historical
Society's Compass Website. Fourteen cultural resources survey projects have been completed
in the immediate vicinity of the proposed pipeline with the result of the recording of only two
sites. Both sites occur within about 0.5 mile of the proposed project area; however, they are
over 0.25 mile from the impact area and will not be directly affected. Of the two, 5GF251 (a
prehistoric open camp) has been evaluated as not eligible, and 5GF304 ( a prehistoric rock art
site) has been field evaluated as eligible for listing on the National Register of Historic Places.
Based on these findings, the occurrence of additional significant cultural resources in the impact
area of the proposed new pipeline is considered low.
A list of the projects that have been completed within about 0.5 mile of the proposed
pipeline is attached. Please call me if you have any questions or need additional information.
Sincerely,
Carl E. Conner
Director
Attachment
•: Cultural Resources Consulting ti•
List of project previously conducted within about 0.5 mile of the proposed Bailey
Compressor Station Pipeline in Garfield County, Colorado
ID: MC.R.R24
TITLE: CULTURAL RESOURCES INVENTORY OF THE WEST DIVIDE IN GARFIELD AND
MESA COUNTIES, COLORADO
AUTHOR: LAPOINT, HALCYON
DATE: 05/01/1979
CONTRACTOR: COLORADO STATE UNIVERSITY, LABORATORY OF PUBLIC ARCHEOLOGY
ID: MC.LM.R320
TITLE: ROCK ART IN GLENWOOD SPRINGS RESOURCE AREA
AUTHOR: COLE SALLY J
DATE: 01/01/1982
CONTRACTOR: BLM GLENWOOD SPRINGS RESOURCE AREA
ID: MC.LM.R95
TITLE: AN ANALYSIS OF THE PREHISTORIC AND HISTORIC ROCK ART OF WEST -CENTRAL
COLORADO. CULTURAL RESOURCE SERIES #21
AUTHOR: COLE, SALLY J.
DATE: 01/01/1987
CONTRACTOR: SALLY COLE FOR THE BUREAU OF LAND MANAGEMENT
ID: MC.LM.R16
TITLE: A CULTURAL RESOURCE INVENTORY OF NORTHERN GEOPHYSICAL SEISMIC
EXPLORATIONS NEAR BATTLEMENT MESA, MESA AND GARFIELD COUNTIES,
COLORADO (S#1092)
AUTHOR: METCALF, MICHAEL D.
DATE: 10/01/1989
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS, INC. FOR NORTHERN
GEOPHYSICAL SEISMIC EXPLORATIONS INC.
ID: GF.FS.NR53
TITLE: CULTURAL RESOURCES INVENTORY REPORT ON THE BLM PORTION OF THE
PROPOSED TIMBERLAND RESOURCES PIPELINE IN GARFIELD COUNTY, COLORADO
AUTHOR: CONNER, CARL E.
DATE: 10/06/1993
CONTRACTOR: GRAND RIVER INSTITUTE
ID: GF.LM.R60
TITLE: A CLASS IB CULTURAL RESOURCES INVENTORY OF PORTIONS OF NASSAU
RESOURCES' PROPOSED RIFLE PIPELINES 1 & 2 IN GARFIELD COUNTY, COLORADO
(S#1234)
AUTHOR: SHIELDS, WM. LANE
DATE: 06/01/1993
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR NASSAU RESOURCES,
INC.
ATTACHMENT PAGE2
ID: GF.LM.R95
TITLE: VESSELS OIL AND GAS CO. GIBSON GULCH #15-29 WELL AND ACCESS, GARFIELD
COUNTY, COLORADO (S#8296-3)
AUTHOR: BRECHTEL, JAMES M.
DATE: 05/07/1996
CONTRACTOR: JAMES M. BRECHTEL CONSULTING ARCHAEOLOGIST FOR VESSELS OIL
AND GAS CO.
ID: GF.LM.NR427
TITLE: VESSELS OIL AND GAS DALEY #1 TO JOLLEY #1 6 INCH PIPELINE, GARFIELD
COUNTY, COLORADO
AuTHOR: BRECHTEL, JAMES M.
DATE: 04/13/1995
CONTRACTOR: CONSULTING ARCHAEOLOGIST
ID: GF.LM.NR447
TITLE: VESSELS OIL & GAS CO. GIBSON GULCH UNIT 13-28 ACCESS ROAD, GARFIELD
COUNTY, COLORADO
AUTHOR: BRECHTEL, JAMES M.
DATE: 09/05/1995
CONTRACTOR: CONSULTING ARCHAEOLOGIST
ID: GF.LM.R262
TITLE: CLASS III CULTURAL RESOURCE INVENTORY FOR THE CALPINE NATURAL GAS
COMPANY'S GIBSON GULCH PROSPECT 2-D SEISMIC LINE IN GARFIELD COUNTY,
COLORADO
AUTHOR: BROGAN, JOHN M.
DATE: 10/01/2003
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR CALPINE NATURAL GAS
COMPANY
ID: GF.LM.NR703
TITLE: CALPINE GIBSON GULCH 2D SEISMIC PROJECT: CLASS III CULTURAL RESOURCE
INVENTORY OF APPROXIMATELY ONE-QUARTER MILE OF SEISMIC LINE, GARFIELD
COUNTY, COLORADO
AUTHOR: O'BRIEN, PATRICK
DATE: 04/21/2004
CONTRACTOR: METCALF ARCHAEOLOGICAL CONSULTANTS FOR CALPINE SEISMIC, INC.
ID: GF.LM.R296
TITLE: REPORT ON THE PREHISTORIC SITE ASSESSMENT OF 5GF304 IN GARFIELD
COUNTY, COLORADO (GRI NO. 2506)
AUTHOR: BARRETT, BILL
DATE: 04/04/2005
CONTRACTOR: GRAND RIVER INSTITUTE FOR BILL BARRETT CORPORATION
ATTACHMENT, PAGE 3
ID: GF.LM.R306
TITLE: CLASS III CULTURAL RESOURCE INVENTORY REPORT FOR ELEVEN PROPOSED
WELL LOCATIONS AND RELATED NEW ACCESS ROAD AND PIPELINE ROUTES IN
GARFIELD COUNTY, COLORADO FOR BILL BARRETT CORPORATION (GRI NO. 2543)(BLM
1105-15)
AUTHOR: MARTIN, CURTIS, CARL E. CONNER AND NICOLE DARNELL
DATE: 07/06/2005
CONTRACTOR: GRAND RIVER INSTITUTE FOR BILL BARRETT CORPORATION
ID: GF.LM.R378
TITLE: CLASS III CULTURAL RESOURCE INVENTORY FOR THE PROPOSED PLATZER
33B-27-692 WELL LOCATION AND RELATED SHORT NEW ACCESS IN GARFIELD COUNTY,
COLORADO FOR BILL BARRETT CORPORATION (GRI NO. 2645)(BLM GSFO# 1106-10)
AUTHOR: CONNER, CARL E.
DATE: 04/28/2006
CONTRACTOR: GRAND RIVER INSTITUTE
SENSITIVE AREA SURVEY
EAST LATERAL PIPELINE AND BAILEY COMPRESSOR STATION
Bill Barrett Corporation has performed past sensitive area surveys for the selected
pipeline route. No areas were found to be within cultural preservation areas along
the proposed route. The proposed pipelines will follow an existing pipeline R.O.W.
that belongs to BBC. If in the case that cultural artifacts are found during the
construction of the projects, BBC agrees to stop operations and inform all
associated agencies of the find. Work will not continue until cleared by prevailing
agency.
BAILEY COMPRESSOR & EAST LATERAL PIPELINE
LAND GRANTS
Please note that due to the route selection for these pipelines that no Land Grants will be
applicable to this permit application.
East Lateral Loop Pipeline & Bailey Compressor Station
Integrated Vegetation & Noxious Weed Management Report
Garfield County, Colorado
Compressor Station Site with big sagebrush the dominant plant cover
Prepared for:
Bill Barrett Corporation, Inc.
Prepared by:
WestWater Engineering
(In Cooperation with Wagon Wheel Consulting, Inc.)
October 2007
INTRODUCTION
A field inspection of the proposed compressor station site and pipeline route was conducted by
WestWater Engineering (WWE) biologists on September 24, 2007. The site map is shown in
Figure 1. The inspection focused on noxious weeds and biologically sensitive areas and wildlife.
This integrated vegetation and noxious weed management plan, required by Garfield County
Regulation 9.07.04 (13) (Board of County Commissioners 2006), uses the data obtained.
LANDSCAPE SETTING
The Barrett East Lateral Loop proposed compressor station site is located in Section 22, SE1/4
SE 1/4, T6S, R92W, 6th PM (Figure 1 - Map). The Colorado River at the town of Silt, Colorado,
is approximately 2.5 miles to the north. The 7 ± acre site is located on a gentle north sloping
Sagebrush Park, which is next to pinon pine -Utah juniper woodland to the east. The proposed
alignment of the associated pipeline follows an existing pipeline southeastward, turning east and
then northeasterly to end 3.1 miles to the east of the compressor station, involving eight sections.
The entire project lies on fee -simple properties. Bailey's ecoregional map (Chapman et al. 2006)
shows the project in the Colorado Plateau's Shale Deserts and Sedimentary Basins Ecoregion.
The soils derive from sandstones, shale, and basalt. The U.S. Natural Resources Conservation
Service classifies the rangeland ecological site on the proposed compressor site and over most of
the pipeline route, as a Rolling Loam (loamy soils on a rolling landscape) (NRCS 2007a).
FINDINGS
The noxious weeds list of Garfield County plus the State noxious weed list formed the search list
(Table 1). These lists can be found online at
www.garfield-county.com/Index.aspx?page=607
and at
www.colorado.gov/cs/Satel lite?c=Page&cid=1174084048733&pagename=Agriculture-
Main%2FCDAGLayout.
Figure 1 depicts weed locations found within and adjacent to the project site/route. Table 2
records the weed findings at the compressor station site and along the pipeline route. All the
weed species found in this inspection occurred in the area before the recent oil and gas
development activity, due to the area's long history of an agricultural, pastoral economy. The
majority of the weeds were found along roads. The roads built or used most recently by
petroleum development activities tend to encourage weeds, in particular, Russian knapweed;
Acroptilon repens (Figure 2). Roadsides with long-established vegetation tend to have lesser
amounts of noxious weeds. Chicory, Cichorium intybus, is a notable exception commonly
established along old roadways (Figure 3). The difference in those two species may be due to
the more recent immigration of Russian knapweed, rather than any lack of ability to compete
with other plants and persist.
WestWater Engineering
Page 1 of 13 pages October 2007
Simplified Control Method Recommendations
Grasses compete well. Re -seed with aggressive grasses, if appearing in
ROW, apply herbicide prior to flowering.
Re -seed with aggressive grasses, remove at flowering or early seed, or
apply herbicides at pre -bud or rosette stage.
Re -seed with aggressive grasses; apply herbicides between rosette and pre-
1
bud stages.
Till or hand grub in the rosette stage, mow at bolting or early flowering;
apply seed head & rosette weevils, leaf feeding beetles, and/or herbicides
in rosette stage.
The least aggressive thistle, prevent from flowering by tillage, hand
grubbing, or mowing. Apply herbicides pre -flowering.
Hand grubbing may be sufficient since there are only a few localized
plants currently.
1 Apply herbicide prior to flowering, Re -seeding disturbed sites with fast
growing grasses. The most difficult thistle to control.
Re -seeding disturbed sites with fast growing grasses, herbicide in fall
(Curtail recommended), allelopathic —tillage & repeated applications may
be necessary.
Common Name*/ Scientific Name Type**
Symbol
0a
W
P7
P]
PP
a
Arctium minus
Cynoglossum
officinale
Cichorium intybus
Carduus nutans
Circium vulgare
Onopordum
acanthium
Circium arvense
Acroptilon repens
Common Burdock /
ARMI2
Houndstongue / CYOF
Chicory / CIIN
Thistle, Musk / CAN
Thistle, Bull / CIVU
Thistle, Scotch /
ONAC
Thistle, Canada /
CIAR4
Knapweed, Russian /
ACRE3
4
0
E
V1
V1
n
N
2
cl) 30 CS
0 'fi
' 0 fi
y 0
0tv° N 4
O 0 0
u
e
odF
o 0.o
.o v�
t3
O U CS
U « s
0 > Q
N y
AA
Vi •
October 2007
Page 3 of 13 pages
WestWater Engineering
Table 2. Noxious weeds encountered along Barrett's proposed East Lateral Loop
Compressor Station and Pipeline, September 24, 2007
Point
Plant Codes'
Notes
1
ACRE3
Russian knapweed along road to point #2
2
ACRE3
Russian knapweed along road to point #1
3
ACRE3
Russian knapweed along road to point #4
4
ACRE3
Russian knapweed along road to point #3
5
ACRE3
Russian knapweed a few scattered plants
6
ACRE3
Russian knapweed scattered plants to point #7
7
ACRE3
Russian knapweed scattered plants to east 30 ft
8
ACRE3
Russian knapweed scattered plants to point #9
9
ACRE3
Russian knapweed scattered plants to point #8
10
ACRE3
Russian knapweed scattered plant patch 10 ft x 20 ft
11
ONAC
Scotch thistle 3 plants
12
ONAC
Scotch thistle 3 plants, appears affected by herbicides
13
ONAC
Scotch thistle 1 plant (see Figure 4)
14
CIIN
Chicory on roadside and north side of right-of-way (ROW)
15
CIIN
Chicory along road to point #17 + 1 clump Canada thistle
16
CIIN
Chicory stand thins & continues east along road
17
CANU4
Musk thistle a few plants (see Figure 5)
18
CIVU
Bull thistle a few plants (see Figure 7)
19
CIVU
Bull thistle a few plants
20
CIVU
Bull thistle narrow fairly dense stand to point #21
21
CIVU
Bull thistle narrow fairly dense stand to point #20
22
Ditch of cockleburs', snipe flushed 25 ft from point
23
CIIN
Chicory band 30 ft wide across field to point #25
24
CIVU
Bull thistle 2 plants
25
CIIN
Chicory west end of stand beginning at point #23
26
ACRE3
Russian knapweed thin patch 20 ft x 30 ft
27
ACRE3
Russian knapweed small patch 15 ft x 30 ft
28
CANU4
Musk thistle 16 plants
29
CIIN, CYOF
Canada thistle, large patch along creek, houndstongue 20 plants
30
CIVU, ELAN
Bull thistle 13 plants, Russian olive (ELAN) 1 plant
31
CYOF, CANU4
Houndstongue & musk thistle to point #32 heavy infestation
32
CYOF, CANU4
Houndstongue & musk thistle to point #31
33
CANU4
Musk thistle heavy infestation
34
CIAR, CANU4
Canada & musk thistles heavy infestation
35
ACRE3
Russian knapweed patch 12 ft x 20 ft
36
CIVU
Bull thistle 10 PLANTS
37
CANU4
Musk thistle patch 120 ft x 100 ft
38
CIAR
Canada thistle patch 90ft x 50 ft (see Figure 6)
39
CIIN
Chicory heavy infestation in pasture to point #40
40
CIIN
Chicory heavy infestation in pasture to point #39
41
ARMI
Common burdock 12 plants
' Plant codes used to identify points on Figure I.
2 Cocklebur, Xanthium strumarium, is not designated a noxious weed
WestWater Engineering
Page 4 of 13 pages
October 2007
Figure 2. Russian knapweed establishing itself along a newly constructed road
Figure 3. East Lateral Loop proposed pipeline follows along the left side of the road.
This is an old road with a well developed stand of chicory along its left side.
WestWater Engineering
Page 5 of 13 pages
October 2007
Figure 4. Dried Scotch thistle found along East Lateral Loop proposed route.
Notice the "wings" on the stem and the pale appearance of the plant.
Figure 5. Musk thistle, notice the flat bracts Figure 6. Canada thistle, gentle bracts
WestWater Engineering
Page 6 of 13 pages
October 2007
Figure 7. Bull thistle, found at Rodriek Well site ponds. A bull thistle leaf has a lanceolate apex
DISCUSSION and PLANNED ACTIONS
Weed Control
Prior to ground disturbing activities, the weeds found along the right-of-way (ROW) should be
treated with an herbicide appropriate for the species at the most effective time for the majority of
the species.
Herbicide treatment with two or more physiological modes of action in spring and fall (fall =
after approximately August 15, when natural precipitation is present) is the best method to
control difficult species such as Russian knapweed (Boerboom 1999, Sullivan 2004). The
resilience and ability to quickly develop immunity to herbicides, particularly those used
incorrectly, makes it imperative to use the proper chemicals at the correct time in the specified
concentration. Most misuse seems centered around excessive use either in frequency or
concentration. This results in mostly top kill and an immune phenotype.
Because noxious weed species occur along the proposed East Lateral Loop route from end to
end, even though generally in low amounts, the potential for these weeds to spread during and
following the construction phase of the project is high. Standard operating procedure should be
to keep soil disturbing activities to the minimum level possible. Construction vehicles should
park on previously disturbed lands. Temporary fencing may be needed in places to confine
vehicular activities. To the extent practical, frequently clean vehicles to prevent the spread of
weed seeds being carried from place to place. Segregating topsoil (0-4 inches rocky soils, 0-16
inches rock -free soils), to be returned to original location in the standard method as the project
proceeds, works well to allow native plants to rapidly return to the site.
State -of -the -industry techniques will best control water drainage to reduce erosion. Erosion
blankets, barriers, and wattles should be of biodegradable materials. Reused materials should
only come from weed -free areas.
WestWater Engineering Page 7 of 13 pages October 2007
The following tables summarize the most effective treatment strategies for noxious weeds,
depending upon their growth habits. Table 3 includes annuals and biennials and Table 4 shows
strategies for perennial weeds.
Table 3. Treatment Strategies for Annual and Biennial Noxious Weeds
Target: Prevent Seed Production
1. Hand grub (pull), hoe, till, cultivate in rosette stage and before flowering or seed maturity.
2. Chop roots below soil level.
3. Treat with herbicide in rosette or bolting stage, before flowering.
4. Mow biennials after bolting stage, before seed set. Mowing annuals may not prevent
flowering.
Table 4. Treatment Strategies for Perennials
Target: Deplete nutrient reserves in root system, prevent seed production
1. Allow plants to expend as much energy from root system as possible, do not treat when first
emerging in spring but allow growth to bud/bloom stage.
2. Herbicide treatment at bud to bloom stage or in the fall. In the fall plants draw nutrients into
the roots for winter storage. Herbicides will be drawn down to the roots more efficiently at
this time. If the weed patch has been present for a long period of time, another season of seed
production is not as important as getting the herbicide into the root system. Spraying in the
fall will kill the following year's shoots, which are being formed on the roots at this time.
3. Mowing usually is not recommended because the plants will flower anyway; seed production
may be reduced, however. Many studies have shown that mowing perennials and spraying the
re -growth is not as effective as spraying without mowing. Effect of mowing is species
dependent; therefore, it is imperative to know the species and its biology (Hartzler 2006,
Sirota 2004).
Re -vegetation
The proposed compressor station would constitute the largest disturbance to natural vegetation
because the site has native big sagebrush; Artemisia tridentata wyomingensis (see Cover Photo).
The proposed pipeline route is along an existing ROW and would re -disturb vegetation in a
lower successional state. The fact that the ROW rehabilitation was successful over most of the
alignment (Figure 8), suggests that returning it to its current condition is a reasonable
expectation. The compressor station would likely be a long-term facility. The possibility of
returning the site to sagebrush cover after site closure is less certain.
The most valuable sagebrush in this area should average greater than 18 inches high with a
canopy cover value greater than 18 percent, occupying stands larger than 18 acres (the "Rule of
Eighteens"). Much of the sagebrush in the basin south of Silt has one or all three of these values
less than this. Mitigation for lost acreage of sagebrush lands could be done, where appropriate.
Two approaches for mitigation are proposed. They are 1) establish sagebrush and similarly -sized
native shrub patches in those portions of the ROW distant (>250 m) from any live sagebrush or
rabbitbrush plants (Attachment A) and 2) treat ROW sagebrush that can be avoided by project
WestWater Engineering
Page 8 of 13 pages October 2007
Figure 8. Pipeline rehabilitation shows successful establishment of seeded grass
species in the mid-ground, yet poor establishment in the foreground, October 2, 2007
construction crews to improve them. Mowing or disking sagebrush, formerly a popular
treatment, would not be done. Biologists now recognize that young sagebrush plants are of less
value to wildlife than mature plants (Welch 2005). Inter-seeding desirable forb and grass species
into sagebrush stands that have a degraded understory is a new and promising practice. Table
5 provides a seed mix formula that can be used in an inter-seeding project.
Because achieving germination of sagebrush seeding is less reliable than achieving it with native
grasses, most of the disturbed area would use a seed mix purely of native grasses. Forbs would
not be seeded due to the difficulty of establishing desirable forbs before undesirable weeds
invade. Also, broadleaf herbicides can safely be used to remove any of the noxious weed species
on the Garfield County list from a seeding that only includes grasses. Non-native species should
not be in the seed mixes because they retard the return to a natural plant cover (CNHP 1998).
Pinon juniper woodland (PJ) is, likewise, much reduced in this basin. The ratio of deer and elk
foraging area (sagebrush, pasture, crop land) to cover area (PJ) is excessively high. Therefore,
no reduction in PJ to expand sagebrush is recommended.
There are four areas of moist soils along the proposed pipeline route: Divide Creek, two small
drainages, and a ditch line east of Garfield County Road 311. Divide Creek, at the proposed
crossing in Section 25 (SE1/4, SW1/4, T6S, R92W) is incised, putting the floodplain water table
too low to support emergent vegetation such as sedges. The water regime does support riparian
vegetation, thus, floodplain-adapted grasses should be seeded for rapid restoration of desirable
perennial ground cover. The seed formula in Table 5 includes moist soil species.
WestWater Engineering Page 9 of 13 pages October 2007
Table 5. Recommended Seed Mix for the East Lateral Loop Pipeline & Bailey
Compressor Station Project, Bill Barrett Corporation, Garfield County, Colorado.
1 d S r'n s BLM Field Office recommendations.
Adapted from G enwoo p t g
Scientific Name
Common Name
Seeds/ft. Z
Percent
of Total
by
Weight
Application Rate
Lbs PLS*/acre
Plant the following sod -forming grasses (25 %)
Pascopyrum smithii
Western wheatgrass
8
20
3.0
Glyceria grandis
American mannagrass
20
5
0.7
Plant the following bunch grasses (16 %)
Sporobolus airoides
Alkali sacaton
20
3
0.5
Achnatherum hymenoides
Indian ricegrass
6
13
2.0
Plant two of the following bunch grasses (26 %)
Agropyron trachycaulum or
Elymus trachycaulus
Slender wheatgrass
7
13
2.0
Elymus 1. lanceolotus
Thickspike wheatgrass
7
13
2.0
Stipa comata
Needle -&-thread
5
13
2.0
Leymus cinereus
Great Basin wildrye
6
13
2.0
Plant one of the following bunch grasses (5 %)
Poa sanbergii
Sandberg bluegrass
15
5
0.7
Poafendleriana
Muttongrass
15
5
0.7
Plant the following warm season grasses (28%)
Panicum virgatum
Switchgrass
15
11
1.7
Hilaria jamesii
Galleta (Viva florets)
9
17
2.5
Totals
97 - 100
100
15.1
*PLS is Pure Live Seed
Disturbed areas should be re -seeded immediately. The seed mix in Table 5 is designed to
simplify rehabilitating loam soils that vary from shallow to deep and drier uplands, and
occasionally flooded bottomlands.
Seed should be applied immediately upon completion of construction. Drilling is preferred, yet
broadcasting at the application rates indicated in Table 5 onto a roughened surface followed by
harrowing may be done. Re -seeding may be required if monitoring indicates lack of adequate
germination. Re -seeding should be done at the optimum season, late fall. WWE can provide
additional help as company environmental managers plan the approach Barrett Corporation will
take in meeting Garfield County requirements for the rehabilitation of the East Lateral Loop
Pipeline and Bailey Compressor Station Project.
WestWater Engineering Page 10 of 13 pages October 2007
Monitoring
Monitoring for targeted weeds and re -seeding success should be performed on a bi-weekly basis
beginning at spring green -up and continuing through the growing season.
Monitoring by qualified personnel should be conducted using Table 6 as a general guide to key
plant growth periods and best control periods. Whitson et al. (1996) is a recommended field
guide to weed identification.
WestWater Engineering Page 11 of 13 pages October 2007
0
z
0
sn
v
04
!flowering — seed set
0
rn
a>
0
0
E
n
n
,0
n
SLA
bA
OD1-4
o E
rosettes #-->
0
ao
n
n
n
0
c
0.1
Houndstongue
Thistle, Canada IP
n
!flowering Iseed set
i
0
7-1
on
0
0
0
0
0
n
re
rosettes I-->
Thistle, Scotch
0
C
a
cn
O
U
II
0
0,
II
Tat
0
0
a)
0
ccs
II
°
O
s-4
0
cat
dl
u
Shaded areas indicate best control timing.
October 2007
Page 12 of 13 pages
WestWater Engineering
REFERENCES
Board of County Commissioners. 2006. Garfield County zoning resolution of 1978, amended October,
2006. Board of County Commissioners, Building and Planning Department, Glenwood Springs,
Colorado, 78 pp.
Boerboom, Chris. 1999. Herbicide mode of action reference. Weed Science, University of Wisconsin,
5
pp.
Chapman, S. S., G. E. Griffith, J. M. Omernik, A. B. Price, J. Freeouf, and D. L. Schrupp. 2006.
Ecoregions of Colorado. Reston, Virginia: U.S. Geological Service (map scale 1:1,200,000).
CNHP. 1998. Native Plant Re -vegetation Guide for Colorado. Colorado Natural Heritage Program,
Caring for the Land Series, Vol. III, State of Colorado, Division of Parks and Outdoor
Recreation, Department of Natural Resources, Denver, 258 pp.
Hartzler, Bob. 2006. Biennial thistles of Iowa. ISU Extension Agronomy. URL:
http://www.weeds.iastate.edu/mgmt/2006/iowathistles.shtml
NRCS. 2007a. Web Soil Survey, U.S. Department of Agriculture. URL:
http://websoilsurvey.nrcs.usda.gov.
NRCS. 2007b. The PLANTS Database (http://plants.usda.gov, 7 September 2006). National Plant Data
Center, U.S. Department of Agriculture, Baton Rouge, Louisiana 70874-4490.
Sirota, Judith. 2004. Best management practices for noxious weeds of Mesa County. Colorado State
University Cooperative Extension Tri River Area. Grand Junction, Colorado, URL:
http://www.coopext.colostate.edu/TRA/PLANTS/index.html#http://www.coopext.colostate.edu/T
RA/PLANTS/bindweedmite.html
State of Colorado. 2005. Rules pertaining to the administration and enforcement of the Colorado
Noxious Weed Act, 35-5-1-119, C.R.S. 2003. U.S. Department of Agriculture, Plant Industry
Division, Denver, 78 pp.
Sullivan, Preston, G. 2004. Thistle control alternatives. Appropriate Technology Transfer for Rural
Areas, National Sustainable Agriculture Information Service, Fayetteville, Arkansas, 9 pp.
Welch, Bruce L. 2005. Big sagebrush: A sea fragmented into lakes, ponds, and puddles. Gen. Tech Rep.
RMRS-GTR-144. Fort Collins, CO: U.S. Department of Agriculture, Forest Service, Rocky
Mountain Research Station. 210 p.
Whitson, T. D. (editor), L. C. Burrill, S. A. Dewey, D. W. Cudney, B. E. Nelson, R. D. Lee, and Robert
Parker. 1996. Weeds of the West. Western Society of Weed Science in cooperation with
Cooperative Extension Services, University of Wyoming. Laramie, Wyoming. 630pp.
WestWater Engineering Page 13 of 13 pages October 2007
ATTACHMENT A
Recommended Seed Mix for sagebrush patch establishment along
the East Lateral Loop Project, B Barrett Corp. Garfield County, Color
Scientific Name
Common Name
Seeds/ft.2
Percent
of Total
by
Weight
Application Rate
Lbs PLS*/acre
Plant the following in wet meadow type soils
Artemisia tridentata
wyomingensis
Wyoming big
sagebrush
50
100
0.9
Chysothamnus nauseosus
albicaulus
Whitestem rubber
rabbitbrush
10
1.1
Atriplex confertifolia
Four -winged saltbush
10
6.7
Castileja cromosa or
linariaaefolia
Indian paintbrush
25
0.2
Glomus fasciculatus
Mycorrhizal pellets*
Per supplier
recommendation
Totals
50
100
8.9
*recommended only, see Barrow and McCaslin (1995)
WestWater Engineering Attachment A October 2007
East Lateral Loop Pipeline & Bailey Compressor Station
Wildlife Assessment and Management Report
Garfield County Conditional Use Permit Application
Northern Saw -whet Owl banding scene near East Lateral Loop Project site
Prepared for:
Bill Barrett Corporation, Inc.
Prepared by:
WestWater Engineering Inc.
(In coordination with Wagon Wheel Consulting, Inc.)
October 2007
INTRODUCTION
The proposed Barrett East Lateral Loop Pipeline and Bailey Compressor Station site is located in
Section 22, SE1/4 SE 1/4, T6S, R92W, 6th PM (Figure 1). The Colorado River at the town of
Silt, Colorado, is approximately 2.5 miles to the north. The 7± acre compressor station site is
located on a gentle north sloping big sagebrush park next to piflon pine -Utah juniper woodland to
the east. The proposed route of the associated pipeline follows an existing pipeline route
southeastward, turning east and then northeasterly to end 3.1 miles to the east of the compressor
station. The entire project lies on fee -simple properties. Bailey's ecoregional map (Chapman et
al. 2006) shows the project in the Colorado Plateau's Shale Deserts and Sedimentary Basins
Ecoregion. The soils derive from sandstones, shale, and basalt. The Natural Resources
Conservation Service classifies the rangeland ecological site on the proposed compressor site and
over most of the pipeline route as a Rolling Loam (loamy soils on a rolling landscape).
WestWater Engineering (W WE) conducted a site and route inspection on September 24, 2007.
The lands were surveyed for plant community conditions, listed noxious weeds, and wildlife.
This document covers those matters that relate to wildlife. The species discussed are a fraction
of the total, yet represent the major wildlife concerns of the area. This assessment and mitigation
plan meets the wildlife requirement of Garfield County Regulation 9.07.04 (10) (Board of
County Commissioners 2006).
RESULTS
Big Game
Colorado Division of Wildlife (CDOW) places the area within Game Management Unit 42.
Mule deer and elk severe winter range overlays the project area entirely. CDOW defines severe
winter range to be where 90 percent of a species of wildlife are concentrated during the worst
two winters in ten. Every winter both deer and elk concentrate in the project area. In the project
area, elk (wapiti) are as common, or more common, than mule deer according to pellet group
abundance (Figure 2). Apparently, elk have adapted to higher densities of roads in the area than
is typical elsewhere (Lyon 1983). The sagebrush generally shows extreme hedging from big
game browsing (Figure 3). This suggests that a shortage of sagebrush is a limiting factor in big
game winter range carrying capacity. The piflon pine -Utah juniper woodlands on steeper,
rockier slopes provide escape and loafing cover for deer and elk.
Black bears typically center their summer activities in the aspen zone and move into the
mountain shrub zone in mid August to fatten up for winter hibernation. This is typical, but bears
exhibit atypical behavior and do it frequently when mast crops fail in their usual range. This
means that bears may pass through the Bailey Compressor Station site. Bears will be drawn to
human food in any form, garbage or otherwise. The maxim cannot be overused, that "a fed bear
is a dead bear". It is highly recommended that food storage and garbage removal be done in a
timely and secure manner so as to not habituate bears to a human facility.
WestWater Engineering Page 1 of 9 pages October 2007
•
•
East Lateral Loop Pipeline
tt1
a
O
R c
a
c
of '0)
c u,
E ILI N 'Y
4) 1-
E E
N
tn
a3
a
co.
g t�
N
0
0
p. µms._....
•
u
Lt.)
(r J
r7„
S')
t)Hm
1
Figure 2. Elk and deer pellet groups near the
proposed Bailey Compressor Station site,
Garfield County, Colorado.
Figure 3. Hedged big sagebrush plant on the
proposed Bailey Compressor Station site,
Garfield County, Colorado.
Birds
Species encountered through casual observation during the multiple -objective survey are shown
in Table 1 below:
Table 1. Species Encountered During the Survey
Red-tailed Hawk
American Kestrel
Wilson's Snipe
Mourning Dove
Northern (Red -shafted) Flicker
Piton Jay
Western Scrub Jay
Mountain Chickadee
Juniper Titmouse
White -breasted Nuthatch
Mountain Bluebird
Yellow-rumped (Audubon's)
Warbler
Chipping Sparrow
Song Sparrow
White -crowned Sparrow
Western Meadowlark
House Finch
Cassin's Finch
Pine Siskin
American Goldfinch
Black -billed Magpie Savannah Sparrow
Note: bold indicates a U.S. Fish and Wildlife Services Species of Conservation Concern & italics indicate species migrating
and/or has no nesting habitat in the area.
Birds of Conservation Concern are known to inhabit the area. These include northern harrier,
golden eagle, loggerhead shrike, pifion jay, Bewick's wren, black -throated gray warbler, and
Brewer's sparrow. Only the Brewer's sparrow has a potential for nesting and/or significant
foraging within any habitat of the type that would be affected by the project.
WestWater Engineering Page 3 of 9 pages October 2007
Considering the current condition of the sagebrush on the compressor site, and generally in the
area, it isn't likely that Brewer's sparrows occupy any of the habitats that would be further
degraded or destroyed by the proposed action.
