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HomeMy WebLinkAbout1.03 Application-Part4Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition On Scene Coordinator (OSC) The federal official pre -designated by EPA or the USCG to coordinate and direct federal responses under subpart D, or the official designated by the lead agency to coordinate and direct removal actions under subpart E of the National Contingency Plan. OPA 90 Federal Oil Pollution Act of 1990 Operational Period The period of time scheduled for execution of a given set of operational actions specified in the Incident Action Plan. Operational Periods can be various lengths, usually not over 24 hours. Operations Section Responsible for all operations directly applicable to the primary mission. Directs unit operational plans preparation, requests or releases resources, makes expedient changes to the Incident Action Plan (as necessary) and reports such to the Incident Commander. Includes the Recovery and Protection Branch, Emergency Response Branch, Air Operations Branch, and Wildlife Branch. OSHA Occupational Safety and Health Administration (USDL) OSLTF Oil Spill Liability Trust Fund OSRO Oil Spill Removal Organization OSRP Oil Spill Response Plan Out of Service Resources Resources assigned to an incident but unable to respond for mechanical, rest, or personnel reasons. Owner or Operator Any person, individual, partnership, corporation, association, governmental unit, or public or private organization of any character. P Pancakes Isolated, roughly circular patches of oil ranging in size from a few feet across to hundreds of yards (or meters) in diameter. Sheen may or may not be present. PEL Permissible Exposure Limit Perennial Flows constantly; intermittent -flows part of the year but groundwater table falls below the stream bottom during dry times. Persistent Oil Under OPA 90, persistent oils are petroleum-based oils that do not meet the distillation criteria for a non-persistent oil. Persistent oils are classified based on a specific gravities as follows: • Group II — specific gravity less than .85; • Group III — specific gravity between .85 and less than .95; • Group IV — specific gravity .95 to and including 1.0.; and • Group V — specific gravity greater than 1.0. March 2013 © The Response Group Page 16 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition Planning Section Responsible for collecting, evaluating and disseminating tactical information related to the incident, and for preparing and documenting Incident Action Plans. The section also maintains information on the current and forecast situation, and on the status of resources assigned to the incident. Includes the Situation, Resource, Environmental, Documentation, and Demobilization Units, and Technical Specialists. Post Incident Analysis Detailed review of an incident to establish a clear picture of events that took place during an incident. Post -Emergency Response The portion of a response performed after the immediate threat of a release has been stabilized or eliminated and cleanup of the sites has begun. PPE Personal Protection Equipment PPM Parts Per Million PREP (National) Preparedness for Response Exercise Program Primary Response Contractor(s) An individual, company, or cooperative that has contracted directly with the plan holder to provide equipment and/or personnel for the containment or cleanup of spilled oil. Private Sector Organizations and entities that are not part of any governmental structure. It includes for-profit and not-for-profit organizations, formal and informal structures, commerce and industry, and private voluntary organizations (PVO). Procurement Unit Functional unit within the Finance/Administration Section responsible for financial matters involving vendor contracts. PSI Pounds Per Square Inch Public Information Officer (P10) A member of the Command Staff responsible for interfacing with the public and media or with other agencies with incident - related information requirements. Q Qualification and Certification This subsystem provides recommended qualification and certification standards for emergency responder and incident management personnel. It also allows the development of minimum standards for resources expected to have an interstate application. Standards typically include training, currency, experience, and physical and medical fitness. March 2013 © The Response Group Page 17 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition Qualified Qualidual(QI) Indivi• An English-speaking representative(s) of the facility identified in the plan, located in the United States, available on a 24-hour basis, able to arrive at the facility in a reasonable time, familiar with implementation of the facility response plan, and trained in the responsibilities of the Qualified Individual under the response plan. This person must have a document from the owner or operator designating them as a Qualified Individual and specifying their full authority to: Activate and engage in contracting with oil spill removal organization(s); • Act as a liaison with the pre -designated Federal On -Scene coordinator (OSC); and • Obligate funds required to carry out all necessary or directed response activities. R RCP Regional Contingency Plan RCRA Resource Conservation and Recovery Act of 1976 Recoverable