Several raptors reside or pass through the basin south of Silt. Kim Potter (U.S. Forest Service
biologist, Rifle, Colorado, pers. comm.) reports nesting red-tailed hawks, American kestrels, and
long-eared owl in the basin. Strong evidence exists for great horned owls, Cooper's hawks, and
northern saw -whet owls also nesting in the area. Swainson's and sharp -shinned hawks may nest
in the area as well. Reports suggest that barn owls and western screech owls have expanded their
ranges into the area almost certainly due to the recent stretch of mild winters (K. Potter pers.
comm.). Northern pygmy owls, northern goshawks, rough -legged hawks, merlins, and bald
eagles winter in the basin.
The mourning dove is the common game bird in the area (Righter et al. 2004). Weedy plants
that usually invade after an area is disturbed provide food for mourning doves plus several
nongame birds, especially finches. Several of these "weed" species can actually be desirable in
that they fill in where a rehabilitation seeding fails to establish. By filling in these areas,
innocuous weedy plants help suppress noxious weeds, while feeding a list of wildlife species.
Examples are common sunflower (Helianthus annuus), stork's bill (Erodium cicutarium), kochia
(Bassia scoparia), and Russian thistle (Salsola kali). Canada goose, mallard, and other
waterfowl, plus American coot, may nest or forage in the right-of-way (ROW) near the pond in
Section 26 (T6S, R92W) and along Divide Creek and the draws east of the creek. The livestock
culture attracts wild turkeys out of the mountain shrub and Douglas fir habitat, south and east of
the area.
Other Wildlife
Widely distributed game species (small game, furbearers) include rock squirrel, mountain
cottontail, red fox and coyote; and along Divide Creek, beaver and mink. In addition to the birds
mentioned above, other non -game wildlife that characterize the area are Hopi chipmunk,
Woodhouse toad, northern leopard frog, western terrestrial garter snake, and various commonly
detected invertebrates, such as alfalfa and monarch butterflies. Speckled dace, fathead minnow,
creek and roundtail chubs, flannelmouth and white suckers, and possibly bluehead sucker swim
in Divide Creek. The frog and chub are Colorado State Species of Special Concern. Attachment
1 lists the wildlife species mentioned in this text.
PLANNED WILDLIFE MEASURES AND RATIONALE
Because the site is on native big sagebrush dominated ground, the proposed compressor station
would constitute the largest disturbance to natural vegetation (Figure 4). The proposed pipeline
route is along an existing ROW and would re -disturb vegetation in a lower successional state.
The fact that the ROW rehabilitation was successful over most of the route (Figure 5), suggests
that returning it to its current condition is a reasonable expectation. Because the compressor
station site would likely be occupied for a long time period, the possibility of returning it to
sagebrush cover after site closure is less certain.
WestWater Engineering Page 4 of 9 pages October 2007
Figure 4. Wyoming sagebrush park at the proposed Bailey Compressor
Station site (note that elk sign is abundant). The site is in a big game winter
concentration area, Garfield County, Colorado, October 2, 2007
Figure 5. Pipeline rehabilitation shows successful establishment of seeded
grass species in the mid -ground, yet poor establishment in the foreground,
Garfield County, Colorado, October 2, 2007
WestWater Engineering Page 5 of 9 pages October 2007
The most valuable sagebrush in this area should average greater than 18 inches high with a
canopy cover value greater than 18 percent, occupying stands larger than 18 acres (the "Rule of
Eighteens"). One or all three of the values in much of the sagebrush in the basin south of Silt are
less than this number. Mitigation for lost acreage of sagebrush lands should be pursued if
feasible. Inter -seeding desirable forb and grass species into sagebrush stands with a degraded
understory is a new and promising practice. Mowing or disking sagebrush is clearly not
recommended here. Young sagebrush plants are of less value to wildlife than mature plants.
Pinon juniper woodland (PJ) is, likewise, much reduced in this basin. The deer and elk foraging
area (sagebrush, pasture, cropland) to cover area (PJ) ratio is excessively high. Therefore, no
reduction in PJ to expand sagebrush is recommended. (See the Integrated Vegetation and
Noxious Weed Management Plan for the East Lateral Loop Project for specific vegetation
treatment and management plans.)
The stream crossing of Divide Creek requires a "404 Permit" from the U.S. Army Corps of
Engineers (COE). Whether the project will qualify for the "Nationwide Permit under #12 Utility
Activities" will have to be determined, e.g., the disturbance < 0.5 acre and < 500 ft long. To be
safe Barrett Corporation should notify the COE district engineer early in the planning stages to
simplify meeting any permit conditions. Whatever the type of 404 Permit this project will
operate under, it will contain stipulations for reducing the adverse effects of redistributing stream
bed material while making a pipeline crossing of the stream. Sedimentation of spawning gravels
could be a contributing cause of the decline of bluehead and flannelmouth suckers throughout
their ranges (Ptacek et al. 2005). Spawning requirements of the state species of special concern,
roundtail chub, are not known (Rees et al. 2005).
The development of the basin south of Silt by the petroleum industry undoubtedly has had and
will have increasing adverse effects on raptors, as with most other native wildlife species.
However, the effect of this one project on wintering raptors would not be measurable.
Conversely, impacts may well arise and be detectable during raptor nesting seasons. A raptor
survey in the spring of 2008 would provide the information needed to prevent nesting impacts.
Late April and early May is the optimum time to survey the area for nesting raptors. Since most
of the likely habitat is evergreen PJ woodland (Figure 6), observing nests would be difficult
without eliciting responses from nesting birds by using recorded call playback techniques. Two
visits should be adequate to survey the project route, a single day for diurnal raptors and one
night for owls. Suspending construction activities within a quarter mile of active nest sites is a
positive conservation action for raptors. Obscuring terrain may allow a closer approach to an
active nest. For great horned owls and American kestrels, merely avoiding the nest is sufficient.
For the other owls and hawks the quarter mile buffer applies and the period from March 15 to
July 15 is the sensitive time. The standard period for avoiding disturbance to golden eagles is
February 15 to July 15.
Construction should be scheduled around seasonally sensitive times to the extent possible. This
may be difficult. On public lands the acceptable work window may only be four months. Such a
period could start as late as August 1 (end of stipulated migratory bird nesting season) and end
December 1 (start of critical big game winter period). In the project area these four months,
August through November, are the optimum work months considering wildlife. If brushing out
WestWater Engineering Page 6 of 9 pages October 2007
Figure 6. Stitched photographs showing the pifion-juniper woodland in the mid -ground
through which the East Lateral Loop Pipeline is proposed to traverse, bending around
public land in Section 25 (T6S, R92W), Garfield County, Colorado, October 2, 2007.
of the line can be done outside the most critical bird nesting season, May 15 to July 15, the most
benefit can be achieved. Likewise, wildlife would benefit if the peak of construction activity
can avoid the critical time for deer and elk, December 1 to April 30. If the Divide Creek
crossing can avoid May through July, the fish spawning period would be protected. Table 2
displays the most critical periods for wildlife in the East Lateral Loop project area. As the
project advances, and if flexibility becomes urgent, it may be necessary to exercise calculated
flexibility to accomplish the work. In this case, the April 30 ending of the critical winter range
period can, in most years, retract two weeks to April 15 with fewer adverse effects than can the
migratory bird period be pushed to June 1. Also raptor nesting is more critical in the first half of
the season when nests are most likely to be abandoned due to disturbance (Richardson and Miller
1997).
Table 2. Seasonal limitations on construction work in the area of East Lateral Loop Project
Concern
Period
Deer and Elk severe (critical) winter range
December 1 — April 30
Migratory Birds primary nesting season
May 15 — July 15
Golden Eagle nesting
February 15 — July 15 (1/4 mile of nest only)
Hawks and Owls nesting
March 15 — July 15 (1/4 mile of nest only)
Native fish spawning
May 1 — July 31 (Divide Creek only)
Ideal construction periods
May 1 —15, July 16 —November 30
Compressor noise should be attenuated to the extent practical. While many species of wildlife
adapt to noise, there is a cost in failed detection and responses to natural sounds. There may also
be physiological deterioration (reduced fitness) due to increased metabolism, increased heart
rate, decreased auditory function, and other effects (Bromley 1985). Tolerance to noise rather
than avoidance by wildlife has resulted in significantly reduced productivity (Ingelfinger 2001,
Stone 2000, DOE 2001, Whittacker and Knight 1998). The goal for noise containment is <-60 dB
at 200 m in any direction from the compressor station pad.
Construction and service vehicle drivers should be encouraged to maintain modest speeds to
reduce the chances of striking wildlife on the road. Speed limit signs can be posted on company -
maintained roads where collisions with wildlife appear most likely.
WestWater Engineering Page 7 of 9 pages October 2007
Power lines, tall towers, vertical exhaust stacks, reserve pits and fences constitute potential
wildlife hazards that may accompany the project. If, or when, any potential hazard becomes a
feature of the project, it should be designed with standard wildlife safe elements following
consultation with specialists such as those at WWE.
A List of recommended mitigation measures for wildlife in this area is shown in Table 3.
Table 3. List of Mitigation Measures recommended for wildlife on the East Lateral Loop
Pipeline and Bailey Compressor Station Project
Mitigating Measure
Benefiting Wildlife
Seasonal scheduling (see Table 1)
big game, raptors, migratory birds, fish
Raptor survey
Raptors
Acquire "404" Permit from COE
four fish species in Divide Creek
Attenuate compressor noise
terrestrial wildlife
Reduce vehicular speeds on access roads
big game
Install wildlife -safe features on project
hazards as they are added to the project
Migratory birds, game, and nongame species
Use disturbance minimizing techniques
Wildlife (food and cover consideration)
Implement the Integrated Vegetation and
Noxious Weed Management Plan IVNWMP
Wildlife (food and cover consideration)
LITERATURE CITED
AOU. 1998. The American Ornithologists Union check -list of North American birds, seventh
edition. http://www.aou.org/checklist/index.php3
Bromley, M. 1985. Wildlife management implications of petroleum exploration and
development in wildland environments. In General Technical Report INT -191. U.S.
Forest Service, Intermountain Research Station, Ogden, Utah
Board of County Commissioners. 2006. Garfield County zoning resolution of 1978, amended
October, 2006. Board of County Commissioners, Building and Planning Department,
Glenwood Springs, Colorado, 78 pp.
Chapman, S. S., G. E. Griffith, J. M. Omemik, A. B. Price, J. Freeouf, and D. L. Schrupp. 2006.
Ecoregions of Colorado. Reston, Virginia: U.S. Geological Service (map scale
1:1,200,000).
DOE. 2001. Impact study of compressor noise on passerine birds [Web Page]. Project Fact
Sheet. Project ID: FEW 49263. Argonne National Laboratory for National Petroleum
Technology Office, Office of Fossil Energy, U.S. Department of Energy, Tulsa,
Oklahoma. 2 pp. Located at:
http://dominoweb.fossil.energy.gov/domino/apps/fred/fred.nsf/0/0a3af21 ed4aea81705256
b0900561281?OpenDocument. Accessed September 11, 2003.
WestWater Engineering Page 8 of 9 pages October 2007
Duff, A. and A. Lawson. 2004. Mammals of the world, a checklist. New Haven: Yale University
Press, 312pp.
Hammerson, G. A. 1986. Amphibians and reptiles in Colorado. Colorado Division of Wildlife,
131pp.
ingelfinger, F. M. 2001. The effects of natural gas development on sagebrush steppe passerines
in Sublette County, Wyoming. Thesis, University of Wyoming, Laramie.
Lyon, L.J. 1983. Road density describing habitat effectiveness for elk. Journal of Forestry,
81:592-596.
Opler, P. A. and A.B. Wright. 1999. A field guide to Western butterflies. New York: Houghton
Mifflin Company, 560pp.
Page, L. M., and 13. M. Burr. 1991. A field guide to freshwater fishes of North America north of
Mexico. New York: Houghton Mifflin Company, 432pp.
Ptacek, J. A., D. E. Rees, and W. J. Miller. 2005. Bluehead Sucker (Catostomus discobolus): a
technical conservation assessment. [Online] USDA Forest Service, Rocky Mountain
Region. Available: http://www.fs.fed.us/r2/projects/scp/assessments/blueheadsucker.pdf.
27pp.
Rees, D. E., J. A. Ptacek, and W. J. Miller. 2005. Roundtail Chub (Gila robusta): a technical
conservation assessment.
http://www.fs.fed.us/r2/pro j ects/scp/assessments/roundtailchub.pdf. 27pp.
Richardson, C. T. and C. K. Miller. 1997. Recommendations for protecting raptors from human
disturbance: a review. Wildlife Society Bulletin, 25(3): 634-638.
Righter, R., R. Levad, C. Dexter, K. Potter. 2004. Birds of western Colorado plateau and mesa
country. Grand Valley Audubon Society. 214 pp.
Stone, E. R. 2000. Separating the noise from the noise. A finding in support of the "niche
hypothesis", that birds are influenced by human induced noise in natural habitats.
Anthrozoos, 13(4): 225-231
Whittaker, D., and R. L. Knight. 1998. Understanding wildlife responses to humans. Wildlife
Society Bulletin 26(2): 312-317
WestWater Engineering
Page 9 of 9 pages October 2007
Attachment 1: Wildlife Species Mentioned in the Text
Group Common Name* Scientific Name* Habitat** Status
MAMMALS
American Beaver
Castor canadensis
Aquatic -Riparian
furbearer
Black Bear
Ursus Americanus
Garbage dumps+
Big game
Coyote
Canis latrans
Cosmopolitan
furbearer
Elk
Cervus elapbus
Winter Range
big game
Hopi Chipmunk
Tamias rufus
Rocky Piiion-Juniper
nongame
American Mink
Mustela visors
Aquatic -Riparian
furbearer
Mountain Cottontail
Sylvilagus nurtallii
Uplands
small game
Mule Deer
Odocoileus hemionus
Winter Range
big game
Red Fox
Vulpes vulpes
Cosmopolitan
furbearer
Rock Squirrel
Spernrophilus variegatus
Uplands
small game
BIRDS
American Coot
Fulica americana
Aquatic -Riparian
game waterbird
American Goldfinch
Carduelis triads
Ruderale/Riparian
nongame
American Kestrel
Falco sparverius
Cosmopolitan
raptor, nongame
Bald Eagle
Haliaeetus leucocepbalus
Cosmopolitan
winter raptor, nongame
Barn Owl
Tyto alba
Pastures
raptor, nongame
Bewick's Wren
Thryommnes bewickii
Pifion-Juniper
nongame, BOCC
Black -billed Magpie
Pica hudsonia
Cosmopolitan
nongame
Black -throated Gray Warbler
Dendroica nigrescens
Pinon-Juniper
nongame, BOCC
Brewer's Sparrow
Spizella breweri
Sagebrush
nongame, BOCC
Canada Goose
Branta canadensis
Aquatic -Riparian, Pasture, Cropland
game waterfowl
Cassin's Finch
Carpodacus cassinii
Pifon-Juniper
winter, nongame
Chipping Sparrow
Spizellapasserina
Pifion-Juniper
summer, nongame
Cooper's Hawk
Accipiter cooperii
Woodlands
summer raptor, nongame
Golden Eagle
Aquila chrysaelos
Cosmopolitan
raptor, nongame, BOCC
Great Horned Owl
Bubo virginianus
Cosmopolitan
raptor, nongame
House Finch
Carpodacus nrexicanus
Pinon-Juniper, Cliffs
nongame
Juniper Titmouse
Baeolophus ridgwayi
Pifion-Juniper
nongamc
Loggerhead Shrike
Lanius ludovicianus
Sagebrush
nongame, BOCC
Long-eared Owl
Asio otus
Woodlands, Tall Shrublands
raptor, nongame
Mallard
Anas platyrbynchos
Aquatic -Riparian, Pasture, Cropland
nongame
Merlin
Falco columbarius
Cosmopolitan
winter raptor, nongame
Mountain Bluebird
Sialia currucoides
Pifion-Juniper
summer, nongame
Mountain Chickadee
Poecile gambeli
Pinon-Juniper
nongame
Mourning Dove
Zenaida macroura
Cosmopolitan
summer, nongame
Northern Flicker
Colaptes auratus
Trees
nongame
Northern Goshawk
Accipitergentilis
Woodlands
winter raptor, nongame
Northern Harrier
Circus cyaueus
Pasture, Wetlands
raptor nongame, BOCC
Northern Pygmy Owl
Glaucidiumgnoma
Woodland, Tall Shrublands
winter raptor, nongamc
Northern Saw -whet Owl
Aegolius acadicus
Woodlands
raptor, nongame
Pine Siskin
Carduelis pinus
Ruderale areas
winter, nongame
Pifion Jay
Gytmrorhinus cyanocephalus
Pinon-Juniper
nongame, BOCC
Red-tailed Hawk
Buteo jarnaicensis
Trees
raptor, nongame
Rough -legged Hawk
Buteo lagopus
Pastures
winter raptor, nongame
Savannah Sparrow
Passerculus sandwichensis
Wetlands
migrant, nongame
Sharp -shinned Hawk
Accipiterstriatus
Woodland, Tall Shrublands
raptor, nongame
Song Sparrow
Melospiza tnelodia
Riparian areas
nongame
Swainson's Hawk
Buteo swainsoni
Pastures
raptor, nongame
Western Meadowlark
Sturneea neglecla
Pasture, Open Shrublands
summer res., nongame
Western Screech Owl
Megascops kennicoltii
Woodlands
raptor, nongame
Western Scrub Jay
Apbeloconuz californica
Pinon-Juniper, Tall Shrubland
nongame
White -breasted Nuthatch
Sitta carolinensis
Pifion-Juniper
nongame
Wild Turkey
Meleagris gallopavo
Pasture
upland gamebird
Wilson's Snipe
Gallinago delicata
Wetlands
game shorebird
Yellow-rumped Warbler
Dendroica coronata
Cosmopolitan
migrant, nongame
WestWater Engineering
Attachment 1
October 2007
Attachment 1: Wildlife Species Mentioned in the Text
Group Common Name* Scientific Name* Habitat** Status
REPTILES
Western Terrestrial Garter Snake Thmmsophis elegaas Near surface water nongame
AMPHIBIANS
Northern Leopard Frog
Ranapipieru'
Aquatic -Riparian
state species of special concern
Woodhouse Toad
Bufo woodl�ousei
Aquatic -Riparian
nongame
FISH
Bluehead Sucker
Catostoams discobolus
Aquatic
nongame
Flannelmouth Sucker
Catostoams latipinnis
Aquatic
nongame
White Sucker
Aquatic
exotic rough fish
Creek Chub
Simollus atromaculatus
Aquatic
exotic rough fish
Roundtail Chub
Gila robusta
Aquatic
state species of special concern
Speckled Dace
Rhinichthys osculus
Aquatic
nongame
Fathead Minnow
Pimephalespromelas
Aquatic
uncertain
INSECTS
Monarch Butterfly
Danausplexippus
Riparian, Ditch banks
unclassified
Alfalfa Butterfly
Collas eurytheme
Hayfields, Ruderale areas
unclassified
* Names follow that of Duff and Lawson 2004; The American Onithologist Union check -list of North American Birds, 7th Ed
with its supplements (AOU 2007) to; Hammerson 1986; Page and Bun 1991; and Opfer and Wright 1999.
**Habitat that is most significant to the species in project area
WestWater Engineering Attachment 1 October 2007
Bill Barrett Corporation
EMERGENCY
RESPONSE
PLAN
1099 18th Street, Suite 2300
Denver, CO 80202
June 2007
Table of Contents
1. Introduction Support
II. Injury / Illness Alert Procedure
11I. Spill Procedure
IV. Other Incidents
V. Emergency Levels
VI. Communication / Evidence
VII. HAZWOPER
VIII. H2S Contingency Plan (if applicable)
IX. General Telephone Numbers
X. Area Specific Telephone Numbers -Including
Hospital and Emergency responders
I. Introduction
Serious incident situations, unless properly controlled, can result in loss of
life and damage to public or private property. Situations resulting from
spills can generate complex technical, legal and public relations problems.
It cannot be overemphasized that the best way to handle emergency
situations is to prevent their occurrence.
This Plan is designed to help Bill Barrett Corporation (BBC) respond
quickly and effectively to the problems presented by serious incidents
when they do occur. The Plan's primary goal is to help the company
prevent, as far as practical, any loss of life or damage to property, wildlife,
or the ecology.
Within this Response Plan you will find descriptions of the duties that must
be accomplished when a serious incident occurs. It provides personnel
with procedures for handling such incidents effectively.
The Plan is prepared:
1. To serve as the basis for an organized action plan in dealing with
emergencies and spills of all magnitudes.
2. To spell out responsibility, priority and importance in countering an
emergency situation or major spill.
3. To provide information on the means of handling serious incidents and
identify the organizations that are involved.
4. To tabulate the personnel and agencies that must be notified.
Prompt action is mandatory. For this reason, the content of this Plan must
be understood by the persons who may have need of it. All involved
employees should be informed to take quick action to protect life and
property and to immediately report the incident.
The plan will require modification from time to time, as personnel change,
as technologies advance, and as experience indicates improvements.
The plan is to be reviewed annually by the EH&S staff to assure that it is
up to date.
This plan is not intended to replace existing SPCC or other required Plans,
but rather its purpose is to be a supplement providing general guidelines
for emergency situations.
Bill Barrett Corporation
Incident Leader
Appropriate VP and
ER Facilitator
EH&S
On Site Incident
Leader
Operations
Field Operations
Legal
Logistics
Communications
Security
Finance
EH&S
Human Resources
Note: Depending on the nature of the incident, multiple roles may be provided by one person.
RESPONSE TEAM
INCIDENT LEADER
1. Calls meeting of appropriate members to evaluate the incident.
2. Develops plan of action in conjunction with Team members.
3. Designates Field Response Team.
4. Implements Response Plan through delegation to appropriate members.
5. Monitors progress and ensures appropriate support activity.
6. Notifies Senior Vice President and EH&S Manager.
ON-SITE INCIDENT LEADER
1. Leads Field Response Team and designates members and
responsibilities.
2. Reports serious incident/spill to Incident Leader.
3. Preserves evidence at site.
4. Coordinates and directs contractor efforts.
5. Direct engineering efforts and acts in advisory capacity.
6. Sets priorities for onsite activities.
7. Keeps Incident Leader informed of status of operations.
8. Documents activities and personnel at incident site.
9. Coordinates efforts with other operational functions.
FIELD OPERATIONS
1. Provides relief for the Field Superintendent.
2. Operations Support Technician may provide specific area EHS Technical
Support and information.
3. Assists in non -associated daily operations.
OPERATIONS
1. Establishes communications.
2. Ensures provisions for incident security.
(a) Incident site
(b) Field operations site
(c) Command center
(d) Staging areas
(e) Warehouses
(f) Other facilities as necessary
3. Claims and Right -of -Way Representative:
(a) Responds to damage claims and obtains access and right-of-ways as
necessary.
4. Operations Engineering:
(a) Provides engineering support as needed.
5. Documentation Coordination:
(a) Provides additional secretarial support as needed.
(b) Collects and maintains logs from all team members.
LOGISTICS
1. Schedules and provides for support needs to the response effort.
2. Alerts major service contractors of incident and activities as necessary to
support needs.
SECURITY
1. Establishes procedure to ensure authorized personnel vehicles access to
secured facilities.
2. Arranges for security.
3. Coordinates security operations with local law enforcement and other
government security agencies.
4. Maintains a record of all visitors to secured facilities.
EH&S - Incidents
1. Investigates incident.
2. Provides health and safety guidance to on-site employees.
3. Develops the Site Safety Plan.
4. Provides necessary regulatory reporting.
5. Acts as liaison with regulatory agencies and Legal Dept..
6. Coordinates operations conducted by Federal, State, Local agencies and
contractors.
7. Prepares initial reports to agencies as required.
8. Advises the Incident Leader and Team of regulatory considerations.
EH&S - Spills
1. Directs all spill clean-up activities and implementing the overall clean-up
strategy.
2. Decides initial start-up strategy with the Incident Leader.
3. Obtains weather information.
4. Develops recommendations and plans for keeping oil away from sensitive
areas.
5. Discusses availability of clean-up equipment with logistics.
6. Discusses transportation resources available.
7. Initiates Federal, State, and Local agency notifications.
LEGAL
1. Review potential legal consequences.
2. Alert and instruct Incident Leader(s) of potential legal consequences.
3. Alert Senior Vice -President of potential legal consequences.
4. Work with Human Resources, EH&S and Operations on incident issues.
HUMAN RESOURCES
1. In the event of personal injuries or fatalities:
(a) For BBC employee, initiates and maintains family contact.
(b) For contractor personnel, initiates and maintains contact with their
employer.
Maintains whereabouts and condition of injured
FINANCE
1. Establishes necessary controls to validate labor, equipment, materials,
consumables, etc. chargeable to the response.
2. Handles insurance filings.
3. Provides effective accounting, cost control, and office support functions for
the response operations.
Bill Barrett Corporation
Emergency Response
Incident Notification Procedure
SPILL
Employee
(First Onsite or
First Made Aware of Incident)
TAKE NECESSARY
STEPS TO SAFELY
STOP SPILL SOURCE
AND/OR PREVENT
FURTHER MIGRATION
OF SPILL
CONTACT ADDITIONAL
SERVICES TO RESPOND
AS NECESSARY
SECURE SITE
NOTIFY AREA
SUPERINTENDENT
OR DRILLING
FOREMAN AS
APPLICABLE
SERIOUS ACCIDENT,
INJURY OR ILLNESS
SAFELY ADMINISTER AID
AS QUALIFIED AND CALL
OR ASSIGN PERSONNEL
TO CALL EMERGENCY
SERVICES
AREA SUPERINTENDENT
OR DRILLING FOREMAN
(AS APPLICABLE)
NOTIFY EH&S
PERSONNEL AND
TEAM LEADER
4
OBTAIN ADDITIONAL INCIDENT
INFORMATION AND PROVIDE
INSTRUCTIONS TO ONSITE
PERSONNEL AS QUALIFIED
NOTIFY APPROPRIATE
TEAM MEMBERS AND
SENIOR MGT PERSONNEL
DEPENDING ON INCIDENT
LEVEL (1, 2, or 3)
SEE INCIDENT LEVEL DEFINITIONS
BELOW
WORK WITH TEAM
MEMBERS AND EH&S TO
REMEDY INCIDENT
EH&S NOTIFIES LEGAL
DEPT. AND
REGULATORY
AGENCIES AS
APPROPRIATE
TEAM LEADER
ENSURE THAT EMERGENCY
SERVICES HAVE BEEN
CONTACTED AND HAVE
INCIDENT AND LOCATION INFO.
SECURE SITE
1
NOTIFY EH&S
PERSONNEL AND
TEAM LEADER
4
OBTAIN ADDITIONAL INCIDENT
INFORMATION AND PROVIDE
INSTRUCTIONS TO ONSITE
PERSONNEL AS QUALIFIED
NOTIFY APPROPRIATE
TEAM MEMBERS AND
SENIOR MGT PERSONNEL
DEPENDING ON INCIDENT
LEVEL (1, 2, or 3)
SEE INCIDENT LEVEL DEFINITIONS
BELOW
1
WORK WITH TEAM
MEMBERS AND EH&S TO
REMEDY INCIDENT
11. Injury/Illness Alert Procedure
1. The employee at the scene who is most qualified to do so will render first aid
or assistance and assign personnel to call emergency services and notify the
Area Foreman/Superintendent.
2. The Area Foreman/Superintendent will obtain details of the incident, assure
that emergency services have been called, notify the Team Leader and EH&S
Manager and direct further on-site activities. Notification will include, at a
minimum, the following:
• Date and time of incident.
• Location of incident (with directions to site).
• Description of incident and nature of injuries.
• Location where injured employee was moved to.
• Identity of emergency services present at site.
• Other considerations (media attention, regulatory agencies at site, etc.)
3. The Team Leader will notify the appropriate Senior Management personnel
and Response Team members.
4. The EH&S Manager will notify appropriate regulatory agencies and the Legal
Department. If the EH&S Manager is unavailable, the Response Team
person in charge of the incident will refer the reporting responsibility to the
Legal Department.
5. If necessary, the Incident Leader will call a meeting of other appropriate
members to assess the size and circumstances of the incident and develop a
plan of action.
6. The Area Superintendent or his designee will act as on -scene coordinator,
with action by Response Team members directed by the Team person in
charge of the incident.
See Section V for emergency level guidance.
• In the event that any of the above mentioned persons are unavailable,
the normal next step in the chain of command should be contacted.
Bill Barrett Corporation
INTERNAL INCIDENT REPORT -SERIOUS INJURY OR ILLNESS
CALLER INFORMATION
Name: Location: Phone:
INCIDENT
Date: Time: a.m./p.m.
Segment Lease
Directions from Nearest Town:
Person in charge at the scene:
DESCRIPTION
What happened:
PROPERTY DAMAGE/AREA AFFECTED
Describe:
INJURIES/ILLNESS
Name (& Company if Contractor)
Extent of Injury
Hospital Taken To
STATUS
Action Taken:
Authorities Notified or at Site:
Media Attention/Name:
DOCUMENTATION
Person Receiving Call:
Persons Notified:
Date: Time: a.m./p. m.
Date: Time:
Date: Time:
Date: Time:
a.m./p.m.
a.m./p. m.
a.m./p. m.
Bill Barrett Corporation
SUPERVISOR'S REPORT OF INCIDENT (SRI
Use this form to report at on the job injuries or lines
experienced by employees, contractors or visitors
Incidents involving serious injury or illness should be
reported by telephone to the local EH&S Dept.
immediately.
INCIDENT DESCRIPTION
❑ Employee ❑ Visitor
❑ Contractor ❑ Other
CASE NUMBER
1.
LOCATION
Organizational/Facility/Department
Address
Phone Number
IDENTIFICATION
Name
Social Security Number
Date of Birth
Sex
•
0
M
Regular Job Title
Years on this Job Classification
Hire Date
REPORTED
TO SUPERVISOR
Date
Time ❑ AM
❑ PM
Name/Title of Person Taking Report
Signature
DRUG/ALCOHOL
TESTING
Date
Time
• AM
❑ PM
Reason if NOT Tested
2.
INDIVIDUAL'S
STATEMENT
(When, how,
where, what)
SIGNATURE
DATE
3.
ONSET OF
SYMPTOMS, ACCIDENTS,
INJURY , OR
EXPOSURE
Date
Time 0 AM
❑ PM
Location
On Work Premises?
D YES 0 NO
Witnesses
Time Shift Started
Equipmen Object, or Substance
Involved
Body Parts Affected
Work Activity
Immediate Supervisor at Time of Onset
4.
CATEGORIZATION
PART B - Update any
information that has
changed since Part A
Submitted
Was a medical procedure performed
(stitches, splinting, foreign body removal?) 0
Yes 0 No
Did the individual die? ❑ Yes 0
No
If yes, give date
Did X-rays indicate a crack, fracture,
or dislocation? 0
Yes 0 No
Did individual lose consciousness?
•
Yes •
No
Was prescription medication given?
(more than a single dose?) 0
Yes • No
Was individual's work modified
or schedule changed? • Yes 0 No
If yes, estimate total days
Were there burns with blisters or loss of skin? ❑
Yes 0 No
If Yes, indicate size
Was individual absent the next scheduled shift or
subsequently? 0 Yes
If yes, estimate total days _
• No
Was repeated therapy with hot packs, cold packs,
whirlpool, or other physical therapy given?
Yes 0 No
•
Management Signature
5.
PERSON COMPLETING
THIS SECTION
Date
Phone Number
Name/Position
Signature
III. SPILL ALERT PROCEDURE
1. The employee discovering the spill (or first at the spill site) will:
A. Take actions to safely stop the release, contain it to the location, and
prevent the spill from reaching surface water.
B. Notify the Area Foreman/Superintendent and the EH&S Dept., giving
details of estimated volume spilled, status of discharge, and other
details that will facilitate response and clean-up.
2. The Area Foreman will:
A. Mobilize material, equipment, and manpower to stop, contain, and
clean up the discharge of the spill.
B. Report spill to the Team Leader and EH&S Dept. (if EH&S not already
notified).
3. The Team Leader will notify the Senior Management personnel and
appropriate Response Team members.
4. EH&S will:
A. Notify appropriate regulatory agencies and Legal Dept.
B. Complete the appropriate incident reports.
C. Provide remediation guidance.
If EH&S is unavailable, the Response Team person in charge of the
incident will notify the Legal Dept. for regulatory agency notifications.
5. If necessary, the Incident Leader will call a meeting of other appropriate
members to assess the size and circumstances of the incident and
develop a plan of action.
6. The Area Superintendent or his designee will act as on -scene coordinator,
with action by Response Team members directed by the Team person in
charge of the incident.
See Section V for emergency level guidance.
Notes:
a. For guidance of the proper handling and disposal of wastes, contact
EH&S Dept.
b. In the event that any of the above mentioned persons are unavailable, the
normal next step in the chain of command should be contacted.
c. All spills (crude oil, condensate, produced water, hazardous chemicals or
E&P waste) > one barrel or any volume that affect surface water or ground
water need to be reported to the Area Foreman and EH&S Dept.
immediately.
d. What is "surface water (Navigable Waters")? In addition to ponds, lakes,
streams, and rivers, "surface water (or navigable waters)" can be defined
as dry ditches, irrigation canals, wetlands, sloughs, and any other natural
or man-made surface feature that contains water at least part of the time.
e. No smoking shall be permitted within a minimum of 150 feet of free
product, condensate or sources of natural gas.
See Section V for emergency level guidance.
Bill Barrett Corporation
INTERNAL SPILL REPORT
Location
(Well, Sec., Twn, Rng, County)
Date/Time Spill
Discovered &
Reported to Supervisor
Person Who Discovered and
is Reporting Spill
Quantity Spilled
(BBLs or Gallons)
Produced Water
Methanol
Other
(Describe)
Quantity
Recovered
(BBLs or Gallons)
Produced Water
Methanol
Other
(Describe)
What was the
source and cause of
the spill?
How was the
problem fixed?
Was there a fire or
explosion?
What distance and
direction did spill travel?
Did the spill leave the
well pad or tank battery?
Describe, including a
diagram on the back
side of this form.
Did the spill reach any
natural or man-made
surface water (navigable
water) feature?
Describe, including
notation of any oil or
sheen on water.
Were regulatory or
emergency officials
notified? If so, who was
contacted, by whom,
and at what time?
Describe actions
taken, using the
back of this form, if
necessary.
SPILLS
NOTIFICATIONS
The EH&S Dept. reports, as necessary, to the appropriate Government Agencies
and obtains services from various Contractors.
REGULATORY AGENCIES
OFFICE
MOBILE
OTHER
WOGCC
307-234-7147
WDEQ-WQD/AQD
307-777-7781/7391
WY-BLM
307-261-7600
UDOGM
801-538-5340
UDEQ-WQDIAQD
801-536-410014000
UT-BLM
(435) 636-3600
CO-BLM=970-947-2800
COGCC
303-894-2100
CDPHE
303-692-2000
Garfield County O&G Liason
970- 625-07790
(970) 309-5441m
ND-IC/OGD
701-328-8020
NDDEH-EHS
701-328-5210
N D-BLM
701-225-9148
M T-BLM
406-232-7000
MT -OG
406-656-0040
MT-WQD
406-444-6911
NRC
800-424-8802
EPA Region VIII
800-277-8917
CONTRACTORS
OFFICE
MOBILE
OTHER
Buys & Assoc. (air)
303-781-8211
303-809-2427
Chenoweth & Assoc. (reclamation)
303-833-1986
Mike Brady - MBC (construction)
970-285-9508
970-250-8188
Cordilleran (remediation)
970- 263-7800
Custom Envir Svcs (24hr-ER)
303-423-9949
800-310-7445 (24 hr)
Striegel Pipeline Construct.
970-675-8444
970-629-2940
BLM: UNDESIRABLE EVENT REPORTING REQUIREMENTS
Major Events:
Must be reported orally to the appropriate District Engineer as soon as practical but
within a maximum of 24 hours. A written report must be submitted within 15 days.
A. Oil, saltwater, and hazardous material spills or any combination thereof,
which result in the discharge (spilling) of 100 or more barrels of liquid.
B. Equipment failures or other accidents which result in the venting of 500 MCF
or more of gas.
C. Any fire which consumes the volumes specified in A and B above.
D. Any spill, venting, or fire, regardless of the volume involved, which occurs in a
sensitive area, e.g., parks, recreation sites, wildlife refuges, lakes, reservoirs,
streams, and urban or suburban areas.
E. Each accident which involves a fatal injury.
F. Every blowout (loss of control of any well) that occurs.
Other -Than -Major Events
Written report must be submitted within 15 days.
A. Oil, saltwater, and toxic liquid spills, or any combination thereof, which result
in the discharge (spilling) of at least 10 but less than 100 barrels of liquid in
non -sensitive areas.
B. Equipment failures or other accidents which result in the venting of at least 50
but less than 500 MCF of gas in non -sensitive areas.
C. Any fire which consumes volumes in the ranges specified in A and B above.
D. Each accident involving a major or life-threatening injury.
Spills or discharges in non -sensitive area involving less than 10 barrels of
liquid or 50 MCF of gas do not require an oral or written report; however, the
volumes discharged or vented as a result of all such minor incidents must be
reported on the Monthly Report of Operations (Form 9-329). The Volume and
value of such losses must also be reported in the Monthly Report of Sales
and Royalty (Form 9-361).
IV. Other Serious Incidents
• Damage to company, contractor or general public property
• Fires and Explosions
• Business Interruption/Civil Disturbance
• Government inspection with civil or criminal sanctions
• Adverse publicity and media attention
• Well blow out
• Security Incident / Bomb Threat
• Gaseous releases of hazardous materials
• Severe Weather
1. The employee first aware of the incident or who is first on the scene will
render assistance if necessary or call for emergency services if appropriate.
Steps should then be taken to correct the problem or reduce the spread or
magnitude of the situation only if it is safe to do so. The employee will then
notify the Superintendent/Area Foreman.
2. The Superintendent/Area Foreman will obtain details of the incident, notify the
Team Leader and EH&S Dept. and direct further on-site activities.
Notification will consist of appropriate information to adequately convey the
nature, size and circumstances of the incident and develop a plan of action.
3. The Team Leader will notify the Senior Management personnel and
appropriate Response Team members. EH&S will notify the Legal Dept.
4. If necessary, the Incident Leader will call a meeting of other appropriate Team
embers to assess the size and circumstances of the incident and develop a
plan of action.
5. The Superintendent/Area Foreman and/or designee will act as on -scene
coordinator(s), with action by Response Team members directed by the
Team person in charge.
* In the event that any of the above mentioned persons are unavailable, the
normal next step in the chain of command should be contacted.
* See Section V for emergency level guidance.
24 -Hour Reporting System
In order to facilitate notification of staff functions, a 24-hour serious incident
notification system is in place.
The intent of the system is to provide for a timely and accurate notification of
the staff divisions in the event of incidents which may put the Company at
risk. It is designed to minimize the company's exposure and make sure all
the necessary parties are informed.
BBC CONTACT LIST
OFFICE
MOBILE
HOME
Fred Barrett - Pres/COO
303-312-8108
303-887-5430
303-421-7780 - Patty
Joe Jaggers-Pres ICOO
303-312-8101
Kurt Reinecke-VP So. Ops
303-312-8113
303-884-2483
303-989-7190 - Lorraine
Terry Barrett -- VP No. Ops
303-312-8110
303-881-1011
303-423-9785 -Sharon
peter Moreland -YellowJacket Leader
303-312-8141
Hollis Bairrington-PRB &CO Team Lead
303-312-8179
303-345-1299
303-439-0122 - Sandi
Duane Zavadil-VP Regulatory
303-312-8128
303-638-1265
303-660-1145 -Glenda
Scot Donato -Mgr EH&S
303-312-8101
303-810-4875
303-617-9987 -Judy M.
Jim Felton - Public Relations
303-312-8103
303-881-0840
970-668-1624 - Janet
Troy Schindler -Drilling Mgr
303-312-8156
303-249-8511
303-740-8507 - Kathryn
Dave Ault -Drilling Coord.
303-312-8143
303-842-6464
Francis Barron -General Counsel -Legal
303-312-8515
303-520-7411
303-756-6335 - Tamara
Dave Scobel-Facilities
303-312-8115
303-324-6135
303-582-3263 -Jessica
George Hartman -Construction Field
307-258-7901
Taryn Frenzel -Completions
303-312-8559
303-241-2247
Chris Bairrington-COINDIMT
303-312-8511
303-877-5239
303-450-3029 - Shana
John Shepard - WY
303-312-8167
303-877-2952
303-680-5306 - Susan
Monty Shed -COLO Supervisor
970-285-9061
307-262-1511
- Ann
Jesse Merry (24HR)
970-285-9061
970-230-0436
V. Emergency Levels
Level 1
(Lowest Level):
Incident which can be effectively managed within the Region without
activating the Emergency Response System. Notification to Sr. Vice
President determined by the nature of the incident.
1. An incident without fire, recordable injuries, public involvement or adverse
media involvement.
2. Oil spills to water equal to or less than one barrel.
3. An incidental release of a substance which can be absorbed, neutralized, or
otherwise controlled at the time of a release by employees in the immediate
area and that does not pose a potential safety or health hazard or threat to the
environment and is not immediately reportable to any government agency.
4. Property Damage Less than $50,000.
Emergency Levels (cont)
Level 2
(Intermediate Level)
Incident which requires notification to the Sr. Vice President.
Corporate notification determined by the nature of the incident.
Activate Emergency Response Teams as appropriate.
1. Incidents involving recordable or serious injury to employees, dependents,
contractors, or the public as a result of Company activities.
2. Any other incident or situation which may create a serious risk to life,
property, or the environment.
3. Oil spills to water greater than one barrel, releases, explosions, fires, or other
incidents that are required to be immediately reported to any government
agency.
4. Property Damage from $50,000 to $100,000.
5. Incidents that may expose the Company to significant liability whether
employees are involved or not (e.g. vehicle accident).
6. Fines, penalties, administrative orders, etc., received from any government
agency.
7. Fires which are controlled and immediately extinguished.
8. Any event that affects the public, or is likely to attract adverse media
coverage.
9. Incidents that affect others which are a concern for the Company (e.g.
helicopter, marine, or facility incidents involving other operators) .
10. Natural Disasters.
11. Severe Weather Events.
Emergency Levels (cont)
Level 3
(Highest Level)
Incidents which require notification to all levels of management.
Emergency Response Teams may be activated depending on
the nature of the incident.
1. Death or injury to any person which has a substantial risk of permanent
disability or impairment.
2. Major spills, toxic gas releases, or other significant environmental
damage.
3. Blowouts.
4. Fires not immediately controlled and extinguished.
5. Property damage greater than $100,000.
6. Incidents that have potential for national/international media coverage.
7. Incidents that could significantly impact the Company's cash flow and/
or financial performance.
VI. Communication / Evidence
It is important when an emergency is identified that notification to an
employee's supervisor is made as soon as possible. It is mandatory that
notices be given internally as soon as practical. Notification will follow the
reporting hierarchy for BBC.
The first person to identify the emergency will report it to his/her supervisor. If
a person's supervisor cannot be immediately reached with the known contact
(i.e. telephone numbers of home, office, portable phone, or pager) then the
next person on the list must be notified. At each notification, instructions may
be received to be implemented. Each person receiving notification then is
responsible for contacting up the chain of command. Notification to
regulatory authorities should be made only after discussion the situation with
the Senior onsite BBC Supervisor.
Communication Techniques
1. Communication must be through a two-way confirmed means. Use of
messages on a voice recorder or answering machine does not constitute
notification. A message may be left, but the next person up the chain of
command must be contacted.
2. If a line is busy, advise the operator that you have an emergency and get
the operator to interrupt the line.
3. Make sure the person you are communicating with understands you. This
can be done by asking them to repeat key parts of your discussion.
4. If you are calling someone you do not frequently talk to, make sure you
identify yourself and where you can be reached.
5. If working with a radio communication, call out the person you want to talk
to followed by your name (E.G. "Kurt, this is Greg, do you read meT)
Wait long enough for a response. The person may be away from the radio
and may need some time to get back,
6. If calling by telephone, let the phone ring at least six times before hanging
up.
7. Do not hesitate to call above your supervisor if your supervisor is
unreachable.
8. Have relevant information available before starting notification. This does
not mean a complete report of everything, but as a minimum the following:
A. Location or facility and call back phone number
B. Type of emergency.
C. Time and date first noticed.
D. Magnitude of emergency (e.g. size of fire or spill, number of people
involved, injuries, if other properties or companies are involved).
E. What you have done prior to making your notification.
F. What your plans are in responding to the emergency.
G. What are the weather conditions?
H. What, if any, outside notifications have been made.
I. What assistance you need.
J. When you will call back with a subsequent report.
Communication Equipment
The primary means of communications will be by telephone and radio.
Field operations that are Company operated will utilize two-way radio(s)
communications and/or mobile telephones. Communications are designed to
allow supervisors to be in contact with the Region office.
Drillings rigs are usually equipped with either radio systems that communicate
with the drilling contractor or mobile telephones. All drilling locations will have
some means of two-way communications either onsite or within a 15 -minute
drive (all types of weather).
Community/Public Affairs
Communication and public affairs are best handled by persons trained in
dealing with the media. There will be times when it is not practical to refer all
questions from the media and public to our headquarters. Indeed, a factual,
short response can help reduce the time and effort ultimately needed to
respond to the media and public.
The senior ranking BBC onsite employee or his/her designate, if approached
for a statement, may respond to questions from the media. The response
should be a short statement of the facts. Estimates or speculations as to
cause or size of the problem must not be made. Information requests for
more than the facts relating directly to the immediate emergency (such as our
future plans, amount of damage, what other hazards might exist, previous
inspections done at the facility, any citations we may have received, etc.)
should be referred to Jim Felton (or other designated personnel). If you are
going to be questioned in front of a camera, consider your appearance and
what will be in the background (behind you) of your interview. If possible,
your interview should be done with a neutral or non -threatening background.
It must be emphasized to provide only the facts. Assume any camera or
recorder in the area is ON at all times (it just may be). Encourage the media
to speak with Jim Felton in the Denver office for any detailed information.
Preserving the Evidence
In the aftermath of a serious incident, it becomes necessary to investigate the
incident in order to determine cause and corrective actions. Perhaps the
most important aspect of this investigation is determining the facts, and as
such, the preservation of the evidence is of great importance.
With the assistance of personnel involved at the incident scene, the evidence
can be preserved and a more beneficial investigation performed. The
following are basic guidelines which should be followed:
1. Secure the Area
Rope off or other control access into the incident site. Access by non -
company personnel allowed only after management approval. The only
exception being necessary access by emergency medical rescuers and
fire fighters.
2. Preserve the Evidence
As much as possible, don't disturb objects relating to the incident. If
unavoidable, stake or mark its location and record what was there. Never
allow evidence to leave the scene with out approval.
3. Document the Evidence
The IncidentLeader is responsible for preserving all documentation until
the investigator(s) arrive at the scene.
4. Identify Witnesses
If persons who witnessed the incident cannot remain on the scene to be
interviewed during the investigation, get their names and pertinent
information so that they can be located later.
VII. HAZWOPER
INDEX
• Introduction
• HAZWOPER Plan Narrative
A. Pre -Emergency Planning
B. Personnel Roles and Line of Authority
C. Evacuation, Safe Distances, and Places of Refuge
D. Employee Safety During a Hazwoper Response
E. Response Evaluation & Follow -Up
HAZWOPER
Introduction
HAZWOPER stands for "Hazardous Waste Operations and Emergency
Response". HAZWOPER is a regulation designed to establish a
management plan for emergencies involving hazardous materials. It is
applicable to oil field operations primarily through the regulations addressing
emergency responses to hazardous substance releases.
HAZWOPER defines an emergency response, or responding to emergencies,
as a response effort by employees from outside the immediate release area
or by other designated responders (e.g., local fire departments, mutual -aid
groups, designated HAZMAT Team, etc.) to an occurrence which results or
potentially results in an uncontrolled release of a hazardous substance.
For the purposes of this plan, the term "immediate release area" has been
defined as encompassing the Superintendent's/Area Foreman's geographical
area; therefore, if an emergency situation can be mitigated by Kerr-McGee
Company personnel, it is not a HAZWOPER Emergency. In the event that an
uncontrolled release requires the response of specially trained emergency
teams to stop or control the release (e.g. Fire Department, Department of
Health Services, etc.), it is a HAZWOPER response and the procedures in
this section of the "Response Manual" must be followed.
HAZWOPER Plan Narrative
A. Preplanning Response Actions
Preplanning is the key to a successful emergency management plan.
Planning is handled through the training of company employees,
formulation of emergency response activities, and pre -planned
coordination with outside emergency responders. The following items
constitute BBC's preplanning actions.
All employees will be trained in Hazard Communication and Emergency
Response. This includes hazardous material container labeling, access
to, and understanding Material Safety Data sheets, and responding to
emergencies involving hazardous materials. Specific emergency
scenarios and appropriate responses will be discussed in these training
sessions. All field employees will receive training to a minimum of "First
Responder Operations Level", as defined by HAZWOPER.
In the event of a HAZWOPER emergency, response activities will be
coordinated with contract companies trained to respond to HAZWOPER.
The names of these companies and their emergency numbers can be
found in Section 9 and 10 of this Emergency Management Plan.
B. Personnel Roles and Lines of Authority
If an incident is classified as a HAZWOPER response, the Superintendent/
Area Foreman responsible for the facility requiring the response shall
supervise BBC personnel in emergency response activities and perform
all reporting requirements pursuant to this Emergency Response Plan.
He/she will continue to perform these duties until such time as the
responding Emergency Response Team arrives.
Upon the arrival of the trained Emergency Response Team, the ranking
official of said team will be designated as the Incident Leader. After that
point, all emergency response activities will be conducted under the
direction of the Incident Leader.
C. Evacuation, Safe Distances, and Places of Refuge
Evacuation - The open air nature of oil and gas operations generally
permits numerous safe evacuation routes. In areas where this is not the
case, employees are directed to attempt escape along a route that takes
them upwind of an incident. Crosswind escape is suggested only until
upwind escape is appropriate. Wind direction indicators are installed on
all properties that contain H2S gas.
Safe Distances - Prior to the arrival of the Incident Leader mentioned in
Section B, the Superintendent/Area Foreman or designee shall be
responsible for establishing the distance from the hazardous scene. After
the Incident Leader arrives on the scene, safe distances will be
established at his/her discretion.
Places of Refuge should be established as appropriate for BBC
operations.
D. Employee Safety During a HAZWOPER Response
All field employees will be trained to a minimum of "First Responder
Operations Level". This training insures that the employee can operate
certain equipment on the property during an emergency in order to bring
the emergency condition under control. In the course of these operations
the employee may be exposed to a hazardous environment, become
injured, or have his/her clothing become contaminated with a hazardous
material. The following items will address these issues.
Personal Protection Equipment (PPE) is available to every employee.
The type of equipment available to the employee will vary depending on
the hazards inherent in the subject work area. Selection, safe use,
limitations, maintenance, care and storage will be thoroughly covered in
employee training. The Company's policies and procedures pertaining to
PPE are found in the EH&S Manual located in each area office.
Employee training will include provisions for initial and periodic refresher
training.
Emergency Medical Services will be provided by local hospitals, urgent
care centers, and fire departments. Services have been identified in
Section 10 of this Emergency Response Plan and are listed by BBC
operating area name.
Decontamination of clothing equipment will be coordinated with BBC
EH&S staff. The MSDS will be consulted for proper disposal of
contaminated items.
E. Response Evaluation & Follow -Up
An Emergency Response Review Committee has been established for the
management and review of BBC's emergency responses. After a
HAZWOPER response has occurred, the Emergency Response Review
committee will submit a report to management discussing the emergency
response. A copy of this report will be kept in the files.
The Emergency Response Review Committee:
• Operations/Area Manager
• Environmental, Health & Safety Manager
• Superintendent/Area Foreman
The report will identify:
• Nature and Cause of emergency
• Statistics pertaining to emergency (i.e. damage, injuries, etc.)
• Effectiveness of Company Emergency Response Personnel
• Corrective Measures taken to prevent recurrence of similar
emergency at this location (considering applicability to other
locations)
DWELLINGS, OFFICES, ETC.
LOCATION PHONE NUMBERS
SEE SECTION 10 FOR AREA SPECIFIC INFORMATION.
COLORADO-PICEANCE - EMERGENCY PHONE NUMBERS
Colorado State Patrol 970-824-6501
Garfield County Sheriff 970-945-9151
Rifle Fire Protection 970-625-1220
Rifle Police Dept. 970-625-2271
Silt Ambulance 970-625-1899
Silt Fire Protection 970-876-5738
Silt Police Dept. 970-876-2735
Grand River Hospital, Rifle 970-625-1510
Valley View Hospital, Glenwood Sp 970-945-6535
Kimley-Horn
and Associates, Inc.
September 4, 2007
Garfield County Building and Planning
108 8" Street, Suite 410
Glenwood Springs, Colorado 81601
Attn: Craig Richardson
Re: Bailey Compressor Station
Traffic Assessment and Trip Generation Letter, Garfield County, Colorado
Dear Mr. Richardson:
Per Garfield County requirements, this letter presents the results of a trip generation
assessment for the proposed Bailey Compressor Station. This letter also includes a
discussion of how vehicles will access the proposed site. The Bailey Compressor
Station is to be located along Alta Mesa Road approximately 3 miles south of the
Town of Silt in Garfield County, Colorado. The total site area is approximately 10
acres. Access to the proposed compressor station will be from Alta Mesa Road.
Site -generated traffic estimates are determined through a process known as trip
generation. For this study, Kimley-Horn used information provided by the client to
determine the number of vehicles anticipated to access the site per day as well as the
number of vehicles anticipated to enter and exit the site during the AM and PM peak
hours. These trip generation estimates include the number and types of vehicles that
are anticipated to access the site during the construction phase, during normal
operations, and in the future.
During the estimated sixteen (16) week construction period it is anticipated that the
total number of vehicles that will access the facility during a typical day would be
approximately twenty (20) vehicles. A vehicle entering the site and exiting the site
counts as two trips; therefore, a total of 40 vehicle trips in and out of the site are
anticipated during the construction phase of the compressor station. These vehicles
would include cranes, boom trucks, semi tractor trailers, concrete trucks, 1 -ton roust-
a-bout/welder trucks, and 1/2 and 3/4 -ton company trucks.
Once construction is completed and normal daily operation begins, it is expected that
approximately eight (8) vehicles would access the site daily resulting in a total of 16
vehicle trips in and out of the site. Typical daily operation vehicles would include 1 -
ton and 3/4 -ton technician, pumper, and contractor trucks, %z -ton manager and visitor
trucks, and water and condensate removal semis.
TEL 303 228 2300
FAX 303 446 8678
Suite 1050
950 Seventeenth Street
Denver, Colorado
80202
STAGING AREA
EAST LATERAL PIPELINE AND BAILEY COMPRESSOR STATION
Bill Barrett Corporation is not proposing the need for any staging areas for pipe,
equipment or material. All fabricated materials will be stored at contractor's yard
and delivered to the job site. Pipe will be strong along the right-of-way during
construction of the pipeline. Equipment used during the construction of the pipeline
and compressor will be required to stay on R.O.W. at all times with no exceptions.
During the construction of the Bailey Compressor Station all materials and supplies
to include equipment, will be stored onsite at all times and within the property
boundaries.
Hydrostatic Testing
For the proposed 20 inch and 8 inch pipelines Bill Barrett Corporation (BBC)is not
planning to hydrostatically test these two lines. These lines will be ran at low
pressures using allowing BBC to test their lines with wellhead pressures.
BBC does intend to hydro test their proposed 6 inch steel High Pressure natural gas
pipeline. It is estimated that the maximum test pressure of this line will be 1573 psig
which is adequate to meet the standards set by DOT and API Specification to test
pipelines at 1'/Z times the maximum operating pressure. BBC intends to utilize
water from contractors with approved water rights to complete the test. Water will
be disposed of at one of their existing water storage sites once test has completed
and is successful or trucked of to an approved disposal facility.
The hydro test will consist of a 8 hour test. This test will be broken down into three
segments during the 8 hour period. The segments are as follows: 2 hour Leak test, 2
hour strength test, 4 hour Stability test. The test shall be recorded with the use of
dead weights and a meter chart showing pressure and ambient temperatures.
During the first 2 hours of the test readings should be taken in 15 minute increments
and then every 30 minutes for the remainder of the test. Pressure shall only be
allowed to drop to the estimated minimum pressure. If pressure drops below
minimum pressure test will be considered as a failure. Test is to be performed by
qualified technicians with approved supervision by a BBC representative or third
party inspection company hired by BBC. All equipment used for testing must be
calibrated and have current qualification documentation prior to commencement of
the test.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 1 of 10
1. DESIGN GUIDE
This design guide covers the design, installation and maintenance guidelines for carbon steel
pipelines used in natural gas service.
2. CODES AND STANDARDS
As a minimum, carbon steel pipelines shall be designed to the latest approved editions and
sections of the applicable codes and standards as follows:
3. DESIGN OF CARBON STEEL PIPE
3.1 Allowable Working Pressure
3.1.1 The following formula is from 49 CFR Part 192, Section 192.105, "pipeline Safety
Regulations" by the Office of Pipeline Safety, Department of Transportation (DOT).
P= 2ST xFxExT
D
Where: P=
Internal design Pressure, pounds per square inch gauge (psig)
S=
Yield Strength, psi of pipe material in accordance with paragraph 192.107
t=
Wall Thickness in inches
F=
Design Factor determined in accordance with paragraph 192.11 of DOT
pipeline safety
E=
Longitudinal joint factor determined in accordance with paragraph 192.113 of
DOT Pipeline Safety Regulations (E=1.0)
T=
Temperature derating factor determined in accordance with paragraph 192.115
of DOT Pipeline Safety Regulations (T=1.00 for a temperature of 250° or less)
3.1.2 The above equation was based on the allowable working pressures for gas transmission
and distribution piping at -20°F to 250°F service temperature.
3.1.3 Corrosion allowance must be added to the calculated wall thickness.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 2 of 10
3.2 Pipeline Sizing
3.2.1 Sizing Equations
The AGA flow equation modified by the Colebrook -White transmission factor as shown below is
recommended for the most accurate prediction of pipeline flow characteristics.
Q= 38.774 10-6 Tb
Pb
[Pi2—p22j0.5 d25F
[G Tr Zavg L]
where: Q=
Flow rate (MMSCFD
Tut=
Base Temperature (520°R)
Pb=
Base Pressure (14.73 psia)
Pi=
Upstream Pressure (psia)
P2=
Downstream pressure (psia)
G=
Gas specific Gravity (air=1.0)
T1=
Flowing gas Temperature (°R)
Zavg
Gas compressibility factor
L=
Pipe Length (miles)
d =
Pipe Inside Diameter (inches)
F =
Transmission Factor =4 Logi° (3.71 d/Ke)
Ke =
Effective Roughness (inches)
3.2.2 Mainline Sizing Criteria
Mainlines are sized based on a 5 to 10 psi/mile pressure drop. Physical and economic
considerations such as horsepower, pipe availability, fuel gas costs and future expansion may
dictate different sizing criteria. Summer or winter gas flowing temperatures and ambient
temperatures will be used depending on the basic purpose of the mainline, i.e., winter peak day
requirements verses year-round transportation for others, etc.
3.2.3 Branchline Sizing Criteria
Branchlines are sized to flow peak hour loads. A specific psi/mile pressure drop criterion is not
used. The difference between the available pressure at the mainline tap and the required meter
facility inlet pressure will be used, resulting in pressure drop rates up to 20 psi/mile. Pipe sized
down to 2" nominal pipe size may be used.
3.2.4 Gathering Line Sizing Criteria
Gathering lines are designed for a 5 to 10 psi/mile pressure drop, with a minimum nominal pipe size
of 4". Physical and economic considerations such as horsepower and pipe availability, fuel gas
costs and future expansion may dictate different sizing criteria.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Nurnber: DG -4850
Date:
Page: 3 of 10
4. ROUTE SELECTION
4.1 The route should be the most direct line between accessible starting and terminal points of the
pipeline. Exceptions to this may be made for items such as rivers, work areas, rough terrain,
archaeological and environmental considerations, towns or populated areas, land use, power lines,
roads, railroads and related facilities.
4.1.1 Rivers and ravines should be crossed at right angles and in a straight run of the river.
4.1.2 Rough terrain, wet land and fault zone crossings should be minimized.
4.1.3 Road and railroad crossings should be minimized.
4.1.4 Areas with a high potential for encroachment should be avoided
4.1.5 Areas with high potential for requiring condemnation to obtain right -or -way should be avoided.
4.1.6 The alternative of routing the pipeline in and along a public road or railroad right -or -way should be
evaluated.
4.1.7 Pipelines should not be routed parallel and adjacent to power lines where reasonable alternatives are
available.
4.2 The start and termination of the pipeline and preliminary route may be determined by using USGS maps.
Route information accuracy requires field reconnaissance and/or the use of aerial photography.
4.3 After preliminary determination of the route, an ownership search and preliminary survey should be made
to determine actual conditions along the route. Based on the survey and related information, the route
should be finalized and resurveyed as required. Property plats, permits and the construction drawings may
then be prepared.
5. RIGHT-OF-WAY (ROW)
5.1 Permanent ROW widths should be a strip of land 50 feet in width for a single pipeline. In addition to the
permanent ROW, temporary additional work space may be necessary for larger line sizes, at road
crossings, river crossings, and areas with side slopes.
5.2 Any conditions or restrictions contained in the easement must be incorporated in the design and
construction of the line.
5.3 The granting of a sales meter (faun tap) as a condition of the easement is discouraged.
6. PERMITS
6.1 Environmental permits may be required for a variety of reasons. The Environmental Department shall be
consulted relative to any permit requirements.
6.2 Use permits are normally required when the pipeline crosses federal land, state land, state and county
highways, railroads and waterways. The design and installation of the pipeline must be in compliance
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
with the specific permit requirements. Any conditions or special requirements should be indicated on the
design drawings and in the contact documents.
7. HANDLING AND STORAGE
The interior of all pipe and fittings shall be kept free of dirt, liquids and foreign matter at all times.
8. PIPELINE DESIGN
8.1 Construction drawings and contract documents for pipelines subject to the requirements of 49 CFR
Part 192 should be thoughtly reviewed to assure that the design meets the latest requirements of that
code.
8.2 The design of any facility considered exempt from Part 192 should be compared to the minimum
requirements of Part 192. A tabulation of any deviations should be prepared and included in the
permanent documentation of that facility.
8.3 All facilities shall be designed using the applicable design factor to meet the Class Locations as
defined in Part 192
8.4 Pipeline cover greater than the minimum specified by Part 192, §192.327 may be required due to
easements, permits, road and railroad crossings, drain tile and to provide clearance between the new
line and existing pipelines. Also cover greater than minimum requirements may be prudent in
agricultural areas due to deep cultivation or operating activities or in areas subject to significant wind
or water erosion
8.5 Trenching
8.5.1 In rocky soil conditions, the trench bottom should be undercut a minimum of 4 inches and the
unde4rcut filled with fine gravel or clean soil that will provide a good bearing surface for the
pipe.
8.5.2 The trench bottom should be flat to eliminate peak loads on the pipe and deter the pocketing of
liquids.
8.6 Crossings
8.6.1 Road and Railroad
Road and railroad crossing design requirements are often dictated by the permit requirements
of the governing body having jurisdictional authority. A permit must be obtained prior to
making any crossing. Uncased crossings are preferred and should be pursued in the permitting
process. Also, 49 CFR Pert 192, requires a lower design factor for uncased road and railroad
crossing in Class I and Class II locations. If unusual loads are anticipated, a stress analysis
shall be required.
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 4 of 10
with the specific permit requirements. Any conditions or special requirements should be indicated on the
design drawings and in the contact documents.
7. HANDLING AND STORAGE
The interior of all pipe and fittings shall be kept free of dirt, liquids and foreign matter at all times.
8. PIPELINE DESIGN
8.1 Construction drawings and contract documents for pipelines subject to the requirements of 49 CFR
Part 192 should be thoughtly reviewed to assure that the design meets the latest requirements of that
code.
8.2 The design of any facility considered exempt from Part 192 should be compared to the minimum
requirements of Part 192. A tabulation of any deviations should be prepared and included in the
permanent documentation of that facility.
8.3 All facilities shall be designed using the applicable design factor to meet the Class Locations as
defined in Part 192
8.4 Pipeline cover greater than the minimum specified by Part 192, §192.327 may be required due to
easements, permits, road and railroad crossings, drain tile and to provide clearance between the new
line and existing pipelines. Also cover greater than minimum requirements may be prudent in
agricultural areas due to deep cultivation or operating activities or in areas subject to significant wind
or water erosion
8.5 Trenching
8.5.1 In rocky soil conditions, the trench bottom should be undercut a minimum of 4 inches and the
unde4rcut filled with fine gravel or clean soil that will provide a good bearing surface for the
pipe.
8.5.2 The trench bottom should be flat to eliminate peak loads on the pipe and deter the pocketing of
liquids.
8.6 Crossings
8.6.1 Road and Railroad
Road and railroad crossing design requirements are often dictated by the permit requirements
of the governing body having jurisdictional authority. A permit must be obtained prior to
making any crossing. Uncased crossings are preferred and should be pursued in the permitting
process. Also, 49 CFR Pert 192, requires a lower design factor for uncased road and railroad
crossing in Class I and Class II locations. If unusual loads are anticipated, a stress analysis
shall be required.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 5 of 10
8.6.2 Waterway Crossings
Waterways may range from small drainage canals to large navigable rivers and lakes, may of
which require a crossing permit from a jurisdictional authority. Wetlands and navigable
waterways are normally under the jurisdiction of the U.S. Army Corps of Engineers. Small
stream crossings controlled by local authorities may not require special permits and may be
accomplished with standard cross-country construction methods. However, the specific
requirement should be checked with local authorities before proceeding with the crossing
design.
The selection of the most suitable location to cross a waterway involves many considerations,
particularly if it is of significant size. In selecting and designing the crossing, documentation
of the history, geology and hydrology of the waterway and projection of possible future
considerations such as bottom scouring and movement of the channel should be competed.
Waterway conditions at the time of construction will also influence the selection of the
crossing. An accurate survey of the river should be made, noting caving banks, sand bars, and
related items in order to arrive at the best location and determine depth below the bottom of
the channel.
Economic and engineering evaluations will need to be completed to determine the design of
the crossing and method of construction to use.
For major pipeline systems, consideration should be given to a dual crossing which would
provide a backup should failure or damage occur to one of the crossings.
8.7 Foreign Pipeline Crossings
The specific requirements for foreign pipeline crossings are normally set by the owner or operator of
the foreign line. The minimum cover requirements are maintained and the crossing is approved by the
operator of the foreign line. Cathodic test leads should be installed on the company line and the
foreign pipeline with the approval of the owner or operator of the foreign line.
8.8 Pipeline Pulling
8.8.1 The effect of pulling a number ofjoined lengths of pipe across the ground by gripping one end
results in the generation of a tensile load in the pipe. The maximum force that can be applied
to the pipe length in pulling it into position should be calculated prior to pulling.
8.8.2 A pulling head should be used to attach to the leading end of the pipe. This can take the form
of a simple rubber pad with a steel cable wrapped around the pipe, or can be more
sophisticated in the form of a pulling head.
8.8.3 Under no circumstances should the pipe be pulled by attaching to the flange. If flange
assemblies are installed, they musty be elevated to keep from dragging, both in front and
behind.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 6 of 10
8.9 Pipe Laying
Connections made to valves, unsupported equipment, manholes, etc., shall be supported. A concrete
pad shall be installed under the heavy member to resist settlement and preclude the pipe from
supporting the component.
8.10 Backfilling
8.10.1 The final backfill material can be the original excavated material or other convenient soil
provided it does not contain large rocks, debris or frozen lumps. The backfill should be
compacted to 90%.
8.10.2 In areas where a high water table exists it will be necessary to allow for the effect of buoyancy
of the pipe and of the backfill material. The conventional trench configuration and the
frictional forces and load on the fill will no longer be sufficient to overcome a tendency for the
pipe to float. This situation requires that the depth of cover be calculated from the following
equation;
H _ 0.785 (D2Ww) — Ws
D (Ws — Ww)
Where: H=
Minimum cover in feet
D=
Diameter of the pipe in feet
Wp=
Weight of empty pipe in lbs
Ws=
Saturated soil density in lbs/cubic foot
Ww=
Density of water in lbs/cubic foot
8.11 Plowing In
The plowing in of gas piping will not be allowed without prior written approval of the Client.
8.12 Valve Spacing and Design
8.12.1 Sectionalizing block valves and blow down valves for new transmission and non -rural
gathering lines must meet the requirements of 49 CFR, §192.179.
8.12.2 The installation of block valves in rural gathering pipelines and in all pipeline segments that
are replaced, relocated or changed shall be based on operating considerations. Hydrotesting is
not considered to be replacement, relocation or change and does not dictate that a valve be
installed.
8.12.3 Block valves should be located at readily accessible locations, such as near roads, but away
from overhead power lines if blow -offs are included.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 7 of 10
8.13 Liquid Removal
8.13.1 Liquid may accumulate at any low point in a pipeline and some means of removal should be
considered during the design phase of a pipeline system. Methods typically used for liquid
removal in pipelines are siphons, drops and pigging. The selection of the method or
combination of methods should be based on the expected liquid volumes and liquid disposal
problems.
8.13.2 Siphons are typically installed at low points in the pipeline where liquids can accumulate and
in drips and scrubbers. They consist of a pipe inserted through the top of the pipeline using a
saddle connection (or piping system) that extends to the bottom of the pipe with a valve to
allow blow down of the liquids from the low point. Temporary insertion type siphons are also
available. Siphons should not be installed where they may become a restriction to pigging
operations.
8.13.3 Drips are fabricated assemblies installed with the pipeline to separate and store liquids. They
are generally located at wellheads, in-line on pipelines, at pig receivers and at inlets to plants.
The liquid capacity of the drip should be based on the expected volumes of liquids to be
removed, time period between draining of the drips and related operating conditions.
8.13.4 Pigging
a. Consideration shall be given to the installation of on -stream pigging systems when
accumulations of liquids, dirt, wax and related materials would severely decrease the
pipeline efficiency or contribute to internal corrosion. Pigs may be any of a large
variety of types.
b. Pigging will normally require the installation of permanent on -stream launchers and
receivers for those facilities that require frequent pigging runs, or those mainline
transmission pipelines which cannot be taken out of service. Temporary or mobile
type pigging systems may be considered for gathering and those pipeline which can be
taken out of service and are pigged infrequently.
c. The design for system to be pigged should ensure that no restrictions are included in
the system. Where a line size change occurs, the normal practice is to install a
receiver and a launcher, although multiple size pigging sections should be considered.
Installation of guide bars on all large side connections and liquid removal facilities
must incorporate into the design to prevent entrapment or damage to the pig.
d. Liquid receiving facilities must be provided and sized to contain the slugs of liquid
expected to be removed from the piping by each pig run.
8.14 Branch Connections
8.14.1 Branch connections or side taps should be designed into the pipeline as necessary to combine
or split flows, and to provide service to other systems or sale facilities.
8.14.2 Farm taps, although discouraged, may be required by ROW easement.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev.No.: 0
Number: DG -4850
Date:
Page: 8 of 10
8.15 Pipe, Valves and Fittings
8.15.1 The pipe used in the design should be seamless, submerged -arc welded (SAW) or electric
resistance weld (ERW). Pipe should be specified to ASTM A106 Grade B or API 5L. The
ratio of pipe diameter to wall thickness (D/t) should not exceed 90 without a specific
evaluation to be included in the permanent facility records. For welded pipelines, field
weldability due to wall thickness should not be of concern for wall thickness 0.156" and
above. Added wall thickness for corrosion allowance shall be added when corrosive gas (with
high levels of H2S or CO2 with free water) exists in the system. Special chemistry should also
be considered for pipe to be used in corrosive gas service.
8.15.2 Valves in pipeline systems shall be rated by an ANSI class designation. Valves 2" and larger
must meet API 6D or an approved equal. The pressure rating of the valve must meet or
exceed the design pressure of the pipeline. For corrosive gas applications, NACE trim should
be specified. Valve ends for connections to pipelines should be either weld -by -weld or weld -
by -flange with the weld always on the side serving the most critical service.
Some common applications of various valves are as follows:
a.
Plug Valves
Block, isolation and blowdown
b.
Ball Valves (full open)
Hot tap valves, where pressure drop
must be minimized or where pigging
is a consideration
c.
Gate Valves
Block, isolation and hot tap valves
d.
Check Valves
Direction flow devices at side valves
settings and in compressor piping
e.
Relief Valves
Overpressure protection
f.
Control Valves
To control volume or pressure
8.15.3 Flanged connections should be avoided below grade in order to reduce the potential for
undetected leaks. Screwed connections 1-1/2" and smaller may be used; however, screwed
connections made directly on the pipeline are prohibited except for locations that may be
conveniently isolated and there is little risk of mechanical damage from outside forces.
8.15.4 The materials and rating of flanges and fittings for the pipeline must be compatible with or
exceed those of the pipeline.
8.16 Pipe Coating and Painting
8.16.1 Sttel pipe installed below ground or submerged must be insulated from the earth to reduce the
cost of external corrosion control (cathodic protection current). Pipelines may be protected
using a variety of external coatings applied in a coating yard, at the job site or over -the -ditch.
8.16.2 All above ground piping must be painted to prevent atmospheric corrosion.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 9 of 10
8.17 Cathodic Protection
8.17.1 Steel pipelines installed below ground or submerged must be protected from external
corrosion using cathodic protection as part of the protective system.
8.17.2 Cathodic protection systems require that pipelines be electrically insulated from other systems
at certain points. Insulating flanges or unions should be installed in above ground piping at all
plants, meter stations and connections with foreign pipelines.
8.17.3 Cathodic protection is normally provided by a rectifier and ground bed system or sacrificial
anodes. The rectifiers are installed as necessary to provide the required protection. Test
connections are provided at intervals along the pipeline, generally at road crossings and cased
road/railroad crossings. The test connections are typically installed with the pipline by the
contractor. The cathodic survey is made by either the Client's cathodic specialist or
specialized contractor. Special grounding system should be considered when the pipeline
parallels a power line.
8.18 Testing
8.18.1 Radiography is a means to control welding quality during construction
8.18.2 Pressure testing must be conducted on all pipeline systems to establish integrity. Most testing
is done with water, however, some testing may be either air, nitrogen or natural gas.
Environmental permit requirements must be considered when planning the hydrostatic test.
8.18.3 After completion of a hydrostatic test, the pipeline must be dried. Generally dewatering of the
line with cup pigs is all that is necessary. Winter start-up, proximity to the market, or contract
requirements may require additional drying. Methanol slugs may be pushed thought the
pipline with pigs to remove moisture and suppress the dew point. Methanol may be injected
during the start-up to reduce moisture and hydrate problems. Compressed and dried air may
also be used with pigs to dry and clean the line.
8.18.4 Under no circumstances shall the total time under test exceed eight (8) hour at 1.5 times the
design pressure.
8.18.5 When draining the water from the pipe, beware of creating a vacuum condition. Both ends of
the line should be open to atmosphere to allow the water to run freely out of the pipe.
8.18.6 Unless otherwise directed in writing, all tests shall be conducted or withnessed by a Client
representative.
8.19 Qualified Welders
8.19.1 Only "Qualiffied Welders" (anyone who has passed a KNE administered welding test within
the preceeding 12 months) will be allowed to perform welding on pipe and fittings.
8.19.2 Candidates for qualification or requalification shall fabricate test assemblies for each type and
size of material required for a specific job.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CARBON STEEL PIPELINES
Rev. No.: 0
Number: DG -4850
Date:
Page: 10 of 10
8.20 Line Markers
Typical signs include "Caution" or mile post signs and aerial patrol signs. The "Caution" signs should
be installed all crossings and other locations where necessary and practical to identify the location of
the pipeline to reduce the possibility of damage or interference. If a line is to be patrolled by airplane
on a regular basis, aerial patrol signs should also be installed. The fence posts on either side of the
pipeline at all crossings shall be painted distinctively.
9. DOCUMENTATION
All documents become part of the "as -built" package and shall include applicable construction drawings
reflecting the actual installation, rechain survey notes, purchase orders, pressure test records, radiographic
records, specifications, manufacturers drawings and certifications, mill test reports, code calculations and other
related documents.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Number:. ES -4852
: 1 of 43
Rev. No.: 0
Dale: 4/17/03
1. SCOPE
This Standard defines the minimum standards of quality for the construction of onshore carbon steel
Pipelines.
2. CODES AND STANDARDS
2.1 The safe design, construction; operation and maintenance of pipelines is governed by documents
that present industry accepted guldellnes such as:
The Department of Transportation (DOT) regaiations
The Americ4in Society of Mechanical Engineers (ASMB) standards
The U.S. Department of Labor Occupational Safety and Health Administration (OSHA)
regulations
The American Petroleum Institute Recommended Practices (API RP).
22 New onshore pipelines shall be designed and fabricated to comply with the latest revision of all
applicable federal, state and Local codes, standards and regulations. Codes and standards shall
include but me not limited to:
API Spec SL, "API Specification For LInQ Pipe"
API Speo 6D, "API Specification For Pipeline Valves"
ANSI BI6.5, "Steel Pipe Flanges and Flanged Fillings"
ASME 031.4, `Liquid Transportation Systems For Hydrocarbons, Liquid Petroleum Gas,
Anhydrous Ammonia, and Alcohols"
ASME 831.8, "Gas Transmission and DistrxbutionPiping Systems"
API Standard 1104, "Welding of Pipelines and Related Facilities"
ASME Section DI, "Qualification Standard for Welding and Brazing Procedures, Welders,
Brazens, and WelNbgandBrazing Operators"
DOT Pipeline Safety Regulations Part 192, "Transportation of Natural and Other Gas by
Pipeline: Minimum Standards"
DOT Pipeline SafetyyRegulations Part 195, 'Transportation ofHazanlous Liquids by Pipeline"
National Fire Protection Association (NFPA) Standards.
National Association of Condon Engineers (WE) Recommend Practice
ANST•TC-IA
ASTM A185 (19.3.3)
ASTM C33 (19.42)
ASTM A 615 (1932)
ASTM C94 (19A.5)
ASTM C150 (19.4.1) '
ASTM C143 (19.4.7)
3. GENERAL
3.1 Contractor shall place all necessary 'one calls' 72 hours prior to conslmction or as required by
one -call system(s). Any costs incurred resulting from failure to comply with this requirement
shall be at Contractor expense. Contractor shall be responsible for the protection of existing
underground &tides. Before performing any rlgbt-af-way work, Contractor shalt verify with
Client that alt property owners have been notified of impending construction
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Number:ES-4852
Page: 2 of 43
Rev: No.: 0
Date; 4/17103
3.2 Only vehicles on the Client or Contractor payroll or otherwise necessary for construction shall be
allowed on the right-of-way. Contractor shall transport crews to the tight -of -way to minimize the
number of vehicles on the right-of-way.
3.3 Equipment involved in pipeline construction shall be moved onto the construction right-of-way
using only Client -approved access roads. Contractor shall cornet vehicle traffic such that o*
Clientapproved access mads and construction right-o&way are Millard and no 'equipment or
vehicles leave the oonstracdon rtght.of-way.
3.4 Contractor shall use access roads in a manner consistent with their parent use. No roads shall
be widened, graded er otherwise impmvedwithoot prior written approval from Client
3.5 Contractor shall maintain restricted area signs and/or orange safely fences and instruct personnel
and subcontractors that vehicular, equipment and pedestrian travel into or through these areas is
striadyproldbited.
3.6 As necessary to meet construction and environmental requirements or as specified in the Scope of
Work, Contractor shall hmiIsh water and egmpmeat to wet the right-of-way, access roads and
work areas used during constuction.
3.7 Prior to construction, Contractor shall instruct its employees and subco o t actors regarding
impiemenration of the Spill Prevention, Control and Countermeasure (SPCC) Plan and the Storm
Water Pollution Prevention (SWPP) Plan, if applicable, as detailed in the Right -of -Way and
Permit Stipulations Sadion of Ibis Contract. If necessary, Contractor abal assist Okra in
pig project c SPCC and SWPP Plans.
3.8 Any damage to erosion contel sinrdures shall be repaired immediately. Contractor shall be
responsible for assuring that erosion control sir aures remain fnndional at all times and that
spoil and sediment do not leave the construction righter --way.
3.9 Throughout construction and restoration, Contractor shall keep equipment bridges and paved
roads dear of dirt and nmdaoammladon resulting from construction traffic.
3.10 Gates shall tomato doseddat all times unless otherwise posted.
3.11 Contractor shall not diwept any irrigation system without Client's prior approval.
3.12 If required in the Scope of Words section of this Contract, Contractor shall provide an
Environmental Crew with menden persoaael, supervision and equipment to supply, install,
maintain and remove environmental protection cbntols.
313 Each Contractor office shall post and maintain an Emergency Telephone Contact List
3.14 Cormaciar Is responsible for its own safety program and shall ensure that porsonnel aro Informed
of and compo' with may, precautions and job requirements.
4. SURVEY
4.1 As necessary, Client shall stake and/or identity with signs the locations of proposed pipelines and
appurtenances, Sating pipelines, oonslmction right' -way boundaries and restricted areas.
ONSIPORE CARBON STEEIJIP111NE 1NSTALLATI0N
ENGINEERING STANDARDS
Number B$4852
Page: 3 of 43
•Rev. No,: 0
Date 4/17/03
4.2 Contractor shall be tesponsllile for determining the actual existence of and the actual Physical
looadom of any and all mating underground facilities that parallel or cross the proposed pipeline
route.
4.3 After lowering -in, Contactor shall allow Client surveyors adequate time to perform the as -built
survey before padding or backfilling the pipe,
4.4 Contractor shall perform neoeaswy field surveys for crossing, Paper grading of the dItch add
bending of pipe, looting existing underground facilities and other such pipeline installations
except for such field survey work as specified to be performed by Client. •
4.5 For detailed survey instructions see Client Standard ES -7013.
5. FENCING
5.1 Saibty Fence
Contractor shall install, maintain and remove temporary safety fence along the rigid -of -way to
isolate adjacent properties from work area as shown in the Scope of Wort, Drawing and Right -
of -Way and Permit Stipulations sections of ails Contract. .
5.2 Right -of -Way Fence
5.2.1 Prior to cutting fences and installing gates or pps, Contractor shall install 'B" brace
assemblies in fence lines as shown in the Drawings and Right -of -Way and Permit
Stipulations section of lids Contract
5.2.2 Gates shall remain dosed whomever possible and as described in the Right -of -Way and
Permit Stipulations section of this Cataract. When gates must bo left open and livestock
are present, watchmen shall be posted to ensure no livestodt pass through gate.
5.3 PermaneatFence
5.3.1 Fences disturbed by contraction shall be restored to original condition according to the
Drawings section chins Contract and to Client and landowner or tenant satisfaction.
5.3.2 Permanent right -of -tray fence gates shall be installed according to the Drawings and
Right -of --Way and Permit Sdpubtiom section of this Contact.
5.3.3 For detailed hence and protective barrier conetnxtion sae Standards ES -7030 and B8-
7035.
6. CLEARING AND GRADING
6.1 general
6.1.1 Before starting clearing and grading operations, Contractor shall be femtliar and comply
with all special provisions Waded in the Drawings and Right -of -Way and Permit
Stipulations sections of this Contract. Immediately aftw' soil disdnbance by Contractor,
erosion control structures skill be installed as specified in the Drawings and Right -of -
Way andPermit Stipulations sections afthis Contact.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No,: 0
Date: 4/17/03
Number: ES -4852
Page: 4 of 43
6,1.2 Clearing and grading of the right-of-way shall be limited to the removal of rocks, trees
or brush dim can damage pipe coating during construction and the amount of grading
necessary ibr equipment and faire inspections and which will preserve u much of the
natural vegetation as passible:
6.1.3 Contractor shall exercise extreme candor when conditions regoke work over exieing
pipelines. The minimum cover required to operate heavy equipment ova existing
pipeline is S $et. Operation of heavy equipment over exlsdng pipelines with km than S
feet of cover shall not be permitted without written Client approval. Client Inspectors
may venulae additional cover, mats or otherprotegion WWII appears sufficiently muddy,
rocky or otherwise unsafe. Tracked equipment sball not spin or Mtn sharply while
working over the existing line. At no time will machine excavation or grading be
allowed below existing grade within 5 feet of the slaked location demisting pipelines.
6.1.4 Contractor shalt hall temporary adverts in drainageditches, canals, creeks and other
drainage neonates which will be blocked during Edon operations or where
damage to property or crops might mar because of drainage being blodied. Should
instal adon of flume pipe in drainage ditches be impractical, Contractor shall construct
drainage ditches Pendia to the pipeline within ate right -atom to connect with the
neatest functional drainage ditch to ensure limper drainage. Contractor shall be
responsdile for determining the proper culvert size according to teal, state and federal
regulations.
6.1.5 Contractor than immediately repair any damage to bridges, Pirate mads, fatal)
buildings or other propdty wben Client determines the damage cannot await repair by
the dannp operation
6.1.6 Contractor shall relocate obstructions in the construction right- way unless otherwise
specified In the Rigbt-of-Way and Pamit Sdpolations section of tills Contract
6.1.7 When utility lines interfere with the ingress and egress of Contractor vehicles and
con on ap ipmed during pipeline aonetruction, Contractor shall arrange to
preserve continuous use of utility lines during pipeline construction and shall pay the
cost of maintaining service.
6.2 Clearing
6.2.1 Brush and trees shall be removed to minimize damage to adjacent trees or structures.
Other beet brush and vegetation shall be buried, chipped or otherwise disposed of
according to the Right -of -Way and Permit Stipulations section of this Contract. When
burning Is permitted, Contractor shall notify Client and obtain and provide for Client a
ow of the proper Clearance from the appropriate governing agency before burning may
COMM.
6.2.2 Contractor shall grub or otherwise remove stumps in dila ditch line.
6.2.3 While dearing, Contractor shall not damage any environmental protection controls;
however, if damage . does . occur daring the clearing operation, Contractor must
immediately perform corrective action. The method of clearing shall take into account
potential erosion, soli stability and the protection of environment, vegetation and
adjacent resources. '
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
Number: ES -4852
Page: 5 of 43
6.2.4 Unless otherwise specified in the Right -of -Way and Permit Stljmlations section of this
Contract, timber not used for construction proposes and tree tops, tree trimmings,
slashing branches, brush, slumps and other vegetation shall be disposed of in a manner
satisfactory to Client. Debris shall not be pushed riff the cleated construction right-of-
way and left on adjoining or adjacent areas. Debtia shall not be mixed with soil from
grading. Disposition or removal of debris shall be completed ahead of the ditching
operation.
6.3 Grading and Soil Segregating
6.3.1 The Right -of -Way and Pomrit Stipulations section of this Contract idem areas that
inquire topsoil xemavaL Contractor shall remove the topsoil Boni the designated areas
of the work space and shall place and segregate the topsoil in specific areas along the
work space so Contractor can return this topsoil to its original location_ Grading
techniques obeli minimize mbdng topsoil with other soils or foreign matter. Graded
subsoil material shall beplaced 1n spoil banks from width it can be returned as nearlpas
prncticai to tla original depth and location. Graded subsoil material and shall not be
aprpad on the right-of-way satraps.
'7. DITCHING
7.1 For excavations and ditches subject to soman ocazpancy, Contractor shall comply with the latest
edition of the Occupational Saftty and Health Administration (OSRRA) Construction Standards
for Excavations and all state and local regulations, and shall provide the trained nail certified
"Competent Person" as defined by the above regulations Contractor also shall provide
personnel, supervision, material and equipment =manly for completion and maintenance of the
ditch including wafer control, shoring, milindams and aheetpling
7.2 Contractor shall coordinate excavation of existing pipelines with Client Inspector. No excavation
shall be performed without Client present. Excavation shall not commence mall the
andergroimd pipeline or facility has been bested and stalked. Sidb cut ung teeth shall be removed
froin buckets of vadng equipment.
7.3 Machine excavation of la -service pipelines shall not be permitted within 5 feet of the staked
location until the pipeline has been physically located by band. After locating the pipeline
facility by hand, marhine excavation within 2 feet shall not be permitted. Final excavation shall
be by hand.
7.4 All possible precmafoas shall be exercised to avoid damage to existing pipelines. Any damage
caused by Contractor to existing pipelines or coating shall be npatred by Contractor at
Contractor's exgxmse. Client shall inspect any damage and smelt typo of repair.
7.5 Contractor shall bo respov:41e for locating all foreign lines and 1Bcllities ahead of construction.
Contractor shall comply with all required notifications of excavation and shall use a reliable pipe
locator abead cinching operations.
7.6 Tho ditch shall be excavated according to the surveyed line, as shown in the Drawings or Right-
er -Way and Permit Stipulations sections oft is Contract and as slaked on the ground by Client.
1
ENGINEERING STANDARDS
ONSHORE CARBON STEM PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
Nambea: ES -4852
Page: 6 of43
7.7 The width of the ditch bottom shall be at least 12 Inches and no more than 18 inches greater than
the oaWda diameter &the pipe.
•
7.8 Ditch depths shall be governed by the depth of cover requited over the pipeline in the Soopa.of
Work Rightof-Way Permits and SdpNalions sections of this Contract When no cover is
specified, the following shall be the minimum:
Location
Inches of Cover
Alt Locations Unless Otherwise Specified 36
Cultivated Land 42
Commercial, Industrial and Residential Areas 42
Water Crossings, including Menthes 42
Road Drainage Ditches and Railroads 42
Water Crossings 60
Roadways ' 60
7.9 Miuimm cover in consolidated rock shall be in aroordance with DOT Pipeline Safety
Regulations Part 192.327 or Part 195.248, as applicable.
7.10 The cover over the pipe normally shall be measured Rom the top of the pipe coating, or the top of
the concrete weight or coaling when used, to the avenge levet of the original ground. in no case
shallpipei1ne be placed infill.
•
7.11 Contractor shallprovide extra depth in those areas identified by Client in the Drawings or Right -
of -Way and Permit Stipulations sections of this Contact or other Contract documents, it tog
areas adjacent to and under road crossings, highways, railroads,. drainage ditches, ravines,
navigable streams, meets and other watercourses.
7.12 Additional depth shall be excavated to allow installation ofpadding material where padding is
required as defined by the Padding, Backfill and DitchBreakers section of this Specification.
7.13 •Unless otherwise approved by Client, maximum cover shall be based on the endo of the pipe
eats* diameter to its Ivan thickness (DA), •a6 shown in the table below:
D/t Rade Maximum Cover, feet
Lest than 90 No Limit
90 to 100 12
Greater than 100 8
7.14 Contractor shall adjust the ditch grade as possible to eliminate excessive cover.
7.15 The ditch bottom shall be graded to proper depths to provide continuous support to the entire
length of the pipeline and mminimize the necessityfor pipebending.
7.16 Stamps and tree roots protruding Into the ditch s5all be removed to prevent damage to pipe
coating daring lowering in operations, Spoil float ditch excavations shall not become
contaminated with mats, stamps, blanches or otherfordgn material.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION Rev. No.: 0 Number: BS -4852
Da= 4/17/03
Page: 7 of 43
7.17 The ditch shall be graded to allow a minimum clearance of 24 inches between the pipe being
installed and foreign pipelines or other rmderground facilities unless otherwise approved by
Client or foreign pipeline Owner. A minimum clearance of 12 inches shall be maintained when
crossing over or under field drain tiIe. No claim for extra work will be allowed for providing the
specified clearance ander foreign lines or other underground fhcilities.
1.18 Contractor shall ditch or clean out caved -in ditch areas before lowering pipe into the ditch.
7.19 Field tyle and dtalns —when cut, damaged or plugged by ditching — shall be flagged and repaired
or replaced to their original or equivalent condition by Contractor before backfilling of pipeline.
Damaged drain lines must be temporarily repaired immediately. and in such manner that the
drain line can fraction property. Contractor shall provide material for repairs of damaged
drains. •
720 Contractor shall probe drainage tile systems within the disturbed area to chock for damage.
Drain tile damaged by ditch excavation shall be removed back from the edge of fhe ditch to a
second undamaged joint A satiable support acceptable to Client Inspector shall be provided and.
installed by Contractor at the same grade and elevation of the original drain tile and the drain tile
line replaced in the support. Drain tile shall be placed with tight joints in the support and held In
place by earth tamped firmly around the repaired line. Drain Me used for replacement shall be of
the same size and quality as original drain tile encountered in the ditch. If original file is not
available, replacement tiles shall be of an appropriate size and material to conned With adoring
tile.
7.21 At the lime any drain We is put, Contractor shall carefully and immediately marc the location of
such damaged drain tiles in a prominent manner by a securely staked lath with a bright yellow
cloth attached. Such markers shall remain in place and shall not removed except by the drain
the repair crew after the We has been repaired and such repair has been inspected and approved
by Client Iaspecgor and landowner or tenant The ditch shall be backfilled and tamped by hand
between the pipe and drain rile to prevent shifting of the reported drain toe ducting backfill
operations.
7.22 Contractor shall maintain flow in mop irrigation systems tbrougbout conetrnctioa, unless
interruption is coordinated with acted parties.
7.23 Gaps, fiumes or openings sball be installed in the spoil bank to allow normal drainage of the area
and to prevent flooding of adjacent lands. Temporary erosion and sediment cool slum res
shall be installed when construed= area is adjacent to wetlands or bodies of water. Extreme care
nest be exercised to ensure drainage ditches and water sources remain open.
7.24 Contractor shall provide safe temporary bridges actors the diteb or shall leave gaps in the ditch
for personnel, equipment or livestock crossing if required by Client Inspector. Bridge and gap
spacing should not bb greater than 5,000 Beet and should be in accordance with the Right -of -Way
and Permit Stipulations section of this Contract.
7.25 Topsoil segregation shall be performed according to the Grading, Drawings and Right-of-way
and Permit Stipulations sections of this Comet. The topsoil shall be kept segregated in its
original uncontaminated state and at no time shall be allowed to hem= contaminated with
forelga material.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Number: E&4852
Page: 8 of 43
Rev. No.: 0
Date: 4/17/03
726 Contractor shall utilize sheet piling, or other means acceptable to Client, to protect adjacent
above- or below-gade facilities such as pipelines, telephone cables, electric power gables, utility
poles, towers, foundations, roadways, waterways, dikes, retaining walls, buildings or other
structures. Contractor also shall ensure that such facilities ate not damaged as a result of
Contractor construction activities.
8. BLASTING
8.1 Blasting -related operations including obtaining, transporting, storing, handling, loading,
detonating and ung of blasting material, drilling and ground -motion monitoring shall
comply with applicable federal, state and local regulations andpermit conditions.
8,2 Blasting for grade or ditch excavation shall be utilized only after all other reasonable means of
excavation have Ikon used and are unsuccessful in achieving the requhed results. Client may
sped& locations (foreign line crossings, nearby structures, eto.) wham consolidated rock shall be
removed by approved mechanical equipment such as rocluditoblag machines, rock saws,
hydraulic rams or jack hemmers in lieu ofblasdng.
8.3 Blasting shall be done with Client Inspector present and with Client .Lrapagor's approval to
proceed prior to each blast Approval does not relieve Contractor from responsdrilityorliability.
8.4 Contractor shall acquire all required federal, state and local permits relating to transportation,
storages hamming, loading and detonation of eaplosives. Blasting operations shall be conducbed
try or under the dated and constant mpetvision of experienced personnel leggy licensed and
certified .to perform such activity in the jurisdiction where blasting ooaas. Contractor shall
provide with abeam of experience and such licenses and permits prior to any blasting
•
8.5 Contactor shat furnish a Blasting Plan to Client at lead five working days prior to any proposed
blasting -related activity and shall obtain Client approval is writing prior to blasting. Any
changes to the Blasting Plan shaft require prior written approval by Client The Blasting Plan
shall include the following lnlarmation:
• Explosive type, product name and size, weight per unit and density
• Delay type, sequence and delay (ms)
• Initiation method (detonating cord, blasting cap or safety ftski)
• Strewing material and tamping method
• Hale depth, diameter and pattern
• Explosive depth, diatrulion and madonna weight of charge per delay
• Numberof holes per delay
• 'Distance and orientation to nearest aboveground structure
• Distance and ozlentBtion to nearest utdergtwnd shuctwe, including pipeirces •
• Procedures for storing, hung, trammorting, loading and. firing explosives, fire
prevention, inspections after etch blast, misfires, *rock and noise prevention, stray
current, accidental -detonation prevention, signs and flagmen, warning signals prior to
each blast, notiicadons prior to blasting and disposal of waste blasting material
• Seismograph name, Owner, egotism* and sensor location, if required
• Copies of all /quilted 'Werra, stab andbeal Damns
• Master's names Owner, copy of icons and statement of quaHGtations
• Magazine type and locations for explosives and detonating caps
• Typical toric type and geology stmctme (solid, layered or fractured)
ENGINEERING STANDARDS
ONSSORB CARBON STBBL PIPELINE INSTALLATION 1 -Rev. Np.: 0 Rather. 834852 Date: 4)17/03 Paige: 90143
6.6 Approval of the Blasting Plan by Client does not limit or reduce Contractor responsibility for
safety, damages, compile= with permits and regnlafions and the accuracy and adequany of the
plan for obtaining adequate nock breakage.
8.7 Contractor shall furnish a detailed Blasting Report to Client immediately after each blast The
Blasting Report shall include specific blast Information requested by Client, piall aa seL mogaph
vibration readings.
8.8 • Caniractor west exercise control to prover! damage to aboveground and underground strucinros
including buildings, pipelines. utilities, springs and water wells.
8.9 Damage claims resulting from blasting shall be Contractor's responsibility.
8.10 Contractor shall provide a Client-ap raved seismograph. Maximum velocity 18 5 inches per
second measured adjacent to as underground pipeline, unless Client approves otherwise; fbr cry
aboveground structure, the peak velocity is as recommended in the Slash's Handbook by Dupont
(latest edition). If the measured peak particle velocity at as existing pipeline or other structure
exceeds the above limit, Contractor shall stop blasting activities immediately and notify Client.
The Blasting Plan must be modified to reduce the peak particle velocity prior to any further
blasting..
8.11 Blasting is not allowed within 10 feet of an' existiugpipeline without written Client approval.
8.12 Hoke shall not be drilled if danger exists of intersocing another hole containing explosive
matcriaL
8.13 Blasting mats or padding shall be used on all shots where necessary to prevent scatteringoflaose
rock onto adjacent property and to prevent damage to nearby structures and overhead utilities
8.14 Blasting shall not begin until occupants of nearby buildings; stores, residences, places of
business, places of public gathering and farms have been 'unified by Contactor sufciently in
advance to protect Personnel, property and livestock.
8.15 Blasting in or near en»rammentally sensitive areas such as shears and wildlife areas may
include additional ieshietions as described in the Righter Wap and Perak Stlpulatlons section
of this Confuter.
8.16 Blasting.opetatlons shall be conducted during daylight hours.
8,17 No loaded holes shall be left unattended or unprotected No explosives or blasting agent shall be
abandoned No loaded holes shall be left ovemigbt.
8.18 In the case of a misfire, the blaster shall provide proper safeguards for personnel until the misfire
bas been so -blasted or safely removed.
8.19 The blasting agent Ammonium Nitrate and Fuel 011 (ANFO) shall not be allowed
8,20 Contractor may select and use any commercial explosives and explosive agents available
consistent with the conditions of the Blasting Plan except as noted above.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
Number: ES4852
Page; 10 of 43
8.21 Contractor shalt recognize the following;
The Owner employs electrical cathodic protection on the existing pipeline and fault
currents may bo present anywhere along the pipeline.
Client employs two-way radios for eomwmication between vehicles and office facilities
Contractor shall advise Client of any need to cease use of such equipment during
blasting activities.
9. MATERIAL HANDLING, STORING AND STRINGING
9.1 General
9.1.1 Contractor shall perform all wade necessary in preparing sitar for unloading, storing,
loading hauling and stringing pipe and material, such as installing necessary crossovers
for &Wks, temporarily removing and restoring fences and relocating obstructions.
9.1.2 Contractor shall provide necessary labor and egaipment fioi unloading securely storing,
loading, hauling and stringing pipe and material and shall perform work in a manner to
preventdamage to pipe walls pipe coning, pipe earls and othermaterial.
9.1.3 Pipe storage sites furnished by Client shall remain dear of trash and debris and shall be
graded by Contractor to allow for proper movement of equipment. Contractor
• immediately shall clean up spilli or leaks of fuels and oils from equipment working at
storage sites. Storage sites furnished by Client shall not be used as a location for
equipment maintenance by Contractor.
• 9.2 Material
9.2.1 Material supplied by Client is listed in the Material section of this Contract and
stockpiled at a site designated by Client. This material will bo pleeed in custody of
Contraetoribr transport to Job sites. Contractor, with Client, shall inspect all material to
ascertain if quantities are correct and to determine If any damage mdsts. Client will
furnish ibrms used to receive, transfer and otherwise account for Client furnished pipe
and material. Any damages and all quantities shall be recorded on these forms which
shall be slgoed by both Client and Contractor, with each retaining a copy. Contractor
shall 1* responsible for replacement cost of any material lost or damaged by Contractor.
9.22 Damaged or defective material shall be segregated, marked and stacked with damaged
agas dearly visible for subsequent inspection and repair.
9.3 Handling
9.3.1 Equipment used in handling, transporting, storing and laying pipe shall be padded
efficHvely to prevent damage to pipe or coating.
9.32 In loading pipe on trucks, each length shall be lowered to position without cit aping and
each snaeedlog length shall nest evenly with other lengths on the rode. Truck bolsters
for handiing bare or coated pipe shall be well -padded and shall bo suitable width and
shape to dim the pressure on the pipe and pipe coating Pads shall be provided
between ebalns used for binding thio load and the pipe when handling pipe.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Elley. No.: 0 Number: ES -4852
Date: 4/17/03 Page: 11 of 43
9.3.3 End hooka, when used, shalt be made of steel faced with a material of equal or lesser
hardness than the material being lifted. Hooks shall be contoured properly' to fit the
inside =wane ori pipe and provide ample holding surikce at each end of pipe joint.
Hooks shall have band holds and mg lines to control suspended pipe. Spreader bars
should be used at the discretion of Client
9.3.4 lined calipers may be used to unload and string pipe of 12 -inch and smaller nominal
diameter.
9.4 Storing and Stacidog
9.4.1 Pipe aba1 be loaded and stacked in suchmanner that flexing and shining of pipe duping
hauling is avoided Cam shoold be exercised In handling or storing of pipe to avoid
distortion, flattening, denting, scoring or other damage. Dropping, dragging or
skidding of pipe shall not be pe®hted.
9.4.2 Stored pipe shall be stacked or nested. Coated pipe that is stacked shall have cross
spacers and be equipped with stops to prevent damage and to prevent pipe from rolling.
These spacers shall be located directly above the bottom bearing strips. Coated pipe that
is nested shall bo separated from each adjacent pipe by not less than three spaods placed
near sack end and in the center of the pipe length for pipe less than 50 feet long. For
pipe longer than 50 feet, spacers shall be placed at least every 20 fad. Padded bearing
strips shall be located below the bottom tier.
9.4.3 Bottom bearing strips shall be blocked to prevent any movement of pipe and to Ment
Inspector satisfaction. The number of tiers of stacked pipe shall be reduced le in Client
Inspector's opinion, there exists evidence of coating damage or pipe deformation. The
height of nested pipe shall be as detailedbelow.
Pipe She (OD) Maximum Number Milers
8 5/8" and smaller 14
10 3/4" 8
12 314" 8
16" 6
20" 5
22" and larger 4
9.4.4 Pipe shall bo racked off the ground in such a manner and location to prevent damage to
and/or contamination of pipe interior or extenlor. Timber skids and/or earth banes shall
be set on no more than 12 -foot centers. Earth berms must bo rose free,
9.4.5 Material shall be placed on (Odds, timbers or dunnage to prevent contact with the ground
and to provide water drainage. Small fittings or supplies and material subject to weather
damage shall be stored in a suitable warehouse provided by Contractor.
9.5 Hauling
9.5,1 Contractor shall furnish n.1 permits required for hauling oxtta wide, extra long or
overweight loads.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION '
Rev. No.: 0
Date: 4/17/03
F
3
Number: ES -4852
Page: 12 of 43 .
9.5.2 Contractor shall provide traffic centtol personnel if required at locations where tacks
enter or exit colon right-of-way Into traffic.
9.5.3 Pipe -truck wheels shall be fitted with fenders and/or gravel guards to prevent damage to
pipe or coaling from gravel impact,.mod and road oil. .
9.6 Stringing
9.6.1 Gaps or openings shallbe left to correspond with ditch crossings for passage of
equipment, personnel or livestock. Pipe shall not be strong along a section of ditch
before that section of ditch is finished unless approved by Client Inspectors. Pipet shall
not be Wrung directly on the ground unless otherwise specified in the Scope of work of
this Contract
9.6.2 Coated pipe shall be placed on skids or earth berms during stringing operations.
Contractor shall pad the "A" frame on side -boons to Client Inspector's tiadslhction.
9.6.3 Pipe shah not be dragged, dropped or scraped against other pipe or against the carrier
while unloading. Pipe remaining on muck during unloading shall be secured at all
times. Care ,must be exercised when stringing pipe to prevent distortion of pipe
ron ndness, damage to bevels or any mechanical damage to Pipe body or ooating.
9.6.4 Daring unloading and stringing operations, Comractor shall allow adequate time for
Client Inspector to inspect pipe and coating. If required by Client Inspector, dents and
gouges shall bo reuwved from a length of pipe by cutting out the damaged portion as a
cylinder, Gouges, scotches and grooves not removed as a cylinder shall be eliminated
by filing to a smooth contour provided the remaining wall 'thickness is not less than the
minimum prescribed.
9.6.5 Coated pipe shall be set an padded skids during laying operation and during stringing
operations where right of way conditions or freezing weather condition warrant deb-
ase to prevent damage to coating.
10. BENDING
•
10.1 Overheads shall be made to allow Installation in sack manner that pipe at the point of bend shall
clear the ditch bosom. At sidebends, pipe shall be bent to allow instillation illation to lie toward, but not
against, the ditch outside wall. Client may provide fabrlcoled bends, as detailed in the Material
section of Ibis Contract, for installation at points described in the Drawinge'section of this
Contract,
10.2 Bending of 12 -inch nominal diameter and larger pipe shall be done by a cold smooth -bending
method using an internal mandrel to produce a smooth, symmetrical bend. A padded bending
shoe shall be used for coated pipe. Na gouging or damage to pipe or coating will be permitted
10.3 Field bends shall not exceed 1 1/2 degrees 1n arty diameter length along the pipe axis.
10.4 Bends shall not be made closer than 5 feet from the end unite pipe or 3 feet from an existing
girth weld.
ENGINEERING STANDARDS
ONSHOBB CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
Number. ES -4852
Page: 13 of 43
10,5 Bends must have a smooth contour and must be ftee of structural damage, cracks, gouges,
wrinkles, egging or curvature deviations. Alter beveling, measurenxeds across the'maxinmm and
minimum diameters of the bent section ofplpe shall not differ more than 2 1/2% of the nominal
pipe dlemeter. Any bends with stnictnml damage, cracks, gouges, wrinkles, egging or omvatare
deviations aball be ad ort and replaced at Contractor expense. Pipe damage due to bending shall
be charged back to Contractor.
10.6 Bends on pipe with a kmgitodimt seam shall be made with the longitudinal seam in the neutral
axis. When beading doable-jo4Wed pipe with lengitudinal seams, the longindlnal seams shall be
located equal distance from the neutral axis.
11. WELDING AND RADIOGRAPHIC PROCEDURES '
11.1 General
11.1,1 This section covers the requirements for Welling ani Procedure Qualification, Welder
Performance Qaalifipdon and the Repair of Production Welds as well as Pipelaying
Operations and Nowdesinxithw Testing.
11.1.2 All welding shall be done in accordance with the applicable pipeline design cods.
Production Welding and Non-destructive Testing shall meet the requirements of API
1104 Latest Edition and Tide 49 of CFR Part 192 and 195.
11.2 Procedure Qualification
I12.1 All welding mealtime alall be qualified by desttucbve testing and approved by Client
prior to construction. Welding Procedures shall be qualified in accordance with AS144B
Sestina IX or API 1104. The Welling Procedures submitted must bo sufficient to meet
all code requirements for the essential variable ranges of the job. The primary welding
process shall be SMAW. Other processes may be used with Client approval
11.2.2 Subject to Client approval, Contractor may, at Contractor cost, elect to qualify its own
weldingprocedures. Prior to project weldingg. Client shalt be allowed reasouabk time to
review the welding procedure for written approval/disapproval Client will witness the
set-up, welding, coupon removal and destructive testing, indndiog approval of the test
nipple material for procedure quallfitatlon testing. Welding procedures not witnessed
by Cheat will not be accepted Contractor may also nae a Client approved independent
testing let.
112.3 Any requested variable change shall be submitted to Client far review and approval
prior to Welder Qualification and Prodoedon Wefdhng.
11.2.4 The selected and approved Welding Proredmes must be adhered to at all times. Welds
made that fall outside the parameters of the essential variables allowed by the applicable
welding code and this specification shall be removed and replaced.
11.2.5 The welding of base metals below 42,000 psi shall use E4010 electrodes with minimum
epecioed yield sbength of 42,000 psi for the root bead and E-7010 electrodes An the
balance. Travel speed shall be 6 to 15 inches per minute RM.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
. ENGINEERING STANDARDS
Number, ES -4852
Page: 1
Rev. No.: 0
Date: 4/17/03
11.2.6 The welding of baso metals with a minimum specified yield strength greater than 42,000
psi and less than 60,000 psi shall use E-6010 for the root bead and &7010 or 13.8010 for
the balance. Travel speed shall be 6 to 12 IPM and the root bead travel speed shall not
exceed 15 IPM.
11.2.7 The welding of base metals with a minimum yield strength of 60,000 psi and above shall
nsa &6010 for the root bead and E-8010 for the balanne Travel speed shall be 6 to 12
IPM and the root bead travel speed shall not exceed 13 IPM
11.2.8 All base metals shall be pre -heated to remove moisture when ambient temp is below 50
degrees Fahrenheit. For X.60 base m ateaiais a minimum pm -beat of 150 degrees
Fahrenheit shall be used. Por X-65 and.]- 70 base materials a 200 degree Fahrenheit
minimum preheat shallbe used.
112.9 If any of the following essential variables are changed, a newwelding procedure shall be
qualified:
• Achange intravel Brad
• A decrease of more than 100 degrees F pre -heal
• A change in base metal thickness qualified
11.2.10 Welding equipment and material shall be of a size and type specified in the approved
welding procedure.
• 11.3 WelderQmEBaUions
•
113.1 All welder performance qualification tests shall be conducted in the presence of the
Client Welding Inspector prior to production welding at Contractors' expense. Such
testing may be terminated at any time if in the opinion of the Client Welding Inspector
the Weider does not have the necessary skills. '
11.3.2 Performance qualification shall be done by destructive testing. Qualification by
radiography shall not be permitted. Welders falling perronnarree kat shall be
disqualified
11.3.3 All welders shall be required to qualify in accordance with '"The Client (TWC) Welder
Qualification Test" or API 1104 Multiple Qua1fcafon Test All Groove Weld Tests
shall be done in the 60 position.
•
11.3.4 The Client qualification test shall consist of a 12" buttweld in the 60 position having a
wall thickness of .375` minima or the Ent pipe used for the prgiect. The test shall be
made with Or -B material as a minimum, using E-6010 electrodes for the root bend
using &7010 or 8-8010 for the balance. This will allow a contract welder to weld on
compressor station and pomp station piping down to 2 112" nominal O.D. up to an
unlimited diameter. It will allow the welder to weld on all API line pipe using E-6010,
E-7010 and E -80i0 electrodes up to a wall thickness of ,750". This qualification will
not allow a welder to weld with E-7018 electrodes nor will the welder be allowed to
weld in a ASMB 8313 Process Piping facility. The destructive testing required for this
test shall be two root bends, two face bends and two nick breaks as described in Client
procedurn
ENGINEERING STANDARDS
Number: BS -4852
Page; 15 of 43
ONSHORE CARBON STEEL PIPEUNB INSTALLATION
Rev. No.: 0
Date; 4/17/63
11.3.5 Welder performance qualification tests shall be renewed every six calendar months by
radiography. In the event a welder cerditation expires, iter welder shall be required to
quality again by destructive testing ReceiNflcatton of welders shall be done by a Client
representative.
11.3.6 Any welding per%omwd by welders who have not been qualified prior to the start of
Production shall be removed. All performenoe teals must coves all essential variables for
the Job. A copy of all qualification records shall be kept in the project file.
11:4 Welding
11.4.1 A11 welding equipment shall be of the size and typo suitable for the specific work or
project Electrode holders used shall be insulated All equipment shall be maiWataod in
such condition tato ensure acceptable welds, continuity of operation and safely of
personnel IL in the opinion of Client any equipment does not meet the above
requirements or appears defective, the equipment shall be repaired or replaced by
Contractor at its etpex e.
11.4.2 During production welding, the Client Representative may request immediate
regnalifrcation or disqualify any welder who produces nnacoeptable welds or may not
have the neoessarystalls even though his qualification is meat
11.43 Welding outfaces shall be Smooth, nnlform, free of fins, laminations, tears, scab slag,
ori, grease, paint, dirt, moisture and any other foreign material that might adversely
affect welding or weld quality.
11.4.4 The electrical ground confect point shall be made of a material grade not greater than
that of the line pipe material The ground shall bo securely fastened, bit not welded, to
the work and shall fit in sack memer to prevent aro hums. This =tact shall be large
enough to prevent local overheatbsg or arcing between the contact and work Magnetic
ground damps or magnets of anykind arenot allowed onthe pipe daring welding.
11.4.5 Ate stokes or dragging of electrodes on the surface of the work will not be permitted.
Arc spiking shall be confined within the welding groove. Any arc stdke ocandng
outside the weld bevel area and any aro bum on a finished weld resulting in pitting or
weld metal loss shall be col out or repaired at Client discretion. The repair ad' any aro
bum shall be done in accordance with. a Client approved repair procedure.
11.4.6 Covered electrodes that have been wet, have clopped or damaged caapngs or show
deterioration shall be discarded and removed fromprgjeet
11.4,7 As required by the qualified welding pyre, Commator shall lade any '-
hydrogen type covered electrodes In hermetically sealed, moisture proof containiers.
Contractor shall provide appropriate holding ones or warming cabinets Mot boxes
for storage of low•bydrogen electrodes after container has bean opener. electades abaft
be stored al a temperature of 350 degrees Fahrenheit -W. 50 degrees Fahrenheit Unused
low -hydrogen electrodes shall be marred after 2 hours exposure, to a separate redoing
oven maintained at 330 degrees Fahrenheit +1-50 degrees Fahrenheit fru a minimum of
8 horns beam reissuing. 'All decliodes considered by Client to be of questionable
dryness or quality shall be discarded.
ENGINEERING STANDARDS
ONSi1ORR CARBON STEEL PIPELINE INSTALLATION Rev. No.: 0 Nimbi: ES -4852
Date: 4/17/03 Pago: 16 of 43`�
11.4.8 If ambient moisture conditions dictate, Client may require storage of all coveted
electrodes in holding ovens alter mntainor has been opened. All celialosio (BXX 10)
electrodes shall be stored at a temperature of 50 degrees Fahrenheit to 100 degrees
Fahrenheit
11.4.9 Preheating of pipe shall be done to assure no moisture is present In base metal prior to
welding Specific regrdrements and temperances shall be stated in the approved
welding procedures. Other conditions may exist when Client wilt require preheating.
Pmheadng may be accomplished using a Client approved method. Oil bureau will not
be permitted. Preheating temperatures shall be checked with temperature indicating
anyone, thermocouple pyrometers or by other Client approved methods. Tho preheated
area shall extend et least two (2) inches on each sire of the weld end shall be uniform
mound the pipe.
11,4.10 The maximum distance between hot pass and fillkap shall be no more than one day's
average progress of the firing line if the general weld quality is acceptable to Client If
the weld quality ie unacceptable, Client reserves the right to reduce this distance until
any welding problems aro corrected. Once deposition of root pass has been started, root
bead and hotpass shall be completed
11.4.11 Slag and remaining flwc shall be removed from each weld pass using hand power tools
prior to deposition of additional weld metal. Visible defects such as slag cavities, cold
laps, surface porosity, starts, stops and high pointsshall beremoved bygdndlo,g,
11.4.12 Tlcln welds shall be completed without interruption once welding is started.
11.4.13 Any two adjacent or successive weld beads shall not be started or stopped at the same
location.
11.4.14 Backwelding shall not be permitted as a routine welding procedure. Backwelding may
bo allowed for fabricated assemblies, fittings installed in the pipeline and pipeline weld
repairs at Client discretion. Suitable backwelding methods shall bo used and shall.bo
approved by Client prior to use. Any backwelds not produced fa accordance with this
requirement shall be removed. •
11.4.15 A flame -proof protective blanket shall bo used to cover coated pipe fbr a minimum. of 2
feet Rom coating cut back unless otherwise approved by Client.
11.4.16 The completed weld shall have au essentially uniform appearance around the entire pipe
dna The weld surface and surrounding arca shall be essentially flee of weld
spatter. The completed weld aball be bashed and cleaned thoroughly prior to weld
inspection.
11.4.17 Client shall have the right to inspect welds by both visual and radiographic means (or
other non-deehnclive methods). Inspection may occur before, dmieg and after welding
operation&
11.4,18 Used welding rods shall be placed in an appropriate receptacle and removed Flom the
job site.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Nmnber: ES -4852
Page: 17 of 43
Rev. No.:. 0
Date: 4/17/03
11.5 Non -Destructive Testing and Personnel Qualifications
11.5.1 All production radiography shall meet the requirements of API -1104 "Standards of
Acceptability" and also meet the requirements set forth in the applicable part of Title 49
of the Code of Federal Regulations part 192 and 195.
11.5.2 Cheat shall reserve the right to inspect the quantity of welds of up to and including
100% if necessary to assure acceptable weld quality. All welds require visual
examination.
11.5.3 Client reserves the tight to remove production welds from the pipeline and subject them
to destructive tests. Such tests shall t the requirements set loath in API 1104. Any
welds that do not meet the requiremeats of API 1104 shall be replaced by the
Contractor. Client shall reimburse Contractor for any welds that meet the above
requirements.
11.5.4 Client shall have the final decision on weld acceptability. Any welds not meeting the
standards of acceptability shall be repaired or replaced by Contactor. Where the length
of undercutting is judged by radiography, mechanical gement is not permitted, and
only the length criteda in API 1104 "Standard of Acceptability' shall be acceptable.
11.5.5 The repair of any welds shall not be done without Client approval.
11,5.6 All non-destn dive testing pommel shall be minified to the requirements ofANST. TC -
IA. All NDT testing prasonnd mast have a copy of their qualification and certification
records available for review while on the project Failure to have the required records
are grounds for removal from the project.
11.6 Pipelaying
11:6.1 Each pipe joint interior shall be visually inspected and foreign matter shall be removed
immediately prior to installation. Contractor shall be responsible for removing any
obstructions imide the pipeline that could inhere with dealing filling, de -watering of
drying pigs used in testing operations.
11.6.2 Ends of each joint of pipe shall be cleaned properly prior to allgnmoat and welding.
11.6.3 Contractor shall reasonable precautions to keep plpdine flea from dust, dirt,
debts or any other foreign material daring work. Open ends of welded sections of pipe
shalt be dosed with a night cap. Night caps shall be installed before the end of each
working day and shall be watertight when /mated below -grade. Pipe shell be
supported in such manner to assure the section will not endanger job -site personnel and
the coating will not be damaged due to expansion and contraexlon or any other pipe
movement Whore passage, pipe support should be placed approximately 8 feet front
each field girth weld
11.6.4 Pneumatia/hydraulic internal line. up damps shall be used for 12 -inch nominal diameter
and larger pipe. Internal lineup clamps mast be kept clean to minimize high -low.
External line-up damps may be used for tle4ns, projects less than 1,000 feet In length
and fabrication. Removal of line-up clamps daring welding shall follow approved
welding pro .
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Rev. No.; 0 Number: E&4852
Date: 4/17/03 Page: 18 of 43
11.6.5 Heating to force proper alignment for welding is prohibited Hammering the pipe to
attain alignment shalt be Wept to a minimum
11.6.6 When welding in a bell hole or other tie-in situation, pipe movement shall be held to a
minimum anal the root pass and the bot pass are complete.
11.6.7 Undamaged pipe 10 feet or more in length shall be moved ahead and installed in the
pipeline.
11.6.8 Immediately after pipe -lay completion, Cofactor shall tenon surplus line pipe, cutout
rings and dein pups to the location specified in the Material section of this Contract.
11.6.9 Welded pipe shall be aligned so losgWdival seams will be located on the top of the
pipeline within 30 degrees of the vertical. Successive Joints of pipe shall be rotated so
longitudinal seams of two successive joints of pipe shall not align with each other.
! Bnimum separadon between weld seams shall be 20 degrees.
11.6.10 Contractor -prepared bevels, both internal and external, shall be made by machine -tool
or machine -oxygen culling. Thdemal bevels shall be 30 degree grooves, +5 degrees and
A degrees, with 1/16 -inch root face.
11.6.11 If Client uses Imemal-crawler type radiographic inspection, pipe section length shall not
coxed crawler's capability and pipeends shall be within 4 feet of tbe green&.
11.6.1.2 When pipe is welded above ground, a minimum clearance of 16" shall be provided.
When welding is ditch, bell hole shall be sufficiently sized to pemdt access for all
welding operation.
11.7 RepairofWelds
11.7.1 This section establishes the minimum requirements for repair or removal of
unacceptable wekls made daring the wastnietion of pipeline systems designed in
accordance to ASME B31.4 'Liquid Dansporiadon Systems for I3ydrocerbons, Lirpdd
Petroleum (las. Anhydrous Ammonia and Alcohols ASMB B31.8, °Gas Transmission
and Dlam'budon Piping Systems' and Title 49 CPR, Part 192 and 195, and Gag
Transmission and Ais[ttbntian Piping Systems.
11.7.2 These requirements also shall apply to the shop and &ld repair or removal of
unacceptable welds made by pipe manufacturers or fabricators who provide mill jolnbers,
double -ended pipe lengths, Held double -end welds and field- or shop -fabricated
assemblies.
11.73 Repair of longitudinal or spiral weld seams and weld repairs to the pipe body, fillings or
other components will not be permitted and is not considered a part of this Specification.
11.7.4 Repair methods described herein ' arc not intended as a justification for poor
workmanship. Any person rely performing substandard work shall be removed
from Client projects and their Welder Qualiflcatloa Card shall be suspended
. ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION Rev. No.: 0 Number: BS -4852
Date: 4(17/03
Page: 19 of 43
11.8 Repair of Welds - Applicable Specifications
11.8.1 Repair work shall comply with the requirements of this Section and, where welding la
required, API Standard 1104, latest edition accepted by Client, "Standards for Welding
Pipelines", applies.
11.8.2 Where provisions of this Section are more stringent than those la the abovereferencFd
spedficadon, provisions of this Specification shall prevali. Where a conflict exists
between specifications, the more stringent requirements shall be followed as determined
by Client
11.9 Definitions
11.9.1 Comaleted Weld - When the required filler material has been deposited; is, the gtoove
or weld cavity has been filled, including reinforcement and otter workprior to visual or
non-desrmctive inspection.
•
11.9.2 Reject - When a completed weldor completed repair weld is visually or non-
destructively inspected and found to contain defect(s) exceeding acceptance limitatiom(s)
of the applied code or specification.
11.9.3 Rework - When additional grinding, chipping, slapper welding, uuderfill welding and
back welding (when permitted) 1s performed on a weld after iia completion and
Inspection. Such rework is not considered repair for purposes of applying the repair
provisions of this Spedlcadoa.
11.9A Rerr • When weld metal excavation and redeposit by welding are performed on a
completed weld for purposes of ooaecting rejected weld defects Identified dnriog visual
or non-destructive inspection lyClient
11.9.5 Q1=1 - Complete removal of weld by removing as a cylinder. (See Cutouts part of this
Section.)
11.10 Repair, Rework, and Replacement Methods
11.10.1 Any weld 'determined by Client to be unacceptable shall be repaired, reworked or
replaced by the following methods:
a) Reworked by power grinding of sorfam defects (see Repair by (binding part of
this Section) or '
b) Reworked by weld dripper passes for elimination of oxtennai =dent, and
weld passes for m iderHE, and backweiding to eliminate internal surface
conditions where practical and permitted by Client (see Repairs by Weld
Stripper Pass and Baccwelding part of this Section).
11.102 These methods shall assure oongilete defect removal and shall be performed according
to this Specification.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Ret No.: 0
• Dale; 4/17/03
Number. ES -4852 •
Fs:
11.11 Repairs by Grinding
11.11.1 Minor surface irregularities and defects, except cracks, detectedvisnally or by other non-
destructive methods, either in root or capping passes, may be removed using a power
grinder. The ground area shall blend smoothly with adjacent pipe or weld surfaces. An
ultrasonic this gauge shall verify that the remaining wall thlamess of the pipe and
weld, alien grinding, falls within minimum design require. .
11.11.2 If grindicg is performed as a consequence of nomdestactive examination, then the
affected repair area shall be re-examined according to Non -Destructive Examination
part of this section. Additional surface nondestructive examination (or leading) may be
required to verify defect removal and check surface conditions.
11.11.3 If grinding fails to eliminate the defect, or if the remaining wall thickness in or
immediately adjacent to the original weld is less than the minimum design
requirements, a weld repair may be attempted according to Repairs by Welding part of
this section
11.11.4 Grinding shall not constitute a repair under the multiple repair provisions of this
Specification.
11.12 Repairs by Welding
11.12.1 Weld desats, except cracks, detected on capping pastes or root -pass sum, which
may be repaired by stripper passes or backwelding, may not require removal prior to
repair welding when Client approves such procedure. Backwelding as a repair method
shall be subject to that approval
11.122 Other weld defects shall be removed entirely by power grinding. Where permitted by
Client, oxygen culling or air carbon -arc gouging also may be used for deflect removaL
When oxygen cutting or air carbon -arc gouging is used, welding surfaces shall be
cleaned thoroughly down to bright metal. Slag, seals, dirt or other foreign matter shall
be removed oompletety.
11.12.3 The repair easily which results from defect excavation, shall have a abape similar to the
original bevel configuration. The cavity shall be blended emootbly into surrounding
weld metal, adjacent pipe walla and surfaces.
11.12.4 A through -wall, "open bort," repair cavi is patterned provided the following
requirements are met
a) The width tithe resultant root opening aball not exceed 1/8 Each.
b) Weld'metal in the mot pass shall be redeposited using the stringer bead
technique,
11.125 Nora crack or other planar defect repair, non rive examination, or testing, of the
repair cavity prior to welding may be regtdred by Client to ensure complete defect
removal
11.12.6 Client shall specify methods of non-destructive examination.
11.12.7 Repair welding operations shall be protected from wind, rain and other conditions that
may have a detrimental effect on weld quality.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0 Nar*ar: ES -4852
Date: 417103 Page: 21 of 43
11.12.8 Welding surfaces shall be smooth, uniform, free of fins, lamination; tears, scale, slag,
oil, grease, paint, dirt, moisture and any other foreign material that might adversely
affect welding or weld quality.
11.12.9 Where Client permits internal backweldiug on internally -coated pipe, coating shall be
protected from weld spatter and mechanical abrasions,
11.12.1013sch repair area shall be preheated as follows:
a) A mtniamnt 3 -inch wide band on each side of the repair cavity and a mint®
distance of 4. inches beyond repair cavity extremities, including feathering,
shall be heated mike* Maximum thwaature differential between any two
points should not craved 50 degrees Fahrenheit
b) Entire repair area shall be preheated to 250 degrees F, unless otherwise
specified in the apprmred welding procaine used
c) Preheating may be accomplished using any Client -approved method. OR
bunters will not be permitted.
a) Preheating temperatures maybe checked prior to the start of welding by use of
tempadure-indicating canyons, thetmoctuple pyrometers or by other Client -
approved methods.
11.12.11 When Client or the approved welding procedure requires post -weld heat tmetmeat,
repair welding shall be completed prior to final heat treatment Any repair welding
. pedbrmed after heat treatment shall be reheat treated.
11.12.12Each repair weld pass shall extend beyond both the start and the stop of any metal
excavation.
11.12.13Each.tepair weld pass shall be power -brushed and carefully visually inspected. The
mmrber of weld passes will vary depending on defect depth and cadent of material
removed.
11.13 Repairs by Weld Stripper Pass and Backweldiag
11.13.1 Where permitted by Client, a stripper pass may be used to eliminate unaeeePiable
external conditions.
11.13.2 Where permitted by Client, ba&welding may be used to eliminate au able internal
oondidons or to complete the weld on transitions of fittings to pipe. Internal back
welding shall be witnessed by Client and, where practical, Brom inside the pipe.
11.14 Ortouls
When it 1s determined that a cutout is required, the entlre weld shall be removed and repined as
a cylinder with a minimum length of 3 feet Sufficient pipe material shall be removed on each
tide to assure complete defect removal, elimination of grind or deposit repairs and elimination of
any appaient thermal damage to surrounding pipe Rom previous defect removal steps.
11.15 Repair Restrictions and limitations
Multiple repairs are not permitted by Client
ENGINEERING STANDARDS
Number: ES -4852
Pale: 22 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date; 4117/03
11.16 Repair of Cracks
Client may anthorize repair of cracks. Prior to repair, the cause of the crack shall be determined
and corrective action shall be taken to avoid Mare cranks. When evaluated on an individual
basis and approved by Client in writing, a weld casco may be repaired provided firs credo is not
more than PA of the total weld length (see Weld Repair Limitation Table). The provisions of
API Standard 1104, latest edition accepted by Client, Seca 7.Z must be satisfied If these
requirements cannot be met, the entire weld must be cut out as described in Section 11.14.
11.17 Maximum and Mecum Repair Length Areas
11.17.1 The maximum length of any individual repair area (except for crack repair), shall not
exceed requirements specified In Weld Repair Limitation Table for the particular pipe
diameter being welded. If these requirements cannot be met, the entire weld shall be cud
out as described la Section 11.14.
11.17.2 The minimum length of any repair weld shall be two Inches.
11.18 ' Maximum Number offepalr Wed Areas
11.18.1 If excessive weld reject rate occurs, Clint may require Contractor to provide plans to
improve quality ofweid&
11.18.2 The maximum rumba of repair weld areas per weld shalt not exceed requirements
specified in the Weld Repair Limitation Table for the pardon/sr pipe diameter being
welded.
11.183 If these requirements cannot be met, the entire weld shall be cut out as described in
Cutouts part of this Section.
11.19 lvfmirnnm Separation Between Repair Arras
When two or mare repair areas require weld metal deposition, they shall, if practical, be
separated by a leagth of unopened weld metal no less than 3 inches.
11.20 Non -Destructive Eamon ofRepaire
11.20.1 Weld repairs will be ma -destructively tested by the same method used for original
C) may require additional methods. The attire will be inspected;
the repair aree(saloneald
may inspected provided a mhdmum of 2inches of original,
amplified, weld metal also is ensrained at each wehl repair extmmity.
radiography is used, the film Image shall idem clearly as a If 81m
.
11.20.2 Defect acceptance limits shall be the same as those applied to the original elation
11.21 Hot Work
11.21.1 Hot work, including hot cub and ]rot taps, shall be conducted according to Client-
approyed procedures and as directed by Client
11.21.2 Contractor shall fantail at least 3, 30 -pound "A-B.C' fire extinguishers. Contractor
shall knish otter equipment and matexlal necessary to safely complete the hot work.
ENGINEERING STANDARDS
Number: ES -4852
Page: 23 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
11.21.3 Prior to performance of hot work, Contractor shall assist Client in the preparation of an
acceptable workplan for each project to be performed.
WELD REPAIR LIMITATIONS"
NOMINAL PIPE TOTAL MAXIMUM MAXA4UM MAXIMUM
DIAMETER WELD ALLOWABLE REPAIR NUMBER
(inches) LENGTH CRACK LENGTH AREA OF REPAIR
(inches)** (inches) (inches) AREAS
41/2 141/8 11/8 41/2 1
6 5/8 2013/16 15/8 5 1
8 5/8 271/16 21/8 5 1/4 2
10 3/4 33 3/4 211/16 5.1/16 2
12 3/4 40 3 3/16 5 3/4 3
14 4315/16 31/2 6 3
16 501/4 4 61/4 3
18 561/2 41/2 61/2 3
20 6213/16 5 6 3/4 3
22 691/16 51/2 7 3
24 75 3/8 6 71/4 3
26 8111/16 61/2 71/2 3
30 941/4 71/2 7 3/4 3
34 10613/16 81/2 8 3
36 1131/16 9 81/4 3
+Backweld, shipper -weld and grind only repairs are exempt from this Table.
+a Total Weld Length = Pipe Diameter X3.1416 (rounded down to the nearest 1/18 of an inch)
12. COATING
12.1 'Selection of coating material, surface preparation and coating application for field joints and
repair of coating ate specked in Standard ES -4024 entitled Field Joint and Repair Coatings
This specification also provides the required holiday detector voltage for a gtven thickness of
coating, the frequency of testing detector voltage during a project and the equipment to test the
voltage.
12.2 This Contract is structured using pipe with plant -applied coating for the project
12.3 After welds have been inspected radiographically and/or otherwise accepted, Contractor shall
provide labor and equipment to dean and coat all field joints, bare pipe, valves and fittings
according to Client specifications.
12.4 The pipeline, including all field joints, wilt be inspected, in the presence of the Client Inspector,
with a holiday detector calibrated for the type and thickness of coating used on the pipe.
Contractor shall use a voltmeter to check the detector's voltage once at the start of the wok day
and once in the afternoon.
12.5 All holidays, imperfections and damaged areas shall be carefully identified with a waterproof
marker.
12.6 Damaged areas of the coating shall be repaired according to the above -referenced Client
specification for that particular type of coating.
ENGINEERING STANDARDS
Number BS -4852
Page: 24 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4117/03
13. LOWERING -IN •
13.1 No pipe or fittings shall be lowered into the ditch without Client's Inspector's presence. Pipe
shall be 100% Inspected with a holiday detector immediately prior to lowering -1n.
13.2 Rodes, largo clods, stamps, pmjeeting rocks, sklde, trash and other foreign material that may
damage the pipe or coating nmst be removed from the ditch prior to lowering the pipe into the
ditch. If the condition' of the ditch is such that the pipe or coating maybe damaged by placing it
dhectly on the bottom of the ditch, then pipe must be supported at least Eli des above the ditch
bottom and placed with at least 6 inches of clearance at the sidewalk. Pipe maybe supported by
any method specified below.
• Soil pillows (rode free, 15 to 18 foot centers)
• Sand bags (15 to 18 foot centers)
• Full bottom Soil padding (rode free) (see Padding, BEIM, and Ditch Breakers section of
this Specification)
• Any other Client -approved method
13.3 Pipe supports installed in cold weather shall be made of a material that shall not freeze. Material
subject to freezing stall be installed and backfilled before freedng weather occurs. •
13.4 Water, snow and civets &ball fie removed from the ditch prior to loweting-in. •Removed water
aballbehandled 'according to Water Cros Crossings section of this Specification
•
13.5 Contractor equipment shall be sufficient in capacity and quantity and spaced at intervals
sniff deet to prevent dropping, sliding, overturning or buckling of the pipe section being handled.
Pipe shall be lifted, without dragging, from skids and shall be placed, without dropping, into
anter of ditch gradually and uniformly without allowing pipe to touch ditch walls.
116 Coated pipe shall be handled at all times with cradles, slings or belle, all of which shall be
specific' designed to prevent damage to pipe coating
13.7 If pipe or pipe coaling is damaged or suspected to be damaged, Contractor shall replace the
dama8vd PIP =diet � Coating shall be repaired as spectfed in the
Material section of ibis Contract. Repairs •shall be Inspected with a holiday detector.
Replacement and repair costs are Contractor's responsibility. Procederes and coalitions ons causing
such damage shall be corrected
13.8 Pipe shall lay u near to the center of the ditcb as possible. Ovntbends shall be installed in such a
mamcer that the pipe at the point of bend shall dear the ditch bottom. At aldebends, pipe shall be
installed to lie toward but not against the outside ditch wall. Saga shall rest on the ditch bottom.
13.9 The use of mechanical means to force pipe down shall not be allowed
13.10 Lowered -in pipe shall to restrained properly from contacting the ditch wall. Client may approve
sandbags or other means of support to ensure pipe shall not touch sidewalk.
13.11 Nightcaps shall be installed before the end of each working day and shall be water fight when
••••••,-, added below grade.
ENGINEERING STANDARDS
Number: ES.4852
The: 25 of 43.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
14. PADDING, BACKFILL AND DITCH BREAKERS
14.1 Padding and bacdill shall follow closely behind lowering -in so tbat a minimum length of ditch is
open at anytime', however, Contractor shall allow Client surveyors adequate time to perform as -
built survey before padding or backfilling pipe.
14.2 Conhactot shall not backfill any portion ofpipeline unless a Client Inspector is present.
14.3 • Extreme care shall be exercised in back illlng to prevent damage to pipe and coating. If pipe or
14.4 Immediately before padding and hadc6Wng, ditch and backfill material shall be inspected and
rocks, large Bods, stumps, skids, trash and other foreign material shall be removed.
•
14.5 water and snow shall be removed flumthe ditch prior to and during backfilling, except at stream
. and river crossings. Removed water shall be handled aocmdingto Water Crossings section of this
Specification.
14.6 In rocky areas or if required by a -Client Inspector, Contractor shall padtha pipeline immediately
after lowering4n to protect pipe and coating from failing nock. Rock shield may be used in lieu
of earth padding with written Client approval.
14.7 Baden wader, around and .up to a minimum of 6 inches over the top othhe pipeline shall be of
• solea material with saf'icient Boll in the mixture to prevent any void spaces beneath the pipe and
damage to the pipe coating as the select backffit is placed in the ditch. No rock larger than ant
and a halfi ekes, hard clods or other hard objects shall be permitted in select backfill area.
14.8 If select badkffil material cannot be obtained from excavated spoil, a padding machine shall be
used or padding material shall be hauled in and placed gond the pipeline. Padding shall be
placed at least 6 inches below, around and above the pipeline.
14.9 Hauled padding material shall be approved by Client prior to Contractor purchase or use. Off
right.& -way padding borrow sites (except licensed, eonmrercial operations) must be cleared and
approved by permitting agencies and Client prior touse,
14,10 Shaving or caving of ditch wade for padding material is not permitted. Segregated top soil from
the fight way shall not be used as padding nmateriaL
14.11 Unless otherwise specified in the Right-of-way and Permit Stipulations Se tion of this Contract,
rock 12 inches in diameter or leas taken from the ditch may be replaced in the ditch at least 6
inches away from the pipe, up to °Adshes rock level.
14,12 Unless otherwise specified, badkfili compaction shall be equal to that of the undisturbed area
across eultivated land, hayfields, pastures and residential land. The badcflu shall be compacted
sot* at crossings of terraces, levees, canals and ditches.
14.13 In meas where the pipeline crosses under foreign lines and field d1es the ditch shall be backfilled
w1W approved material and compacted to prevent settlement
ONSHORE CARBON STEEL PIPELINE INSTALLATION .
ENGINEERING STANDARDS
Number BS -4852
Date: 411103 .ao: 26 01 43
Rev. No.: 0
14.14 Ditch breakers shall be applied and Installed by Contractor as imitated in the Drawings or
Right -of -Way and Permit Stipulations sections of ibis Contract, or as directed by a Client
Inspector. Topsoil shall not be used to fill sacks.
14.15 If erosion control stmchnes, are damaged, Contractor shall immediately make repairs, including
extenelon of temporary diversion terraces across the right-of-way.
15. ROAD, RAILROAD, FOREIGN LINE AND UTILITY CROSSINGS
15.1 General
15.1.1 The method required for cansinoction of each crossing shall be shown in the Drawings,
Right -of -Way and Permit Stipulations, or Scope of Wo* section of this Contract
Contractor shall comply with •all crossing penult requirements and resections, and shall
notify Client so that Client can appropriately notify the authorities, as spec fled in
crossing permits, prior to staRedconstruction Contactor shall not excavate a crossing
without Client approval. Recall of crossings shall be maintained by Contactor until
final completion and acceptance of work
15.1.2 Ditch shall be backfilled immediately following the installation of pipe.
15.1.3 Crossings are to be maintained continually until completion.ofwork.
15.1.4 When Contractor most cross ova railroads with equipment at locations other than
pabiic aossings, Contractor shall meet requirements of each railroad and shall acgrdte
necessary permission and aball pay neeessmy foes. Suitable measures stall be used at
all times to prevent damage to roads and railroads when crossing with construction
equipment Contractor shall provide and maintain In safe condition the temporary
approaches to auy crossing of public roads, private roads and railroads opened for
contauctimo.
15.1.5 Contractor shall place and maintain ilaspersons, signs, barricades, guard rails, safety
fences and signals at road crossings white were progresses as required by city, county
and state rugolalbna, the Right -of -Way and Frit Stlpslations section of this Contract
and Chau. In tiro absence tit' suck regulations, Contractor shalt phaco danger signs
visible In both dlmtions.dudhg darkness at the crossing location, and also 500 feet in
each direction from the crossing. As it minimum, the danger signs dell be legible at
100 feet and flashers shall run continnonsly from 30 minutes before sundown until 30
=tea niter make;
15,2. Bored Crossings
Bore pipe aball be at least the same size as the crosdag pipe including any external waling -
After boring bas been completed, the crossing pipe stall be welded to the bore pipe and pulled
into place. No boring or auguring shall take place tuough carrier pipe that will become part of
the permanent installation
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Dale: 4/17/03
Number: ES4852
Page: 27 of 43
15.3 Cased Crossings
15.3.1 Where pipe is installed Ina casing, the resistance ofthe pipe to the casing shall be tested
after installation but prior to the time the pipe b tledan on either side. The best shall be
conducted with either a Mar and Razor Model C31 -1T insulator tester or a Gas
Electronics Model 702 insulator tester; in the presenco of the Client Inspector. If the
casing is favnd to be shorted to the carricrpipo, the Contractor shall determine the cause
and make nocessaty repairs.
15.3.2. All torch cutting or welding on Ibe casing pipe shall bo completed prior to insertion of
the coated carder pipe. The casing pipe shall be welded into a continuous length butte
insertion into the casing When caring insulators are to be used on the carrier pipe, the
coated cancer pipe shall law in abrasion coating applied over the corrosion coating of
15 to 20 mils thickness using Poterraete 1 or Lilly 2040 coating according to the
madam instructions. Mewing insulators aro not used, the abredon coating shall
1* 140 mils in thickness or shall be 1.5 Indies of concrete. Atter the casing and carrier
pipe have been installed under the mad or railroad, the ends &the casing shall be sealed
at each end with a casing seal as shown in the Drawings section ofthis Contract
15.3.3 Casing pipe shall be welded into a continuous length. Torch catling and welding shall
be completed prior to insertion of the muter pipe. The carder pipe for cased road
crossings shalt be coated accorging to the Coating section ofttds Spedfcadon. Carrier
pipe with insulators shall be Installed is rho casing pipe as shown is the Drawings
section of this Contract, with care taken not to damage hunch[ rs. currier pipe or
protective ming. Should damage result, Contrada shall =ova repair and reinstall
new carver pipe. After casing and carder pipe have beat hastened under the road or
railroad, space between' the carrier pipe and casing shall be sealed at each end with a
casing seal as shown in the Drawings section of this Conriact.
15.3.4 For bored cased arisings, carder pipe and casing shall be supported adequately at each
side of the crossing to prevent the pipe from senting am sharingto the casing as shown
in the Drawings section of tile Contract or as approved by Client Inspector. These
supports shall be placed beneath the rmrler pipe immediately outside of easing pipe and
at ten4bot intervals until the ceder pipe rests firmly on the trench bottom.
15.4 Foreign Pipeline and Utility Crossings
15.4.I A mWmnm of 24 inches of clearance is required In accordance with the Ditching
section of this Specification unless otherwise speaded by Client. This clearance maybe
maintained by ea*C.breakore.
15.4.2 M foreign pipeline crossings test leads shall be installed as shown in too Drawings and
per the Right -of --Way and Phan$ Stipulation sections of this contract These wires shall
be brought aboveground and attached boa temporary poet set securely in the ground.
The cleanup crew wilibe notched of the existence of these posts and shall tato sure not
to disturb them daring clean np. The Right -of -Way and Permit Stipulations section of
this Contract may prohibit placement of posts in open fields and may require placement
at other locations.
ENGINEERING STANDARDS
Naar. Bs.4852
Page; 28 of 43
ONSHORE CARBON STEEL PIPEIdtE INSTALLATION
Rev. No.: 0
Dale; 4/17103
16. WATER CROSSINGS
16.1 Water crossing locations will be identified in the Drawings or Right-of-way and Permit
Stipulations section of this Contras.
16.2 Client may elect to use concrete -coated pipe, set -on river weights, bolt -on river weights or other
means of obtaining sufficient negative buoyancy of the line, as shown in the Drawings section of
this Contract Client -supplied material will be specified in theMaterial section of this Contract.
16.3 Except where otherwise specified, Contractor may propose the method of each water crossing for
Client appmvat.
16.4 Where federal, state or local permits do not specify the method of water crossings, Contractor
will perform the work consistent with regairements outlined in the Right -of -Way and Permit
Stipulations section of this Contras. Any deviations from the rppdrements ®st be requested in
writing by Contractor and appmrved in writing by Client. Approval shall be at the sole discation
of Client Compaction percentage shall be equal to or above that of the nudistmbed areas shown
in the Drawings section adds Contras.
16.5 Unless otherwise specified, all stream banks shall be restored to the original grade and all foreign
objects shall be removed from the stream. Repairs for an open -cut canal shall include, but not be
limited to, wechanirnl compaction, sack -breakers and Installation of bentonite, or equivalent, on
the face of levee banks and canal bottom
16.6 All equipment used in water crossings shall be in good operating coaditionand fine of fluid leaks
that may sauce contamination
16.7 Contractor shall portect any adjacent pipelines to allow them to remain in service during the
installation of the new pipeline clawing.
16.8 The pipeline ditch shall be excavated to a bottom width at least 12 inches greater than the
proposed pipe outside diameter or to a greater width to allow proper backfin beneath and along
side the pipeline. The section of pipeline installed across water crossing beds shall be weighted
with concrete weights, mechanical amines !edea concrete coating, as shown in the Drawings
section of this Contract or as directed by Client When water main ditch excavations contain
rock, pipe protective coating will be as specified In elm Material ration of this Centras.
16.9 On certain water crossings, Contractor may be required to install ditch pings of crashed done,
sandbags or dry soil after the pipe has been lowered into the ditch. These plugs are brooded to
keephaceiill from sloughing in toward the dream's center. Maga shall be Installed at both banks
and shall be instaledup towater level When crushed rode plugs are requited, Contractor shall
use a Client proved protective wrap to double -wrap pipeline to protect coating. Protective
wrap shall be held 'Apiece by non-metallic banding or reinforced tape famished by Conbnretor.
Client shall identify water crossings where these plugs shall be required.
16.10 If weights are used to provide negatve buoyancy, Contractor shall double -map the pipe with a
Client approved protective wrap prior to Inmalling concrete weights to ensure a snug fit, to
prevent slippage of weights and to pravam damage to pipe Coating. Protective wrap shall be
wrapped around the pipe 1n two (2) layers and held in place by non aetalllc banding or
reinforced tape.
ENGINEERING STANDARDS
Number. ES -4852'
Page: 294143
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
16.11 Boit-on type weights shall be fitted securely to double -wrapped pipe and bolts should be lightened
adequately. Bolton weights gall be installed on the line pipe so that bolls are located at 12:00
SW 6:00 positions along the pipe d aenve (i.e., the joint between the bolt halves is vertical
not horizontal). Steel bolls used Ex fastening weights shall be chased and a Client approved
protective coating shall be applied to the exposed portion Awaits and nuts.
16.12 Contractor shall take precautions to prevent burbling of pipe when lifting sections with weights
attached.
17. HORIZONTAL DIRECTIONAL DRILLING
17.1 General
17.1.1 Contractor shall positively lake and stake existing lines, cables or other underground
fatalities, including exposing arty facilities located within 10 feet of the designed drilled
path. Contractor shall modify drilling practices and down bole assemblies to prevent
damage to e:dsting facilities prior to commencing drilling operations. Contractor shall
be responsible for losses and repairs occasioned by damage to underground finalities
resulting from drillingoperalons.
17.1.2 At all limas, Contractor shall provide and maintain intuumentation to document and
hate accurately the pilot hole, to measure ddIFetring axial and torsional leads and to
measure drilling euld discharge rate and pressure. Client shall have access to these
doh and instruments along with their readings at all time.
17.1.3 Contractor shall submit procedure and material deseripticem to Client for approval prior
to commencing any holizamlal directional drgligg. This description shall include, but
not be limited to the following:
• Profile and plan showinglacation of emu and exit points
• Work space required to perform the wink
• Mud containment and Opus! sites
11.2 Pilot Hole
17.2.1 The pilot hole shall be drilled along the path shown in the Drawings and Right -of -Way
and Permit stipalatons sections of tbls Contract. No pllot hole will be accepted ifit win
result in any of the pipeline being Installed In violation of the Right -of -Way and Permit
Stipulations section of this Contract Conan for adjacent utilities and/or structures •
shall take precedence over the listed tolerances. Listing of tolerances does not relieve
Contractor from responsibility for safe operations or damage to adjacent utilities and
ahndares.
•
11.2.2 In absence of tolerances to the Drawings or Right -of -Way and Permit Stipulations
section of this Contract, the pilot hole shall have the following tolerances:
• Elevation of 40 feet and -15 feet
• Alignment of +/-20 feet as long as It does not core to within 3 feet of the tight -of -
way boundary
• Initial penetration of ground surface at exact location shown In the Drawings
section alibis Contract
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Rev. No.: 0 Number: BS -4852
Date: 4/17/03 Page: 30 &43
• Final penetration of the ground surface within +/-10 feet of the alignment and
witldn +30 feet and -0 fief of the length shown in the ',tunings section of this
Contract
• Awes shall be drilled ata radius equal to or greater than that specified in the
Drawings section of this Contract. The drilled tadtns will be calculated over any 3
Joints (range 2 typo drill pipe) segment using the following formula;
Rama
where:
Lelia ig
Ate
(I,/A.,B) x 180/p
Its =drilled radius over Lamed
length drilled; no leas than 75 het and no greater than 100 tact
total change in angle over Ldavor
• 17.23 At the completion of the pilot -hole drilling, Contractor shall provide a tabulation of
horizontal and vertical coordlnatea, refer to the drilled entry point, which
accurately desaib ethe location of the pilot hole.
17.3 Ream and Pull Back
17.3.1 The entire ptdl 'section shall be subjected to a •2 -hour hydmstalic pretest prior to
Installation in the hole. Thepretest pressure shall be equal to or exceed that required for
final certification. The hydrostatic pretest shalt be conducted and documentedaocording
to the Cleaning, Testing and Drying Section of this Specification.
17.3.2 Pre -reaming operations sball.be conducted at Contractor's discream Pre-maming
however, shall be sufficient to prevent damage to pipe or pipe coating that may be
caused from insofdent pre-reanting. Provisions of this spxffcallon relating to
simoltsseous reaming and pulling bade operations also shall protein to pre -reaming
operations The use Ma nose section ahead of pipe during pull batt to prevent damage
to crossing pipe is roque
173.3 The =damn allowable tensile load imposed on the pipeline poll section shall be equal.
to 90% of the product of the Specified Minimum Yield Strength (SMtS.) of the pipe
and the steel area in the pipe section. If more tbaa one value is involved for a given pull
section, the lesser shall govern. The steel area in the pipe section shall be deteonined
using API SL minluntm talcum:8.
17.3.4 A swivel shall be used to connect the pipeline pull section to the reaming assembly to
minimizeto>stosal stress imposed on the section.
17.3.5 The pull section shall be supported as it proceeds during pall back so that it stoves freely
and pipe and coating am not damaged.
17.3.6 The pull section shall be installed in the reamed hole so that .o eternal stresses are
minimized. Any damage to pipe resulting from extemai stresses dining installation
shall be Contractor's respopetbilty.
ENGINEERING STANDARDS
Number: ES -4852
Page: 31 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
17.3.7 Buoyancy modification shall be used at Contractor's discretion. Any buoyancy
modification procedure proposed for use shallbe submitted in writing 'to Client for
approval prior to any modifications being started. No procedure may be used which
Client bas not approved Contractor is responsible for any damage to the pipeline
resulting 'tom buoyancy modification
17.3.8 Tho poll suction shall be inspected with a calibrated holiday detector as it enters the
bole. Any coating damage found shall be repaired before it =bus the hole and without
imethmting installation.
17.4 Drilling Plaids
17.4.1 The composition of drilling fluid's proposed for use shall be submitted to Client kr
approval prior to start of wodc No fluid will be approved or utilized that does not
comply with the Right -of -Way and Permit Stipulations section or Ns Contract
17.4.2 Contractor is responsible for obtaining, transporting and storing any water required for
drilling fluids. At its option, Client may secure a water source for Contractor. Water
sources secured by Client are listed in the Material or Scope of Work section of this
Contract
17.4.3 Contractor shall maximize 'recirculation of drilling Ease surface returns. Contractor
shall provide solids control and fluid -cleaning equipment of a configuration and
capady to process seduce reams and produce drilling flmd suitable for rase. Client
SLY specify standards in the Scope of Work section of this Contract for solids control
and ciPaning equipment pedomrance or for tri of wwess drilling fluid and drilled
sPvli.
17.4.4 Disposal of drilling fluids and drill cuttings shall be Contractor's responsibility and
shall be conducted in compliance with federal, state and poral regulations. Drilling Raid
disposal procedures proposed kr use shall be wbmttted in writing to Client ibr approval
prior to start of work.
17.4.5 Contractor shall employ best efforts to maintain full annular dreuladon of drilling
fluids Drilling fluid relums at locations other than enhry and mit points shall be
minimized If annular circulation is lost, Contractor shall take steps to restore
circulation. If inadvertent surface returns of drilling fluids occur, they shall be
immediately contained with hand -placed banters (e.g., bey bales, sand bags, [(Ultima,
4th.) and collected asfug pumps es practical. If the amount of surface return is not great
enough to allow practical collection, the affected area will be diluted with fresh water
and the tlmdd will be allowed to dry and dissipate naturally. If the anoint of sorthce
return exceeds that which can be contained whh band -placed barriers, small collation
sumps (less than 5 cubic yank) may be used unless remits or other regulations prohibit
the use of collection tamaps. If the amount of surface rebut) exceeds that which can be
contained and collected using barriers or small sumps, or if the return of drilling fluids
occurs in the body of water proper, drilling oparatione will fie euaperd 4 until mike*
return volumies can be controlled.
ENGINEERING STANDARDS
ONSHORE CARBON STEE[. PIPELINE 'INSTALLATION
Rev. No.: 0
Date: 4/17/03
18. FABRICATING
18.1 Genera!
Number: ES -4852
Page: 32 of 43
18,1.1 Contractor shall furnish personnel, supervision, material and eNaipmeut necessary to
assemble, fabricate, test, dean, coat and install fabricated assemblies according to the
Drawings section of this Contract and Client Spedfcatlbns.
18.1.2 Contractor shall expose existing facilities prior to or during fabrication and shall field-
verify elevations and dimensions which may affect the fabricated assembly. A Client
Inspector shall have authority to make dimensional changes as necessary 10 ensure an
acceptable fit -up with existing facilities.
18.1.3 Valve hand -wheels and handles shall be instated to provide sato, unrestricted movement
of the operator.
18.1.4 Welding on fabricated assemblies shall be accomplished by applying Client approval
welding procaine. Welders asst have been tested and qualified as described in
Welding section of this Specification.
18.2 Flanges and Gaskets Including Insulating Gaskets
18.2.1 NO gaskets are to be reused when flanged assemblies are separated. Flange faces shall
be inspected, cleaned and new gaskets installed prior to reassembly,.
182.2 Flanges shall be made snug prior to tightening the bolts to their .final torque.
Tightening shall proceed in small increments, following a crisscross pattern until the
final torque value is attainedat all points.
18.2.3 Insulating flanges shall be installed as shown in the Drawings section of this Contract
insulating flanges shall not be installed below grade.
18.2.4 Client will tarnish insulating flanges either as pre$bdcated assemblies or as
components to be field -assembled Nuts shall be re -tightened 24 bons after initial
assembly to compensate for cold flow in bolts and insulating material
18,2.5 tumbling flanges shall be tested electrically to ensure effective electrical resistance of
'notatingthe
18.2.6 Once testingprocedures are complete, the fabricated assembly shall be coated
19. CONCRETE
19.1 General
19.1.1 Specifications inthis scollop shall only apply to onshore pipeline Halides, including
anchor blocks, pipe and valve supports and meter skid foundations
19.1.2 Contractor shall famish qualified personnel, supervision, marshal and apdpment to
perform concrete construction, as specified in the Drawings and Material sections of this
Contract.
ENGINEERING STANDARDS
ONSHORE CARBON SIffi. PIPELINE INSTALLATION
Rev. No.: 0
Date; 4/17/03
Number. ES -4852
Page: 33 of 43
1.9.3 Concrete footings shell be placed on nndlstnrbed soil
1.9.4 Ream material shall be disposed of according to federal, state and local Taws and
tegulatlons. Under no circanntances shall retina material be buried in the ditch or on
the right-of-way.
1.9.5 For specifications for concrete and grout construction apo Standard DZ -7110.
20. CLBANINO, TESTING, AND DRYING
20.1 General
20.1.1 Contractor shall clean, 611, test, de -water, dispose of teat water and dry pipeline and
facilities according to the Scope of Wodc, Drawings and Right -of -Way and Permit
Stipulations sections of this Contract.
20.1.2 Contractor shall provide qualified persoime! to be present at all times during cleaning,
• Wig, ping, testing, dewatering and drying. Contractor shall have sulmdem
personnel and equipment available to gniddy repair any failures oxuning during
testing Contactor is responsible fbr completion of ail required test mcords including
charts, reports, toms and calculations. Test records shall be approved by signatures of
both Contractor test supervisor and Client Inspector upon completion of the test
20.1.3 Anti -freeze, methanol, glycol, mon inhibitors or other chemicals shall not be added
. to the pipeline without written Client approval.
20.1.4 Pipeline taps to vent air are permitted, but shall be pipedto an atmosphetio tank.
20.2 Test Plan
•
20.2.1 ' Prior to any testing activities, Contractor test supervisor and Client Inspector shall mat
to thoroughly review testing motions, dotlon and appropriate drawings in
the Drawings Section of this Contract. Unless otherwise specified in the Scope of Work
section of this contact, prior to any testing activities Contractor shall submit Lor written
Client approval, aTest Plan including, but not limited to, theibilowing Information:
• me schedule and sequence of cleaning, ming, testing, de -watering and drying the
test sections, including witch sections will be filled from or de watered to adjacent
salons
• The fixation of test manifolds, fill -water solaces, do -water auras, air compressors,
pressure recorders, deadwelghts'and temperature recorders
• Fill -meter types and quantities
• F111- and pressure -pump types, quantity, size in inches, rating (g.p.m. at p.s.i.g.),
pressors limits andperfonance carves
• Fill -line size, length and type, maxinnmi fill rate for each water swmto, andllslt box
size and design, if required
• Containment structure material and design for pumps near streams and wetlands
• De -water structure material, design, discharge line size and type, maxinmm
discharge rate
ENGINEERING STANDARDS
Number:ES-4852
Page: 34 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
20.3 Safety
• Air compressor quantity and radog (elm. at p.s.i.g.)
• Quantity, model, range and acaracy for temperature recorders, pressrue recorders,
deadweight pug= and fill volumes meters
• Types and quantity for each of the following: cleaning pigs, 511 pigs, de -water pigs
and dlYinf1PiBs
• Drying equipment type, procedure and specified dew point, if required
• Spill containment material and equipment scull site
• Method to control speed of fill pig with back pressure to prevent acceleration on
downhill section.
20.3.1 Persons not directly engaged in the testing operation shall remain out of the test area
during testing. No work shall be permitted on the pipeline atter pressured.
20.3.2 If required by Client, tenmoraey welds subject to test pressure shall pass inspection and
nondestructive testing prior to filling and testing.
20.3.3 Personnel, test trailer, pressnre recorders and deadweight gauges shall be located a safe
distance from the facility being tested. If the test manifold or facility contains a
longitudinal seam, the test equipment shall be located on the side opposite that seam
when possible.
20.14 flits, lose andlittinga shall be nnm,fadmed to proper pressure rating and in good
condition. Hoses and pipes «ball be anchored to prevent whipping in the event of
failure.
20.3.5 Prior to pressurization, the pipeline Stull be completely batadilled crept test -header
locations, pipeline valves and ether areas approved by Client
20.3.6 Contractor shalt furnish and install signs to be placed over the pipeline notifying the
public when testing is in progress. Notification of individuals living in close proximity
to the pipeline shall be. done by a Client representative.
20.4 Equipment Requited
20.4.1 Unless otherwise specified in the Material section of this Centrad, Contractor shall
supply matatal and egulpmeat to den, test, deruter and dry rho pipeline and
appurtenances )naluding test manifolds, test equipment, pigs, temporary pig and
fittings, pig launchers and receivers, de -water structures and instruments.
20.4.2 The temperature recorder shall be loused is an insulated housing and the capillary lino
- shall be insulated to the sensing balb, which shall be taped to tine pipeline after removal
of dm coating. Pipeline will be backilned and tamped around the sensing bulb and the
temperature recorder shall be installed at least 200 feet from the test header.
ENGINEERING STANDARDS
Number ES -4852
Page: 35 of 43
ONSHORE CARBON STEEL, PIPELINE INSTALLATION
Rev. No.: 0 '
Date: 4/17103
20.5 Cabbcatlon of Test Equipment
Temperature recorders, pressure recorders and deadweight gauges shall bo calibrated by a Client
approved third -patty, immediately prior ID test start. Certificates of cal bxatlon: with instrument
serial numbers mast be presented to Client Inspector for approval prior to starting any testing.
20.6 Internal Cleaning
Contractor shall internally clean the pipeline prior to filling and pressure -testing as detailed in
the Scope of Work section of this Contract. Pigs shall be marked with an identifying number and
approved by Client before any testing.
20.7 Filling
20,7.1 Prior to filling each test section, Contractor shall check candidly to ensure the facility is
reedy. — including cheddng that pipe, hose, flange and fitting connections properly
installed and block valves used for filling am in open position. Other valves which are
part of the test bit not used for W1 connections should be in the half open position and
plugged or blind-fianged.
20.7.2 Filling shall be continuous from start of fulling until test section(s) is/are completely
filled Client may specify minimum fill rates. If required in Test Flan, the speed of the
fill pig shall be controlled with back ptessme to prevent acceleration on downhill
sections. Ager test section® Ware filled, connections shall be cbecked for leaks with
*vented as required.
20.8 Testing
20.8.1 Contractor shall test the pipeline for the duration and at the minim test pressure
identified in the Scope of Work and Drawings sections of this Contract.
20.8.2 Vahes most be tested inthe half -open position to prevent seal damage.
20.8.3 Below -grade valves and flanged connendens shall be left un -backfilled during the teat so
that Banged and screwed connections can be claeccedfor leaks
20.8.4 Water pressure and temperature shall be allowed adequate time to stabilize prior to
starting testing as determined by Client Inspector.
20.8.5 Prior to start of testing, new charts shall be installed on the pressure and temperature
recorders so that rho full test is on the Same chert. Contractor shall record the Nina, pipe
temperature, ambient lempmakuo, dead-weight pressure readings and the location of the
deadweights (mile posts/engu¢ering stations) on forms at testing start and as specified
in Ts Plan. Any volume of water added or drained to maintain test pressure must be
measured accurately and volumes recorded along with time, pipe and ambient
temperatures, if required by Test Plan.
20.8.6 If the test pmssurre drops below the specified minimum, the test section shall be re-
pressurized and the entire test restarted.
ENGINEERING STANDARDS
ONSRORR CA11H0N STFBI. PIPELDIS INSTALLATION
Rev. No.: 0
Date: 4/17/03
Number: ES -4852
Pelta: 36 of 43
20.8.7 Minimum acceptable test results shall be a specified in the Scope of work and Drawings
sections of this Contract
20.9 Gas Testing
20.9.1 This specification shaft apply when new steel gas pipelines of G' nominal diameter and
smaller are leak -and -strength tested using natural gas or inert gas as the test media Gas
tasting of larger diameter steel gas pipelines must be approved by an Engineering
Manager.
20.9.2 Client will provide calibrated dead-weight tester and indicating or recording gauges, as
well as communications and (if testing at night) lighting equipment.
20.9.3 Test Calculations to be Used
a) Determining the volume of pipe to be tested:
NOTE: To calculate volume, use only the diameter and length for the largest
pipe size in the section under test
VP = (0.00545) 02) (L)
Where: VP = Internal volume of pipe ft 3
d = Inside diamete<ofplpe, inches
L = Length of test section, feet
b) Determining the pressute/tempemlure corrected volume before pressure
reduction cad:
VCI = VPX(PPI +Pa) X520
(14.73 X(Tgl +460)
Where: VCI Pressurekemperature corrected volume prior to pressure
reduction, SCP.
PPI = Internal pipeline pressure prior to pressure reduction, Pa&
Pa=m atmosphericpressure, psia
TgI = Gas temperature prior to pressure reduction, °F
c) Ileterndning the pressctte/lempemture corrected volumeafter pressue
reduction has occurred:
VC2 = VP X (PP2+Pa) X 520
(14.73 X (Tg2 + 460)
Where: VC2 Pressure/cemperatate corrected volume after pressure
redaction, SCP.
P _ Internal pipeline pressure prior to pressure redaction, pstg.
TBZ = Gas tenmerainte prior to preserve reduction, °F
d) Determining gas loss:
Gas Loss = VC1— VC2 = SCF
e) Detemtining rate of gas loss:
Rate = Gas Loss / Hour X Mlle = SCF/hr/mile
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
Number: B&4852
Page: 37 of 43
20.9.4 Activity Prior to Testing
a) Contractor shall run bi-directional drank* pigs through the teat legion (using
an air compressor) to ensure construction muted foreign matter has been
removed from the pipeline. The pipeline shall be pigged a minimum of two
times or until Client Inspector determines the pipeline is free of construction
related *migu matter.
b) If test manifolds, pigs, finings, etc. are contaminated with any petroleum based
solvents or grease, they shall be cleaned thoroughly prior to use. Non -
petroleum -based solvents and greases may be used for cleaning and lubdcatton.
c) . Pipeline taps to vent Or locate lodged pigs are permitted only with written
approval of Client prior to installation Contractor has the option, at
Contractor expense, to fit pigs with pig locating devices.
d) Client Inspector shall insure that
• MI construction work has been completed in accordance with drawings
and specification
• Pigging headers are removed, unless part of permanent pipeline design,
and final tie-ins am completed
• All valves in test section are operational and setin properposition
• Public, Contactor and Client personnel and equipment not working on the
testing operation are airside the teat area
• Dead-weight tester, indicating gauges and retarding equipment ' are
ley connected
e) When natural gas will be used as the teat media, Client Operations personnel
shall be responsible for purging air from the test section (ming natural gas).
No purging shall be required when inert gas is used as the test media
20.10 Equipment Required
Unless otherwise specified in the Material section of this Contract Contractor shall supply all
material and equipment to clean and test the pipeline and appurtenances including test
manifolds, test equipment, pigs, temporary piping and fittings, temporary pig launchers and
receivers and inafnuents not otherwise specified
20.11 Test Plan
Prior to any testing activities Test Supervisor and Client Inspector shall meet to thoroughly
review testing specifications, test plan, forts and appropriate drawings in the Drawings section
of this Contract Prior to the scheduled start of any testing, a Test Plan shall bo prepared
containing information including but not limited to:
• The schedule, segoeaco and responsibility of cleaning, filling and testing the test sections
• The location of test manifolds, compressors, pressure recorders, deadweights and
temperature recorders
• . Fill -line size, length and type
• Test medium source, pressure and volume evadable in scfin
• Air compressor capacity and rating (c.tm. at p.sig.) for cleaning
ENGINEERING STANDARDS
Number ES -4852
Page: 38 of 43
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Rev. No.: 0
Date: 4/17/03
• Gas compressor capacity and rating (c.f m atpsig) for testing (if applicable)
• Types and quality of coniractoMurnished rlenning pigs
2012 • Leak and Strength Test Application
20.12.1 After verifying all pretest regulmmenls are completed, Client Ingwtnr °ball ask Client
Operations personnel to increase pressure in the test section to:
• A minimum leak -test pressure of 100 prig
• A mamdmnm leak -test pressor° of 20% of System Design Pressure
20.12.2 Contractor shall have sufficient personnel and equipment available to quickly repair any
.failures occurring during resting.
20.12.3 Client shall monitor and record the test pressure and gas temperature every 15 minutes
in the test section once the specified leak test pressure is obtained and stabilized, A gas
loos calculation shall also be perms every 15 ndmdes to obtain an indication of
stabilization and an indicated gas -loss rate within acceptable limps. These intermediate
gas -loss calculation sheets need not be included with the final test doaunrn tatlon. The
fust 15 -minute period having a calculated gas -loss rase of 800 standard cubic ret (sof)
per hour per mile or less may be considered the fust 15 -minute period of the required
one-hour leak test, if no additional loss is indiseted within the nett three 15 -minute
periods. Teat data shall bo recorded on Client Standard Fong AF1516.
20.12.4 For final acceptance of the leak test, the calculated gas -loss rate shall not emceed 200 sof'
per hour per mile. Assimilation must beCompleted mdetermine that the fndk ted loss
is below the spadfied 200 scf per mite per hour maxim for the one-hour test period.
Thal calculation shall be included with the final teat documentation.
20.12.5 If Client determines the loss rate is unacceptable, Client personnel must walk the line
and lacate the leak(s). Temporary repairs shall be made before the teak test can
NOTE: Temporary repairs (damps and sleeves) shell be made to any leaks discovered
during a test in oder to avoid an int amptlon of the test. Final leak repines whit be made
by Contractor after completion of strength test
20.12.6 If no leaks are detected and the calculated gas -loss sale is below 200 scf per hour per
miIc for the required one how period, the leak teat will be concluded and the strength
test can begin.
20.12.7 Upon completion off satisfactory leak test, Client shall request the pressure be increased
to the designated strength test pressure (according to the test plan or specification). The
test pressure and gas temperatar° stall be monitored and recorded may 15 mid by
Client doing the specified test duration. A gas loss calculation shah also b0 completed
every 15 minutes doing the strength test to obtain an indication of pressure stabilization
and to determine if the gas loss rate is within acceptable limits. These intermediate gaa-
loss calculation sheets need not be included with the final test documentation. The first
15 -minute period having a calculated gas -loss rate of 800 scf per hoar per mile or less
may be considered the first 15 -minute period of the strength test duration period, if no
additional loss is indicated within the next three 15 -minute periods.
L
ONSHORE CARBON STEL PIPELINE INSTALLATION •
ENGINEERING STANDARDS
Number: ES -4852
Page: 39 of 43
Rev. No.: 0
Date: 4/17/03
20.12.8 Strength test duration and pressure - gas testing only:
FACILITY MAOP AS TEST MJNAMUM MAXIMUM MINIMUM
TYPE A%oOF MEDIUM TEST TEST DURATION
SMYS PRESSURE PRESSURE
Gathering 30%or Natural Gas, 1.1 X 1.2 X 4 haus
lines • more inert gas desired. desired (includes
(including MAOP MAOP leanest)
well lines,
trunk lines
and laterals)
Less than Natural gas, 1.1 X 1.2 X 2 hours
30% Inert gas desired desired (tea
MAOP. MAOP leak test)
20.12.9 For final acceptance of the strength test: the gas -loss rate shall not exceed 200 sci per
hat p� mile. A calculation most be completed. to determine that the indicated loss is
below the specified 200 sof per boar per mile mardmum for the strength test period
This calculation shall be included with the final documentation.
•
20.12.10W Giem determines the Toss rate is moble, Client personnel must walls the line
and locate the leak(s). Temporary midis shall be made before the strength test can
•
20.12.11A test failure is a break or rupture that occurs during a strength test and that is of such
magnitude as to require moment repair before mon of the test
NOTE: When a strength test failure oasts, and repairs have been made, both the leak
and strength testing process nmst be repeated.
20.12.12Uptn completion of a satisfactory strength test, Client Operations personnel shall reduce
line pressure below the established MAOP for the acuity.
20.12,13 aim Inspector shall insure the disposition of all test records is in accordance with all
applicable Client policies and procedures. In addition, the Gathering Systern Gas Loss
Determination sheets for both the leak and strength tests shall be forwarded to the
Project Manager,
20.13 Testing Safety
20.13.1 Persons not direct engaged in the testing operation shall remain out of the test area
during bsdng.
20;132 Temporary welds subject to test pressure shall pass radiographic inspection per
applicable code prior to tilling and testing.
20,13.3 Personnel, test trailer, pressure recorders and deadweight gauges shall be located a safe
distance from the facility being tested. If the testmanifold or flxJlity contains a
longitudinal seam, the beat equipment shall be located on the side opposite the seam
when possible.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE INSTALLATION
Roy. No.: 0
Data: 4/17!03
Number: ES -4852
Page: 40 of43
20.13.4 Pipe, hose and fittings shall be manufactured to proper pressure rating, so labeled and in
good condition. Rose and pipe shall be anchored to prevent whipping in the event of
ihiluro.
20.13.5 Prior to pressurization, the pipeline shall be at least rough back-filled except at test -
header locations, pipeline valves and other areas approved by Client.
20.14 Testing at Crossings
Water, railroad and highway crosslgg carrier pipe shall be pretested hydrostatically before
installation as specified in the Drawings section of the Contract, except for in service pipelines in
Pte•
20.15 Records
20.15.1 Complete, signed original records of the testing program shall be maintained for each
test Handwritten records most be legibly
20.15.2 Preserve recorder and temperature recorder charts shall provide the following
information.
• Client name
• Test ,Supervisor and pipeline Contractor
• Pmjoctname
• Work-0ador manlier
• Test medium, source and quality
• Facility tested (pipeline or fabricated assembly name)
• Pipe outside diameter, oaf thio and grade
• Beginning and ending milepost and engineering stations
• Location of pipeline test section or final fabrication location (section, township,
range, aunty and state)
• Recorder location
• Recotder model and serial number
• Beginning time, date and test pregame
• Ending time,date and testpressue
• Signatures oiliest Supervisor and Client Inspector
20.15.3 Record packages for each pipeline test section shall include the following
• Test -suction profiles with winded manifold locations and test pressures
• Pipeline Facility Test Reports, signed by TDt Supervisor and Client Inspector
• Pram and tare recorder charts
• Pipeline Failure Report and charts and photos of ledks and failures
20.16 De -Watering
20.16.1 Block varves shell be in the fatly open position for de -watering. Water shall be drained
from the valve bodies after the dewatering is complete.
20.16.2 At the end of a successful test, Wander shall lower the Pressure slowly by releasing
water while maintaining a positive pressure at the highest point of the test section to
prevent air -lock Water is displaced using pigs driven either by air or nitrogen.
ENGINEERING STANDARDS
Number: ES -4852
Page: 41 of 43
ONSHORE CARBON STEL PIPELINE INSTALLATION
Rev No.: 0
Data: 4/17/03
20.16.3 No wales shall be discharged without Client's prior approval. Water shall be discharged
as outlined in the Right -of -Way and Permit Stipulations Section of this Contract.
20.16.4 De -watering of the pipeline shall be complete when no free water is received with the
running of a new pig through the pipeline.
20.17 Pre -Testing
As specified in the Scope of Work and Drawings sections of this Contract, river crossings,
horizontal .directional drills and encased crossings shall be pretested hydrostatically before
installation.
20.18 Drying
20.18.1 If required in the Scope of Work section of this Contract, Contractor shall dry pipeline
sections to a specified dewpolnt at the outlet of each pipeline drying section.
20.18.2 If required in the Scope Of Work section of this Contract Client may specify use of an
electronic gauging tool. Client shall supply both electronic ganging tool and technician
to interpret the survey malts. Contractor shall supply other labor, equipment and
matelal to load, ran and unload the survey pig.
21. CLEANUP.
21.1 General
2L1.1 Contractor shall clean up the construction right-of-way according to the Right -of --Way
and Permit Stipulations section of thin Contract and to Client and landowner or tenant
satisfaction. Contractor shall clean up pipe yards, warehouse sites, additional staging
areas and any adjoining areas used by Contrector before Client acceptance of clean up
work.
21.1.2 Clean up work shall begin immediately after the start of backfill and shall be pursued
diligently until*, entire clean up has been completed and accepted by Client
21.1.3 Rodc, which, as determined by Client cannot be backfilled according to the
Sperdfcationa, shall be disposed of at locations and in a manner satisfactory to Client
and landownor. or tenant Such disposal shall not interfere with subsequent collivalfon,
grazing or otter land uses and shall not otherwise cause damage to the property of
others. Smits rock on the right-of-way that cannot be so shad' be disposed of at Client-
appioved sites.
21.1.4 Temporary roadways shall be cleaned up and matting material shall be removed to
Client and landowner or tenant satisfaction.
21.1.5 Rough cleanup shall be completed ahead oldie testing operation.
ENGINEERING STANDARDS
ONSHORE CARBON STEEL PIPELINE h1NS'CAId.ATION
•
Rev. No.: 0
Date: 4/17/03
Number ES 4552
Page:' 42 of 43
21.1.6 Meltable disc harrow or, if necessary, a suitable subsohhur, shall be used properly on
lands subject to cultivation to break up underlying soil compacted by mon and to
enswt removal of construction debris. In addition, except for swamp erase, the entire
oonahactlon right-of-way shall be disked thoroughly to pulverize and smooth the soil in
propr manner and to depth suitable to Client and landowner or tenant.
21.1.7 Topsoil shall be 'replaced as near as possible to its original location. Client may test for
topsoil and. subsoil compaction at regular intervals across the disturbed construction
right-of-way in agdculdual and residential areas. Tests shall be done on the same soil
type under shadier moisture conditions in uadlshubed areas to identify approximate pre-
coastnudlon conditions. Devices such as Corps a Engineers style cone penetrometers
or other appropriate devices may be utilized to test for compaction.
21.1.$ After clean up and final grade of the right-of-way, Contractor shall, unless otherwise
specified in the Material or Right -of -Way and Permit Sttpolations section of this
Contract supply and apply to the right-of-way seed, fertilizer, limo, mulch and mulch
binder as described in the Right -of -Way and Permit Stipatations section of this Contract.
Contractor must keep records &type of seed used and quantities ef items listed above.'
21.1.9 Landscaped property and driveways shall be restored to original or equal condition,
which may include re -sodding Damaged yards and driveways shalt be restored to their
Conner condition or to a condition provided for in the Right -of -Way and Permit
Sttpmlaticoa section of thisContract and to Client and landowba or tenant satisfaction.
Shrubbery and/or plants will be replaced or transplanted as detailed in the Right -of -Way
and Permit Stipulations section &this Contract
21.1.10 if pipeline construction crosses streets or occupies streets longitudinally; Contractor
shall replace road surface, emits, sidewalks and driveways with the saama kind and
quality of material that was removed. Street repair is subject to the approval of Client
and the local jurisdictional sothority. •
21.1.11 Terraces, levees, water courses, drainage ditches or any other drainage system shall be
restored to former condition as detailed in the Right -of -Way and Permit Stipulations
Section of this Contract and to Client satisfaction.
21.1.12 On hillsides and sloping ground, Contractor shall providediversion terraces for
drainage across the pipeline ditch to direct water Sow into natural drainage comes and
away from the pipeline. Diversion tehraces can fait no more than 1 foot in a 50 foot
length and as shown in the Drawings or Right -of -Way and Permit Stipulations section
of this Contract. Diversion terraces shall be maintained and left unobstructed to prevent
water retention or divetaion on land adjacent to the construction right-of-way provided
by Client_
21.1.13 Fences disturbed by construction shall be restored to original condition according to the
Drawings and Right -of -Way and Permit Sttpdalons sections of this Contract and to
Client and landowner or tenant satisfaction. Upon completion of final clean up, fences
shall be replaced by Contractor using new material of like or equal quality than the
original fence to Client and landownerortenant satin action.
21.1.14 Access roads used by Cgntraotor shall bo restored to former condition to Client and
landowner or tenant satisfaction.
ONSHORE CARBON STEEL PIPELINE INSTALLATION
ENGINEERING STANDARDS
Number: ES -4852
Page: 43 of 43
Rev: No.: 0
Date: 4/17/03
21.1.15 Where clean up proceeds under adverse weather or gromul conditions, Contractor shall
assulne 5d1 risk of acceptance and maybe required by Client to repeat such clean up and
final grade, searing, fertilizing, liming and mulcldng to meet Client standard of normal
d -weather clean up. The work shall be performed in &workmanlike manner.
21.1.16 Client may require Contractor to expand the size of the clean up crew and increase the
amount of allocated equipment if clean up is not progressing in a manner satisfactory to
Client.
21.1.17 Contractor shall arrange to ream relocated ul ltty lines and retain other obstructions as
directed by Client.
21.2 Pipeline Markers
21.2.1 Pipeline markers, including markers on navigable waterways, will be installed by
Contractor directly over the pipeline according to the Drawings section of this Contract
of as directed by Client Inspector.
21.2.2 Pipeline markers shall be installed at road, railroad, fence and waterway crossings and
along line of sight where land use permits.
22. CATHODIC TEST STATIONS
22.1 Cathodic test stations shall be installed aeoording to the Drawings section of this Contract or as
designated by Client Inspector. Coating shall be repaired as described in the Coating section of
this Specification.
22.2 Areas of the pipe where teat leads are to be connected shall be cleaned of dope and primer by
using a land file. At connecting the test lead to the pipes, Contractor shall secure the test lead
to an aboveground post
22.3 Contractor shall test the cathodioprotection test stations for short circuits after installation and
prior to baddfh and shall again test them after backfilling.
22.4 Any test station found to be sborhclrcuited or otherwise defective prior to final acceptance of
work by Client shall be repaired at Contractor expense.
22.5 Client will disconnect existing cathodic -protection rectifiers in the vicinity of the project before
Contractor commences wodr as determined necessmy by Client. If Contractor cuts existing
cathodic cables or wires, the ends must be pulled bade and marked for repair.
ENGINEERING STANDARDS
PIPING MATERIAL SPECIFICATION
VALVE LIST
Rev. No.: 1
Date: 1/21/03
Number:
Page: 5 of 22
BBOA
60A
80B
ANSI Class 600, RF flanged ends, trunnion mounted
ball valve, non-lubrioated, BODY- ASTM A216 WCB
cast carbon steel; STEM AND BALL- Chrome plated
steel; SEATS- Teflon or reinforced Teflon; fire safe,
reduced port.
KF Series T-XXXX-112229X, or approved equal
•B80AF
14
60A
BOB
ANSI Class 800, RF flanged ends, trunnion mounted
ball valve, non -lubricated, BODY- ASTM A216 WCB
cast carbon steel; STEM AND BALL- Chrome plated
steel; SEATS- Teflon or reinforced Teflon; fire safe, full
Pa
KF Series T-XXXX-112229X, or approved equal.
8600
60C
ANSI Class 600, 50 °F Temp. rating, RF flanged ends,
trunnion mounted ball valve, non -lubricated, BODY -
hardness controlled carbon steel; STEM AND BALL -
316 SS; SEATS- Teflon, fire safe, reduced port.
KF Series T-XXX-8R40999X, or approved equal.
B60CF
60C
ANSI Class 600, 50 * Temp. rating, RF flanged ends,
trunnion mounted ball valve, nonlubricated, BODY -
hardness controlled carbon steel; STEM AND BALL -
316 SS; SEATS- Teflon, fire safe, full port.
KF Series T -XXX -882229X, or approved equal.
8808
60S
60.31
ANSI Class 600, RF flanged ends, trunnion mounted
ball valve, nonlubricated, BODY- 316 S8; STEM AND
BALL- 318 SS; SEATS- Teflon, fire safe, reduced port.
KF Series T-XXXX-22229X, or approved equal.
B6DSF
808
8081
ANSI Class 600, RF flanged ends, trunnion mounted
ball valve, non -lubricated, BODY- 316 SS; STEM AND
BALL- 316 SS; SEATS- Teflon, fire safe, full port
KF Series T-XXXX-22229X, or approved equal.
B6OA
15A
30A
60A
2250 PSIS at 100°F, FxF threaded ends, non -
lubricated, BODY- Carbon Steel; STEM AND BALL -
Carbon Steel; SEATS- Teflon or reinforced Teflon,
reduced port.
WKM 310, R -8138 -CS -02 -CS or approved equal.
r
ENGINEERING STANDARDS
PIPING MATERIAL SPECIFICATION
VALVE LIST
Rev. No.: 1 Number:
Date: 1/27/03 Pa e: 17 of 22
NBOA
15A
6000 PSIG at 200°F, needle valve, screwed ends,
158
15C
screwed bonnet, Inside screw and rising stem, 3/16"
orifice; BODY AND BONNET- ASTM A479-316,
7
158
STEM- ASTM A276316, SEAT- Integral; PACKING -
1581
Teflon.
1582
3DA
AGC0 H7VIS-440 or approved equal.
308
300
308
3081
60A
608
80C
60S
6081
90A
P150A
90A
ANSI Class 1500. Balanced Plug Valve, RTJ flanged
ends, bolted cover, Regular Pattem.
• Nordstrom 3045A or approved equal.
PISA
1M
ANSI Class 150, Plug Valve, RF flanged ends, bolted
150
cover, Short Pattem.
Nordstrom 1925A or approved equal.
P15AG
15AANSI
Class 150, Plug Valve, RF flanged ends, bolted
158
gland, Regular Pattern. ,
Nordstrom 1979A or approved equal.
P150
15C
ANSI Class 150, LCC materiel, Plug Valve, RF flanged
ends, bolted gland, Short Pattem.
Nordstrom 19258 or approved equal.
P15CG
150
ANSI Class 150, LCC material, Plug Valve, RF flanged
ends, bolted gland, Regular Pattem.
Nordstrom 19796 or approved equal.
P30A
30A
ANSI Class 300, Plug Valve, RF flanged ends, bolted
308
cover, Short Pattern.
Nordstrom 2025A or approved equal
P30AG
30A
ANSI Class 300, Plug Valve, RF flanged ends, bolted
30B
gland, Regular Pattem.
Nordstrom 2079A or approved equal.
..................................
ENGINEERING STANDARDS
PIPING MATERIAL SPECIFICATION
VALVE LIST
Rev. No.: 1
Date: 1/27/03
Number:
Page: 18 of 22
P30C
90C
ANSI Class 300, LCC material, Plug Valve, RF flanged
ends, bolted gland, Short Pattern.
Nordstrom 20258 or approved equal.
P3000
300
ANSI Class 300, LCC material, Plug Valve, RF flanged
ends, bolted gland, Regular Pattern.
Nordstrom 20798 or approved equal.
PGOA
60A
60B
ANSI Class 600, Balanced Plug Valve, RF flanged
ends, bolted cover, Regular Pattern.
Nordstrom 2244A or approved equal.
P6OAG
60A
6013
ANSI Class 600, Balanced Plug Valve, RF flanged
ends, bolted gland, Regular Pattern.
Nordstrom 2249A or approved equal.
P60C
60C
ANSI Class 600, LCC material, Balanced Plug Valve,
RF flanged ends, bolted gland, Regular Pattern.
Nordstrom -2244B or approved equal.
P8OCG
60C
ANSI Class 600, LCC material, Balanced Plug Valve,
RF flanged ends, bolted gland, Regular Pattem.
Nordstrom 22498 or approved equal.
P8OA
�
15A
0A
60A
ANSI Class 900, Plug Valve, NPT Ends, bolted cover,
Short Pattern.
Nordstrom 2024A or approved equal.
P90AG
90A
ANSI Class 900, Balanced Plug Valve, RTJ flanged
ends, bolted cover, Regular Pattem.
Nordstrom 2349A or approved equal.
ENGINEERING STANDARDS
PIPING MATERIAL SPECIFICATION
VALVE LIST
Rev. No.: 1
Date: 1/27/03
Number:
Page: 19 of 22
PIA
15A
15B
15C
6000 PSIG at 200°F, gauge valve, 3/4 inch MNPT x (3)
1/2 Inch FNPT connections, inside screw and rising
stem; BODY, BONNET, and SEAT- ASTM A479-316;
7
158
STEM- ASTM A276-316; PACKING- Teflon. Each
1581
valve shall be assembled with (1) 1/2 inch heavy hex
1582
plug and (1) 1/2 Inch bleeder valve.
30A
30B
AGCO M5A-VSS-46 wN6VIS-4 or approved equal.
30C
30S
3081
60A
601
60C
608
6081
90A
T150A
90A
Vogt SW 15141 or approved equal.
TIBIA
90A
Vogt 10603 or approved equal.
T15A
15A
ANSI Class 150, RF flanged ends, bolted bonnet, plug
158
disc, replaceable disc end seats; BODY AND
BONNET- ASTM A216 WCB cast carbon steel; STEM -
ASTM A182 -F6 11.5 to 13.5% chromium steel; DISC
AND SEATS- Stainless steel- Graphtted non -asbestos
packing.
Powell Figure 1531-P140 or approved equal.
T150
15C
ANSI Class 150, -59 °F Temp. rating, RF flanged ends,
bolted bonnet, plug disc, replaceable disc and seats;
,
BODY AND BONNET- LCB; STEM- ASTM A182 -F6
11.5 to 13.5% chromium steel; DISC AND SEATS -
Stainless steel- Graphlted non -asbestos packing.
Velan F-00-0074C-26TY or approved equal.
T150
15G
Class 125, FFFE, bolted bonnet rising stem, solid
wedge disc; BODY and BONNET — ASTM A126 Class
B, STEM, SEATS, and DISK — Bronze; non -asbestos
packing.
Crane 351 or approved equal.
ENQINEERING STANDARDS
EV Nil 1 NUMBERbZ-4363
1 l
•
PIPE
SIZE
CLAD'
TYPE
•
• ALL
DIMENSION'S RN INCHES - •
ANCHOR
BOLT
A
B
0
.DF�
3/B
R
3/4
T1
'1/4
T2
-
H
.1518
SIZE •
3/4
J"
A
2 1/2
7 1/2
. 3
1 1/2 ,
1 1/2"
J
2 3/4
8 1/2
3 1/8
2 1/4
1/2
1 1/8
i 4
-
15
/16
3/4
2"
A
3
9
3 3/16
2 5/8
3/4
t 5/16
1 4
-
15 6
3/4
3"
A
3 314
10 1/2
3 3;
3 3/4
1 1 4
1 7/;
-3 8 .
-
15 6
3/4
4"
,A
4 1/2
12
3 3;
4 3/4
1'338
2 3 8
3;
1 4
16 6
3/4
8"
2.3/4
B
6 1j(2
16
3 9/116
8 7/8
3 3/4
4 7 16
3 8
1 4
1 3//16
1•
1i•
8
7 1/2
18
31/2
11
4 3 4
51 2
3;
1 4
1 3/16'
1
14`
B
8 1/2
20
22
3 1/4
37
13
141 4
5 3 4
614
61 2
71/�888
3 8
38
1 4
14
1 3/16
1316
1
1
. �
8
91/2
8
4
it
8•
11 1/2
26
3 7j6 .
18 1/4
8 1 4
9 1/8
1 2
3
1 7 113
1 1/4
24`
0
12 1L2
28
3 7
20 1 4
9 1 4
10 1 8
1
3 8
1 7 16
1 1/
22`
B.
13 1/2
30
3 7 -
22 1 4
10 1 4
11 1 8
1 2
3 8
1 7 16
1 1 4
24'
B
14 1/2
3
34(
3 7
24 1 4
11.1 4
12 1;
1 2.
3
1 7 16
1 1 4
261r
8
15 1(2'
3 7 8
26 1jj/4
12 1 4
13 1
4 2
3
1 7 16
1 1014
30"
B.
17 1 2'
38
3 7 8
30 1j4
14 1 4
15 1
1/2
3 6
.1 7/16
1 1/4
€ USE,THIS PIPE CLAMP WITH PIPE SUPPORT STANDARD DZ43s ONS t .
rantX31) CLAMP TO BE MADE FROM ONE PIECE OF METAL (N0 SPLICES PERMITTED)
2.) ALL ITEMS ARE TO BE .CARBON STEEL. UNLESS NOTED,
3.) ALL BOLTS TO BE FURNISHED HATH ONE EACH HEAVY FLAT WASHER AND HEX NUT.
i 4.) THIS CLAMP DESIGN SHOULD NOT BE USED FOR PIPING DESIGNS IN EXCESS 1200 PSI.
L CONSULT ENGINEERING FOR CLAMP DESIGN ON HIGH PRESSURE SYSTEMS.
PIPE SUPPORT
W6x15
ENGINEERING STANDARDS
WELD 3" LONG STUD BOLT TO •
/ BEAM (SEE TABLE FOR 0)
BEAM •
! T : PIPE CLAMP, SEE
SID DZ -4383
PLATE 3/8",N.S do F.S.
4" STD PIPE
t
M
FOUNDATION TYPE 1:
1'-810 x 5'-6' PIER
(SEE TABLE)
FOUNDATION TWE 2:
x 6'-6' PIER
(SEE TABLE)
FOUNDATIQN TYPE 3:
3'-0'0 x 6'-6' PIER
(SEE TABLE)
NOMINAL
SIZE
2'
(4)1.0x 0'-4" 1G. PIPE
EQ. SPA. AROUND 4'0 PIPE
6) /5 BARS
/4 CLOSED 11ES
A (In.)
4'
6'
3
B (In.)
STUD•BOIT
0 (In.)
FOUNDATION
TYPE
3.3/4
• 41/2
8" •
10'
5 1/2
8 1/2
7 1/2
11
12
14
3/4
3/4
3/4
• 16
1
1
1
1
1
18
1
1
20
1
1
12'
8 1/2
22
1
1
14"
9 1/2
. 24
1
. 2
16'
10 1/2
18
11 1/2
26
28
11/4.
2
1 1/4
2
20'
12 1/2
13 1/2
14 1/2
30
32
34
11/4
1 1/4
1 1/4
2
3
3
26"
15 1/2
38
1 1/4
•28'
18 1/2
38
1 1/4
3
30'
17 1/2
1 1/4.
3
NOT*,
1. MAX. SPACING OF SUPPORTS = 15'-0"
2, SUPPORTS ARE NOT SUITABLE FOR
SOILS CONSISTING OF ORGANIC CLAYS
OR PEAT
3. ISOLATE PIPE FROM SUPPORT 111H
APPROVED FIBERGLASS SHIELD.
4, DESIGN CONDITIONS
PIPE — FULL OF WATER
WIND — 100 MPH MAX.
SEISMIC — ZONE 1'
SOIL BEARING — 1000 PSF
METHOD — UBC CHAPTER 18
5. CONCRETE: MIN. 1'c=3000PSI
REINFORCING: A-815, GRADE 60
ENGINEERING
STANDARDS
BARRED TEES - BRANCH OUTLET OF WELD
TEES TO ALLOW FOR PIGGING OF PIPELINES
REV.
N0:1 N01E13:036
DATE: 3/21/03
SHEET: 1 QF 1
8
SINGLE BAR
1/4 0.0
1/2 0.D
8
TRIPLE BAR
1/16" 0.D,
1/3 O.D.
8
DOUBLE BM
LENGTH OF
FILLET WELD
1/16" CLEARANCE THIS EDGE TO BE IN LINE
BETWEEN BAR AND YV1TH THE INSIDE WALL OF'
•
INSIDE WALL THE RUN.
SECTION A - A
NOMINAL
BRANCH
SIZE 02TLET
OUTLET
0.D.
BARS.•SET
IN
BRANCH
DIMENSIONS
B
C
D
2 375"
1
1 4"
1 1/16"
3.500"
1 4"
•
6
8"
4.501
6.62
8.625`
1
2
10"
12"
10.751"
12.75
16.000
20.000"
2 .
3
"
4
�1 4"
1
1 4"
1 4"
5 16"
17/6"
1 1116"
2 3 6"
2'9 16"
3 1 16"
13;2"-
1 2"
3 4"
/4"
1"
3 9/16"
1"
1"
3
5 16"
3 15L16"
1 1 /8"
3
24.000"
3
351: 8"
4 15/16"
5}8"
1 1/4"
1 3/10"
NOTE: BARS ARE TO BE CUT FROM
C. S. PLATE. ALL FLAME CUT EDGES
MUST BE GROUND SMOOTH AND
CORNERS ROUNDED TO A
1/8" (APPROX>) RADIUS.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
PIPELINE CASING AND INSULATOR INSTALLATION
FOR UNDERCROSSINGS
Rev. No.: 0 Number: DZ -4914
Date: Page: 1 of 2
... W5`Iat( aIK
W F1
104D OE CAsddc SERI_ A
'h ;U._n Ott
DSI, 2" [ &�_ 7 fJ° {{I Iii i4" } tr ie' J 22" 25 26" >0 T 3fri &O° 42 .;ti`
_... io o" a "ko" 1 i" , K;" t" p I
D7A. ! f { i 2U" 24" 26' NO" 30° :36" S 42" 46" 4-r ti -4" ,
.965 ,?,fifj_3t::'. .3:51,43, .500
.200 ! -r/Zi
f,6:4.25t .881.1
i 4 1
c"
WAGON WHEEL CONSULTING ENGINEERING STANDARDS
PIPELINE CASING AND INSULATOR INSTALLATION
FOR UNDERCROSSINGS
Rev. No.: 0 Number: DZ -4914
Date: Page: 2 of 2
Notes:
1. Insulators shall be installed over specified protective coating on carrier pipe.
2. Insulator rings and seals furnished by Client and installed by Contractor.
3. Follow highway and railroad specifications for specific depth and length.
4. Use 2 extra casing insulators, one on end and one 4' from end, to guide though properly. Drag
section must be placed in the casing so that casing insulators will satisfactorily center drag sections
in casing.
5. All below ground casing and vent pipe to be coated with approved external protective coating.
Above ground portion to be painted in accordance with specifications.
6. Install casing vent with 10" x 22" warning sign on each end of casing.
7. Anodes shall not be connected to the casing
8. Casing vent lines to be electrically isolated from carrier pipe and installed so they cannot contact the
carrier pipe after settling.
9. Install cathodic test load at each vent in accordance with cathodic test stations.
10. Above information must be submitted and approved by the regulating authorities prior to
installation.
11. Refer to the following standards:
Pipeline Undercrossing for Highways DZ -4911
Pipeline Undercrossing for Railways DZ -4912 and 4913
Cathodic Testing Station DZ -4939
Pipeline Marker DZ -4940
Casing Vent DZ -4915
Casing Insulator DZ -4916
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CASING VENT
Rev. No.: 0
Date:
Number:DZ-4915
Page: 1 of 1
PP
Nt&1'X'�ti 1. 14.•:fiFt11. �
SIDE
TION
I ION
"I- ' j 4 434"f
Notes:
1. Vent pipe material to be the same as the casing
2. Vent shall e l'-0" outside R/W line.
3. All materials to be furnished by contractor except pipeline marker, unless otherwise noted on
construction drawings or contract documents.
4. All material except pipeline marker to be installed by contractor.
5. When casing extends at least 12" outside R/W line, double miters in vent are not required.
6. All below ground vent pipe to be coated with approved external protective coating. Above ground
portion to be painted in accordance with specifications
7. Refer to insulator and casing standard, DZ -4914.
8. Refer to pipeline marker standard, DZ4940.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CASING INSULATOR
Rev. No.: 0
Number:DZ-4916
Date:
Page: I of 1
LI:S
•---k C NSIOi93 ti
PIPE! INE I n ..
CASING { n 1 d 10 j j iG 2€ 1
APT 8A710 WIDTH 1 3-1/2 8
•
,A3,/1. 843313! 1i-li
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CATHODIC TEST STATION
Rev. No.: 0
Number:DZ-4939
Date:
Page: 1 of 2
-J'IYit n
WS ISSIEAJ,U
SAUStal
CATHODIC TEST STATIONS
GENERAL CONSTRUCTION INFORMATION
A cathodic test station shall be installed approximately one mile apart at section roads or access trails, on either
side of the road in the fence line at the most convenient approach. If no fence is present, then test station shall
be brought up along side the pipeline marker. Location shall be at the discretion of pipeline inspector. Material
will be furnished by the company and installed by the contractor. All wires welded to pipe shall be given slack
to bottom of ditch and along the ditch bottom and wall to test post and conduit fitting. Company will install
conduit covers. Coating shall be replaced at all test lead sites with approved coating.
A double pole electrical test station, including two test leads connected to each pipeline, shall be installed at
specified pipeline crossings. The test leads will be connected to the foreign pipline only on permission or
requiest of another Pipeline Company. The test leads connected to PDI's pipline shall be black, and the test
leads connected to the foreign pipeline shall be of another color. White test leads shall be used for the second
pipeline connection in the case of a crossing of two PDI pipelines. Two adjacent double pole tst stations shall
be brought up on the same post. If this should occur in cultivated land or road, the test stations shall be set near
the cross-over and 16" below grade, and all cable and wire ends shall be taped. At cross-over 1 #8 and 1 #12,
insulated leads shall be installed on each line. No wires shall be joined as a bond at time of construction.
All cased under crossings shall have a #12 TW wire on the carrier pipe. (See Engineering Standards DZ -49I 1.
4912, 4913 and 4914.)
At each underground insulating flange, a double post test station shall be installed on each side of the insulated
joint with wire and color as indicated above.
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
CATHODIC TEST STATION
Rev. No.: 0
Date:
Number:DZ-4939
Page: 2 of 2
Y1f-� ANODE SHOWN VIVID NO
FILL IN THE PERMEABLE CLOTh
BAG FOR CLARIFY ONLY.
•s
COATED PIPELINE
BURIED AND BACKFILLED
sMAGNE S!UM ANODE'
W./PERMEABLE CLCTI{ BAG
INSTALLED IN BACKFILL MIXTURE
HORIZONTAL INSTALLATION SHOWN)
WAGON WHEEL CONSULTING
ENGINEERING STANDARDS
PIPELINE MARKER
Rev. No.: 0
Dale:
Number:DZ-4940
Page: 1 of
Note:
1. The warning sign shall be ten inches (10") wide x twenty-two inches (22") high metal plate. Each
sign shall be printed black on white and nclude the following information:
►"Warning High Pressure Gas Pipeline"
I. Company Name
► Telephone numbers of Corporate office and Division office
2. Contractor will furnish 10" long steele pipe posts of 2", 3" or 4" nominal diameter junk pipe. Some
of the posts will have warning signs bolted to them and others will be only the plain posts.
3. Posts are to be set 1'-0" to one side of the edge of the installed pipeline. Postholes are to augured
and made a size larger than line marker post. Holes are to be filled with dirt and tamped sufficiently
to provide a firm post setting.
4. Posts are to be installed a maximum of mile intervals or at fence lines, and other locations
necessary to locate pipeline. Final locations will be designated by the Client representative on the
job. At road crossings, a post is to be installed on both sides of the road with both posts having a
warning sign.
5. Posts are to be buffed clean of all rust, scale, oil, etc., then prime coated. After primer coat is dry,
the entire post is to be painted red.
ENGINEERING STANDARDS
FENCING Rev. No.: 0
Nwpber: ES -7030
Date: 9/1/00
Pia e:lof4
1. SCOPE
This Standard covers the requirements ix the design ttricatlun, material and inspection of&ndng.
2. CODES AAID STANDARDS
All work, materials and design shall be in accadance with the latest editions and sections of the
applicable codes and standards as follows:
American Society of Testing Materials (ASM).
3. DESEGNREQUII BMI3NIS
31 Fences should be installed airy to provide security, or a visible bamdarybetween the &ally and
adjaoentprope ty. The fence should be located as rurrsnry to enclose the facility, but no closer
to the edge of the property than one foot inside the property line.
3.2 In general, barbed wire fences should be used In rural locations. Chain link fillets may be used
in populated locations and for mainitnr dons and treating plants.
33 Emit fence around a compressor station must have at least two gates located so as to provide
separate escape tortes in case of an emergency. Each gate located within 200 ken of any
rompr'essa plant building mast open outward and when the plant is occupied, the gate must be
operable -without akey.
3.4 In upgraded area.% the fence shall follow the existing ground line. Mina irregularldes shall be
resioved a filled bygrading 2 {t. on eaeh side ofthe fence.
3.5 'Changes In line where the angle of defie cion Is 20 degrees or more shall be considered as
corners and comer posts and bracing shall be installed.
3.6 All end, an angle and gate posts shall be braced. Line posts shall be braced in both
direetiaus at Intervals nut to exceed 800 feet
3.7 Maximum spacing of line pada shall be 10 feet.
3.8g shall be erected so that it is plumb, taut, true to line and grade, and complete in aR
details.
3.9 Fencing &brio or barbed wire will be located on the outside of the post toward the adjacent
may
4. MATERIALS
4,1 All materials shall be new and the of defects other than those permitted by the appropriate
spedfleati n. Ifmatedals are not specified on the specification sheet, material selection Is at the
disattire of the vendor. Material selection shall be consistent aslth the codes and design
conditions specified. The vendor may quote alternate materials that meet the specified code and
the design conditions as specified.
FENCING
ENGINEERING STANDARDS
Number: ES -7030
Page: 2 of
Rev. No.: 0
Date: 9/1/00
5. BARBED WIRE FENCING
5.1 Barbed wire post shall be 4.12 Leet high with 4 strands of barbed wire spaced with the top
strand of barbed wire 48' above grade and the bottom strand shall not be more than 8" above
grade. Other strands shall be placed equally between the top and bottom strands. Caner and
%d post arrangements shall be constructed using a 6" 0.13. wood caner post with a 4" O.D.
wood post spaced 7-1/2 fret item the comer post. The corner and aDaoent poet are tied together
by a 4" O.D. wood team extending between the tops of each post with a guy wire extending from
ground level of the corner post to the top ofthe adjacent post. Wood posts sball bed minima of
7-12 &atlmg
5.2 Line pasts shall be either wood. 4" OD. by 7-1/2 fret long, or steel, heavy duty "'i" type. All
wood pasts should be mean treated to resist rotting.
53 The barbed wile shall be composed of two strands of 12-12 gauge w(re, with 2 or 4 point barba,
spaced approximately 5" apart
5.4 Gates shall be free swinging (180°) aluminum farm gates with Radlllies for securely Locking.
6. CHAINLINKP&cING
61 General
6.1.1 The fence shall be a galvanized wire &brie, 7 %A total height, including seauitytop.
6.1.2 All sted materials shall be of good cammerdal quality, hot -dipped galvanized steel
having a carbo[ content of not Less that 0.1%. Posts shall be galvanized cold rolled
tubing bmfrrmingto AS1MF-669, (ThtF-40 or equivalent
6,13 Zinc coating shall be smooth and relatively free of humps, globs, or points. Hxccsstye
roughness, blisters, sal -ammoniac spots, bruises or 9eckfsg will be a basis kr rejection.
6.1.4 Miscellaneous material shall be galvanized as specified in ASTM Designation A-123
and A- 153.
6.1.5 Weight of coating sball be tested as specified inASTM Designation A-90 and A-239.
6.2 Fabric
62,1 Fabric shall be made frau No. 9 Gauge galvanized wire Steel whit shall have a
minimum silicon content of 0.10%.
6.2.2 Fabric shall be woven in a 2" chain link diamond mesh. Top and bottom selvage shall
be twisted and barbed. Galvanizing shall be done atter mesh is assembled as specified
ASTM Designation A-392, Class L
6.3 Posts
6.3.1 Line posts shall be 2-318" O.D. galvanized pipe.
6.3.2 Caner pasts and intermediate braced posts shall be 2-7/8" O.D. galvanized pipe.
ENGINEERING STANDARDS
Number: ES -7030
Page: 3 of4
FENDING
Rev. No.: 0
Date: 9/1/00
63.3 Gateposts for man gates shall be 2-7/8" O.D. galvanized pipe.
6.3.4 Gate posts kr double swing and eliding vehicle gates shall be 4" O.D. galvanized pipe.
6.4 Oates
6.4,1 1-5/8" O.D. galvanized pipe shall be used for gate flames and traces.
6.4.2 Gates shall be hung by at least two steel or malleable iron hinges, 3 inches or more in
width, designed to allow the gateto swing 180 degrees.
6.43 Suitable malleable Iran ar pressed steel latches, stops, cents rests and locking device
shall be provided.
6.4.4 The tame fr sliding vehicle gates shall be daixicated Dam 1-5/8" 0». galvanized pipe
and adequately traced with 3/8" diameter truss rods with tightener and 1-58" O.D.
center vertical brace. The gates shall be manually operated.
6.5 Braces
6.5.1 1.58" O.D. galvanized pipe shall be used for horizontal braces at posts requiring
tradng. Braces shall be located midway between the top and bottom of the fabric, and
secured to posts with suitable steel or malleable iron fittings.
6.5.2 Races shall be extended them the terminal lost to the that aryacemt line post, and
nursed back to the base of the terminal post with 3)8" diameter rod, cc*n tete with
turnbuckle or truss tightener.
• 6.6 Tetsuo Wire
6.6.1 Seven (7) gauge galvanized spring cell steel wire of good commerdai quality shall be
used between pasts at the top and bottom of all ibnce fabric
6.7 bfscellaneausMatedais
6.7.1 &tenetea arm shall be mounted as all posts at a 45 degree angle toward outside of'
fenced area. Arms shall be 12" long with 3 slots far wire.
6.7.2 Three strands 9f barbed wire shall nm the entire length of fence above fabric and gates,
composed crf two strands of 12 - 1/2 gauge wire, with 2 or 4 point barbs, spaced
fib' 5" apart. The barbed wire shall be tied off at terminal pests whidt shall
Extend one >bot highs than tae line posts.
6.7.3 Galvanized malleable wrought hen or pressed steel shall be used fbr fittings and
mLccellaneeav me talc.
6.7,4 To Thsten iklxIe, heavy galvanised steel metal bands or wire of not less than No. 9 gauge
shall be used For line posts, Ranish one de to every that of Rule height For tension
wires and traces, finish approximately 24" apart.
6.7.5 Molature proof caps are to be trashed fa all posts.
ENGINEERING STANDARDS
FENCING
Rev. NA: 0
Date: 911/00
Number: ES -7030
;4of4
6.8 Construction
6.8,1 The bottom ofthe fence Ethic will extend to within two Innes of firm ground and shall
be searely anchored to prevent intruders a animals Brom lifting the fabric to orate an
6,82 All pasts shall be set in concrete of not less than 2,500 psi compressive teat. Concrete
shall extend 4"below the post. Concrete shall be poured lash with the gtound, crowned
and left smooth. Cmaete ibmdadeos shall be of such she end shapeas required to
withstand anystraln a shadm ordinarily brought to bear on the knee, but not less than
Indicated in the Rnllowingtable:
The of Post
Dlameta of
Concrete
Depth of
Concrete
Fad post
10"
40"
Pall, corner & angle costs
10"
40"
Gateposts (man gates)
10"
40"
Gate posts (doable swing gates)
10"
48"
Line posts
9"
34"
If forms are used, badcflll shall be acted to density of surrounding soil.
6.$.3 Where solid rock. Is encountered, a hole 2" larger than post OD. shall be drilled and.
grout a sand shall be placed around post.
7. INSPECTIONS
7.1 The materials and &brlcadon shall be subject to hupedion and approval by the Client in addition
to those required by code. The valve: cr approval of inspection shall not relieve the vendor of'
respmslbilityto meet the requirements of the applicable codes and this standard.
8. GUARANTEES
8.1 The vender shall guarantee against defects of material apt wuricmanship and warrant that the
materials used In the mamutheio re meets thou respective standards, for a period of 12 months
tan the date ofinstalladon.
BiII Barrett Corporation
STORM WATER MANAGEMENT PLAN
BILL BARRETT CORPORATION
MAMM CREEK FIELD
GARFIELD COUNTY, CO
0.0 INTRODUCTION
This Storm Water Management Plan (SWMP) has been prepared for the BILL BARRETT CORPORATION (the
Company) MAMM CREEK FIELD in order to identify Best Management Practices (BMPs) which will be implemented
to meet the terms and conditions of the Colorado General Permit for Storm Water Discharges Associated with
Construction Activity. The SWMP has been prepared in accordance with good engineering, hydrologic, and pollution
control practices, and is designed to constitute compliance with rules and regulations promulgated by the Colorado
Department of Public Health and Environment (CDPHE).
This SWMP is divided into two sections: the Reference Section and the Site Specific Section. The Reference Section,
also referred to as the Master SWMP, contains information that is applicable to all Sites. The Site Specific Section
includes Site maps and discussion regarding each Site; this information will be updated over time as the activities at each
site progress and change. Both Sections together are referred to as a "Field SWMP."
The SWMP Administrator is Scot Donato.
The following Sections 1.0, 2.0, and 3.0 comprise the Reference Section of the SWMP.
I.0 FIELD PROJECT DESCRIPTION
The below sections (a) through (h) follow the General Permit C.1.(a) through (h).
(a) THE COMPANY is constructing the oil & gas production facilities Iocated in Garfield County, Colorado, which
involves oil & natural gas well drilling, completion and production facilities, and associated roads and pipelines. The
facilities meet the CPDHE term of a "common plan of development," which is defined as a site where multiple separate
and distinct construction activities may be taking place at different times on different schedules, but still under a single
plan.
(b) This section discusses the major steps for completion of the different types of construction activities. Construction of
each type of facility follows a typical, consistent procedure.
The construction sequence for major activities for construction at oil & natural gas well pads consists of:
• Clearing vegetation and establishing perimeter stormwater control as shown on the Site diagrams;
• Removing and stockpiling topsoil, grading and compacting the project areas level;
• Excavating the reserve pit;
• Moving in drilling equipment and drilling oil & gas well;
• Removing all drilling equipment and moving in completion equipment to complete well;
• Removing all completion equipment and installing semi-permanent production equipment; and
• Re-seeding/reclaiming the remaining disturbed area with uniform vegetative cover to at least 70% of pre -
disturbance levels, referred to as Final Stabilization. Note that stabilized unpaved surfaces can meet the
definition of Final Stabilization for those areas that must remain unvegetated for production operations at a
well pad.
• Portions of a site returned to cropland use and the control of the farmer to not require establishment of
vegetative cover. Once returned, these areas are no longer regulated as construction activity.
The sequence of major activities for construction of the access roads consists of:
• Clearing and grading the road right-of-way;
• Cutting the roadside drainage ditches;
• Contouring and compaction of existing or imported materials;
• Emplacing and compacting roadbase as appropriate;
• Re-seeding/reclaiming the remaining disturbed area with uniform vegetative cover to at least 70% of pre -
disturbance levels.
• Following construction of the well for which the access road was built, dirt road surfaces will remain for
access to the well and are considered `stabilized unpaved surfaces.'
The sequence of major activities for construction of the pipeline route consists of:
• Clearing and grading the road right-of-way;
• Trenching for the pipeline install;
• Welding pipe together and placing in the trench;
• Backfilling and compacting the trench;
• Re-seeding/reclaiming the remaining disturbed area with uniform vegetative cover to at least 70% of pre -
disturbance levels.
The sequence of major activities for construction of the completion and production facilities consists of:
• Installing production facilities including tanks, separators, and piping.
• Regrading the surrounding area for reclaimation as appropriate.
• Re-seeding/reclaiming the remaining disturbed area with uniform vegetative cover to at least 70% of pre -
disturbance levels.
Where the above procedures differ during actual construction activities and the change results in a change to a BMP at a
site, this will be described in the corresponding Site -Specific Section.
(c) The approximate total area of the Mamm Creek Field is 20,306 acres. The approximate areas to be disturbed at each
individual Site are as described in the Site -Specific Section.
(d) USGS topographic maps were used to evaluate the topography of the Sites. The topography and natural site drainage
are discussed in the Site Specific Sections. If wetlands are present at any individual facility and the potential impact to the
wetlands is determined to fall under the jurisdiction of the U.S. Army Corp. of Engineers (Army Corps), the Army Corps
will be consulted for the proper permit(s) as appropriate, and the construction methodology outlined in the permit will be
followed.
(e) The majority of the project area is located in short grass prairie or range land, and existing vegetation may include
range -type grasses, sage brush, forbs, pinyon, juniper trees, willows and cottonwoods. Vegetative ground cover ranges
from approximately 10% to 70%. A description of the existing vegetation at each of the Sites is included in the Site
Specific Sections.
(0 The most common substances that have the potential to be spilled within the project area are: I) fuel and lubricants for
construction equipment and vehicles; 2) water or gel based frac fluids (surfactant, friction reducer, acid, potassium
chloride) using during completion, sand; 3) produced water; and 4) produced crude oil/condensate. The locations for
storage and handling of these substances will be chosen based on protection from moving vehicles, distance from surface
water bodies, distance from sloped ground, and other practical factors. The locations are shown on the Site maps in the
Site -Specific Section.
(g) No non -storm water components of storm water discharge such as irrigation return flows or spring discharge are
anticipated. If non -storm water discharges are found to be required at a Site, a discussion will be included in the Site -
Specific Section.
(h) The potential receiving water bodies for surface water drainage from the Sites will be Divide Creek, Dry Hollow
Creek and Mamm Creek. The receiving water body for each Site is noted in the Site -Specific Section.
2.0 STORMWATER POLLUTION PREVENTION
This section covers the specifications of the Best Management Practices (BMPs) that will be applied during construction
activities covered in this SWMP. The implementation of BMPs in the field will be shown on the Site maps, and
deviations from the specifications below will be discussed in the Site -Specific Section.
2.1 Erosion and Sediment Controls (BMPs)
Erosion control will be accomplished through a combination of construction techniques, use of structural
features, and non-structural practices. Erosion controls, as appropriate, will be implemented prior to
successive phases of each project including; site clearing, road grading, and final pad grading. The controls
will remain in place and active until the project site is appropriately stabilized.
2.1.1 Construction Techniques
Excavation
a. Excavated materials will be stored next to the excavation to protect the material from vehicular and
equipment traffic. As required by the Reclamation Regulations all excavation operations on cropland shall
separate and store the various A, B, and C soil horizons.
b. Excavation in especially sensitive areas may be conducted according to special techniques as specified by
the landowner/agency representative
c. Materials excavated will be utilized as backfill when practicable. An exception may be some rock excavated
by blasting. In these areas, some select backfill may be required to protect the project area. Excess rock
may be pushed into rock filter dikes, used in energy dissipation zones below culverts, constructed into rock
check dams within grassed swales, distributed over a portion of the project area or disposed of' off-site.
d. All cuts made in steep rolling terrain during construction will be regraded and contoured to blend into the
adjoining landscape and to reestablish the natural drainage patterns.
e. Materials that are unsuitable for use as backfill or excess backfill material will be disposed at approved
locations.
f. Temporary workspace areas will be restored to approximate pre -construction conditions.
Streams and Wetlands
a. During construction near perennial streams, lakes or wetlands, sedimentation (detention) basins, straw bales,
or fabric filters may be constructed to prevent suspended sediments from reaching downgradient
watercourses, streams, lakes or wetlands.
b. Disturbance of riparian and wetland areas will be kept to the minimum needed for construction and
installation. Approaches to streams will involve selective clearing of vegetation. Willows and cottonwoods
cleared during construction will be reestablished as part of reclamation.
c. If work occurs in willow/shrub type areas, the small trees and shrubs may be trimmed to ground level in
areas where equipment will be working.
d. The first 1.0 feet of topsoil from wet areas will be salvaged and redistributed over the excavation as quickly
as reasonably possible following installation of the pipeline. The seeds, roots, rhizomes, tubers, and bulbs
present in the topsoil will enhance and help speed up reclamation of wet areas disturbed by construction.
e. Where appropriate, water bars or sediment filters, such as staked straw bales or silt fences, will be
constructed adjacent to the crossings to reduce potential sedimentation in streams or wetlands. Trenching
will cross dry streams. Small flowing streams will be crossed by fluming or trenching with a downstream
silt barrier to reduce downstream sedimentation.
2.1.2 Structural Features
Structural site management practices refer to physical structures such as vegetative filters, soil roughening,
crimped straw, brush dams, rock filter dikes, silt fences, straw bale dikes, water bars, or equivalent sediment
controls installed so as to protect down slope surface waters, wetlands and roads from sediment flow due to
runoff from a storm event. Specifically, during construction, soil roughening, crimped straw, silt fences, straw
bale dikes, water bars, terracing, or equivalent sediment controls are recommended for all side slope and down
slope boundaries for the construction area. Alternatively, a detention basin providing storage for runoff from a
l0 -year, 24-hour storm event could be implemented. Below are listed several considerations for structural
practices:
a. To minimize disturbance associated with installation of the Facility, level and gently sloping terrain outside
the project area will not be graded, except where reasonable for construction equipment stability and fire
safety.
b. Silt barriers and deterrents (eg. crimped straw, brush dams, rock filter dikes, silt fences, hay bales, or water
bars) will be installed as needed on down -gradient portions of the project area. Typical silt barrier
construction are shown on BMP figures
c. Side hill cuts will be kept to a minimum to protect local resources while providing a safe and stable plane for
the efficient and safe use of equipment.
d. Where conditions warrant, erosion control structures such as berms, water bars, diversion or collection
channels, terraces, or culverts will be constructed to divert water away from the project area and to reduce
soil erosion along and adjoining areas disturbed during construction.
e. In areas of' steep slopes that are not annually cultivated, water bars or runoff diversions, will be installed as
indicated in Table 1. The water bars will begin and end in undisturbed ground at a 2% slope.
f. Culverts may be installed at a grade ranging from 2-5 %. Inlet protection may include inlet aprons and rock
armoring around the culvert perimeter while below grade inlet sumps may be installed to enhance
deposition. Outfall protection may include the use of a rock armored splash pad to slow water.
Table 1 - Spacing for Erosion Control Structures
Slope Diversion Spacing (Feet)
5-15% 300
16-30% 200
30+ % 100
Table 2 - (BLM Cold book)
Slope Diversion Spacing (feet)
2 % 300
2-4% 200
4-5% 75
5+ %
50
Post -Construction Structural Measures will include:
a. Permanent water bars will be installed on steep slopes according to Table 1 and at wetland and stream
crossings.
b. Trench plugs will be installed on steep slopes according to Table I and at wetland and stream crossings.
After restoration work is complete, required repairs to vegetation and erosion and sediment control structures will
be completed along with routine scheduled pipeline inspections and/or in response to other notification.
2.1.3 Non -Structural Practices
Non-structural practices such as leaving existing vegetation, shrubs, and trees in place where possible, and
interim reclamation such as interim seeding of select areas, mulching, geotextile fabrics, and vegetative
buffers, will be employed wherever practicable to assist in preventing erosion from project sites. The
following describes some general practices, and implementation at each site will be discussed in the Site-
specific information.
a. Existing cover will be removed only where necessary for the operation of equipment. In general, vegetation
will be cut off near ground level leaving the root system intact. Cuttings may be stacked into a brush dam,
distributed along the contour across reclaimed areas during reclamation or disposed of as directed by the
landowner/agency representative.
b. Trees and large shrubs that are not cleared from the site will be protected from damage during construction
by avoiding them with equipment. For example, bulldozers will maintain their blades in a raised position
except for areas designated for clearing or to smooth out sharp breaks in relief.
c. Grading outside the project area will be done only when necessary for the safe operation of equipment and
for fire protection.
d. Trees will be cut or trimmed only to facilitate clearing, grading, and safe installation. Trees which must be
removed will be cut. Trees outside the area of disturbance will not be cut, but will only have overhanging
limbs removed by cutting, with the tree to remain. The bulldozers will maintain their blade in a raised
position in sensitive visual resource areas, where practicable.
e. Interim reclamation of soil stockpiles and other appropriate areas may be implemented to prevent erosion
from these areas. Interim seeding, mulching, or geotextile fabrics may be used to stabilize slopes. Cut or
existing live vegetation may be used as a vegetative buffer to slow runoff water flow and prevent sediment
from reaching live water.
Following construction, the following non-structural practices will be employed:
f. Unless otherwise directed by the landowner or the jurisdictional authority, rocks, cut vegetation, and other
surface material temporarily stockpiled for construction will be redistributed back across non -fenced portions
of the project area.
g•
Disturbed areas will be seeded using seed mixes appropriate to the location. Local soil conservation
authorities with the U.S. Natural Resources Conservation Service, surface owners and/or reclamation
contractors familiar with the area may be consulted regarding the correct seed mix to be utilized.
h. On terrain where drill seeding is appropriate, seed may be planted using a drill equipped with a depth
regulator to ensure proper depth of planting. The seed mix will be evenly and uniformly planted over the
disturbed area. Drilling may be used where topography and soil conditions allow operation of equipment to
meet the seeding requirements of the species being planted.
i. Broadcast seeding will occur on steep terrain and on areas such as where the cut vegetation and rocks were
redistributed over the right-of-way.
j. Seeding will be done when seasonal or weather conditions are most favorable according to schedules
identified by the jurisdictional authority, reclamation contractor, or landowner. Whenever possible, seeding
will be timed to take advantage of moisture, such as early spring or late fall to benefit from precipitation.
k. Seed mixes will be planted in the amount specified in pounds of pure live seed/acre, where necessary. There
will be no primary or secondary noxious weeds in the seed mix.
I. As far as possible, the reestablishment of vegetative cover as well as watershed stabilization measures will
be scheduled during the working season and before the succeeding winter. In any case, revegetation
treatments will be accomplished as soon as practical following completion of facility construction.
m. In general, the applicable portions of the project area will not be mulched during reclamation and
revegetation. Mulch will only be applied at the request of the jurisdictional authority in areas where the cut
vegetation and rocks are not redistributed over the disturbed area. (The cut vegetation and rocks will act like
mulch in the areas where they are applied.) Where straw or hay mulch is requested, the mulch will be
applied and crimped into the soil.
n. The need for fertilizers will be determined in conjunction with the jurisdictional authority, surface owners
and/or reclamation contractors. If fertilization is necessary, the rates of application will be based on site-
specific requirements of the soil.
2.2 Phased BMP Implementation
There are many possible options for application of BMPs during the phases of construction outlined in Section 1 (b)
above. The actual implementation will depend on the conditions at the individual Sites.
As such, site-specific BMP changes from phase to phase will be noted on the Site maps and, if needed, described in
writing in the Site -Specific Sections. Each time that a BMP is changed, the Site map will be updated. The Site maps and
written sections are intended to be dynamic - changing frequently to reflect the actual conditions in the field. The
exception to this will be at the very beginning of the activities, when the Site -Specific Sections will show the anticipated
activities.
2.3 Materials Handling and Spill Prevention
Hazardous materials and petroleum products to be used in construction of the facilities are limited to diesel fuel and
lubricants for construction equipment and vehicles; small quantities of paints and solvents; water or gel based frac fluids
(surfactant, friction reducer, acid, potassium chloride) using during completion; produced water; and, crude
oillcondensate. Material Safety Data Sheets (MSDSs) for materials to be used on sites will be available either at the Site
or the closest regional office.
Practices for the prevention of pollution due to materials handlin are specifically outlined in the Spill Prevention, Control
and Countermeasures (SPCC) Plan. available at the Silt field office.
The general BMPs that will be employed at all sites include:
• Refueling and lubrication of vehicles will be conducted a minimum of 100 feet back from flowing streams and
wetlands.
• Spills will be promptly cleaned up and contaminated materials hauled off-site and disposed of/recycled properly.
• Quantities of materials on site will be limited to "as -needed" for the immediate operations underway.
• All waste from materials imported to the construction site are to be removed for disposal/recycling to an
appropriate licensed disposal/recycling facility, including sanitary sewage facilities (typically portable).
2,4 VEHICLE TRACKING CONTROL
To prevent tracking of sediment onto public roads, the facilities shall have, at a minimum, compacted ingress and egress
areas adjacent to public roads. Other means such as gravel/scoria placement, or cattle -guards may be utilized if
appropriate.
2.5 WASTE MANAGEMENT AND DISPOSAL
No wastes of imported materials shall be buried, dumped, or discharged to waters of the State, and there are no anticipated
pollutant sources from areas other than construction areas.
2.6 GROUNDWATER AND STORMWATER DEWATERING
roundwater from the wells is `produced water' and will be managed by storing in the reserve pit during drilling activities
nd in a tank during production activitie4 tipAhekdomring activities are anticipated, as precipitation would bq
pected to infiltrate and evaporate;
3.0 MAINTENANCE and INSPECTION
Maintenance will be the responsibility of the Company. Maintenance will be performed on an as -needed basis based upon
the results of inspections conducted at the site or general observations during any reason for being present on the site.
The baseline schedule for inspection of the construction sites is outlined below. If deviations from the baseline schedule
are found to be required, approval of alternative schedules will be pursued from the CDPHE. Information regarding an
alternative schedule will be included on the respective Site-specific section.
1. An inspection of the Site to document pre-existing conditions will be conducted prior to construction
activities.
2. During construction activities, inspections will be conducted at least every 14 calendar days and within 24 -
hours of any precipitation event exceeding 1.0 inch during construction and prior to initiating reclamation.
i. An exception to the 24-hour post -storm inspection requirement is if a site is "temporarily
idle," meaning that no construction activities will occur following a storm event. In this
case, an inspection is required prior to re -commencing construction activities, but no later
than 72 hours following the storm event. If this exception occurs, it will be documented in
the Site-specific section.
3. In the case where the following three conditions are met, the permittee is allowed to reduce the inspection
frequency to once a month, and post -storm inspections are not required. The conditions are:
i. All construction activities that will result in surface ground disturbance are completed (this
may include some well completion activities);
ii. All activities required for final stabilization, in accordance with the SWMP, have been
completed, with the possible exception of the application of seed that has not occurred due
to seasonal conditions or the necessity for additional seed application to augment previous
efforts (this allows for seeding to occur in more favorable growing conditions); and
iii. The SWMP has been amended to indicate those areas that will be inspected in accordance
with this reduced schedule. This will be noted in the Site-specific section of this SWMP.
The monthly schedule described above is allowed for sites within a field permit that meet the final
stabilization preparation criteria and are waiting for the 70% vegetative cover to be achieved.
4. Inspections are not required at sites where construction activities are temporarily halted, snow cover exists of
the entire site for an extended period of time, and melting does not pose a risk of surface erosion. If this
situation occurs, it will be documented in the Site-specific section of this SWMP.
5. Inspections will be documented and these records kept on file for three years following reclamation.
6. Negative inspection results will be corrected as soon as practicable. Reporting requirements for
noncompliance are outlined in Part II A. 3 of the General Permit. The 24-hour spill reporting hotline is
1-877-518-5608.
SEDIMENT AND EROSION CONTROL
MEASURES
(BEST MANAGEMENT PRACTICES — BMPs)
SITE SPECIFIC SECTIONS
PARACHUTE OFFICE
120 North Railroad
MOBILE
HOME
Chris Hansen -Team Leader
Suite C
303-513-9963
Production
Duane Zavadil-VP Regulatory
PO Box 661
303-638-1265
Superintendent
Jesse Merry
Parachute, CO 81635
303-549-7739
303-733-0130
Jim Felton — Public Relations
Phone #
303-881-0840
970-285-9061
Troy Schindler -Drilling Mgr
Fax #
303-249-8511
970-285-0244
Dave Ault -Drilling Coord.
BBC CONTACT LIST
OFFICE
MOBILE
HOME
Chris Hansen -Team Leader
303-312-8545
303-513-9963
Duane Zavadil-VP Regulatory
303-312-8128
303-638-1265
303-660-1145 -Glenda
Scot Donato -Mgr EH&S
303-312-8191
303-549-7739
303-733-0130
Jim Felton — Public Relations
303-312-8103
303-881-0840
970-668-1624 - Janet
Troy Schindler -Drilling Mgr
303-312-8156
303-249-8511
303-740-8507 - Kathryn
Dave Ault -Drilling Coord.
303-312-8143
303-842-6464
Francis Barron -Atty
303-312-8515
303-520-7411
303-756-6335 -
Jay Bauer -Facilities
303-312-8101
303-638-9558
George Hartman -Construction
307-258-7901
Chris Bairrington
303-312-8511
303-877-5239
Taryn Frenzel
303-312-8559
Monty Shed -Regional Supervisor
307-265-0256
307-262-1511
307-856-6196
Jesse Merry -Area Superintendent
970-285-9061
970-230-0436
970-285-0103
Shane Collette -Compressors
970-230-0464
Jim Bailey —Construction Supervisor
970-319-9944
James DeShields
970-230-0927
Aaron Axelson
970-230-0926
Jeff Fandrich-Land
970-230-0924
970-945-8147
Bill Kelly
307-360-6266
Brady Construction
970-285-9508
970-216-0642
Mark McNamee -Windmill Energy
303-573-4449
303-898-0989
Site -Specific Section
Mamm Creek Field Stormwater Management Plan
Site Name/Identification: Bailey Compressor Station
Approximate area (acres or sq. ft) disturbed: 6.0
Description of pre-existing vegetation and % vegetative cover:
Existing terrain includes range and grasslands. Approx 60-70% ground coverage.
Potential receiving water body for stormwater runoff:
Dry Hollow Creek
Information to be shown on Site Map:
When BMPs change, show the
change and date on Site map. Once
BMPs are implemented and
construction activities begin, the map
should reflect actual site conditions.
Print new copies of the map as
needed. Discard old versions.
Site-specific drainage and topography,
including streams, ditches, surface
water bodies
Location of potential pollutants such as
vehicle fueling, chemical storage areas,
produced water storage, etc.
BMP types (color coded) and locations
Areas of cut and fill
Are there any exceptions to the BMPs from the specifications shown in the
Master SWMP? If so, describe below and note the date of the change.
na
Are there any exceptions to the permit inspection and maintenance
procedures or frequency as described in the Master SWMP? If so, describe
below and note the date of the change.
na
Use more than one form as needed.
1
1.111
5
•
2
II