Oil Oil in a thick enough layer on the water to be recovered by conventional techniques and equipment. Only black or dark brown oil, mousse and heavy sheens (which are dull brown in color) are generally considered to be thick enough to be effectively recovered by skimmers. Recovery The development, coordination, and execution of service -and site -restoration plans; the reconstitution of government operations and services; individual, private -sector, nongovernmental, and public -assistance programs to provide housing and to promote restoration; long-term care and treatment of affected persons; additional measures for social, political, environmental, and economic restoration; evaluation of the incident to identify lessons learned; post -incident reporting; and development of initiatives to mitigate the effects of future incidents. Resource Unit Functional unit within the Planning Section responsible for recording the status of resources committed to the incident. The Unit also evaluates resources currently committed to the incident, the impact that additional responding resources will have on the incident, and anticipated resources needs. Resources All personnel and major items of equipment available, or potentially available, for assignment to incident tasks on which status is maintained. Response Guidelines Guidelines for initial response that are based on the type of product involved in the spill. These guidelines are utilized to determine clean-up methods and equipment. March 2013 © The Response Group Page 18 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition Response Plan A practical plan used by industry for responding to a spill. Its features include (1) identifying the notification sequence, responsibilities, response techniques, etc. in an easy to use format; (2) using decision trees, flowcharts, and checklists to insure the proper response for spills with varying characteristics; and (3) segregating information needed during the response from that required by regulatory agencies to prevent confusion during a spill incident. Responsible Party (RP) Any person, owner/operator, or facility that has control over an oil or hazardous substance immediately before entry of the oil or hazardous substance into the atmosphere or in or upon the water, surface, or subsurface land of the state. Restoration The actions involved in returning a site to its former condition. Rivers and Canals A body of water confined within the inland area that has a projected depth of 12 feet or less, including the Intracoastal Waterway and other waterways artificially created for navigation. ROW Right of Way RQ Reportable Quantity RRT Regional Response Team S Safety Officer (SO) A member of the Command Staff responsible for monitoring and assessing safety hazards or unsafe situations, and for developing measures for ensuring personnel safety. The Safety Officer may have assistants. SAR Search and Rescue SARA Superfund Amendments and Reauthorization Act SCAT Shoreline Cleanup Assessment Team SCBA Self -Contained Breathing Apparatus SDWA Safe Drinking Water Act of 1986 Section The organization level having functional responsibility for primary segments of incident operation such as: Operations, Planning, Logistics, Finance/Administration. The Section level is organizationally between Branch and Incident Commander. Service Branch A Branch within the Logistics Section responsible for service activities at the incident. Includes the Communications, Medical and Food Units. Sheen A very thin layer of oil (less than 0.0001 inches or 0.003 millimeters in thickness) floating on the water surface. Sheen is the most commonly observed form of oil during the later stages of a spill. Depending on thickness, sheens range in color from dull brown for the thickest sheens to rainbows, grays, silvers, and near -transparency in the case of the thinnest sheens. SOP Standard Operating Procedure I March 2013 © The Response Group Page 19 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition S (Cont'd) Site Conditions Details of the area surrounding the facility, including shoreline descriptions, typical weather conditions, socioeconomic breakdowns, etc. Site Safety and Health Plan (SSHP) Site-specific document required be state and Federal OSHA regulations and specified in the Area Contingency Plan. The SSHP, at minimum, addresses, includes, or contains the following elements: health and safety hazard analysis for each site task or operation, comprehensive operations work plan, personnel training requirements, PPE selection criteria, site - specific occupational medical monitoring requirements, air monitoring plan, site control measures, confined space entry procedures (if needed), pre -entry briefing (tailgate meetings, initial and as needed), pre -operations commencement health and safety briefing for all incident participants, and quality assurance of SSHP effectiveness. Site Security and Control Steps that must be taken to provide safeguards needed to protect personnel and property, as well as the general public, to ensure an efficient clean-up operation. SITREP Situation Report Message Situation Unit Functional unit within the Planning Section responsible for collecting, organizing and analyzing incident status information, and for analyzing the situation as it progresses. Reports to the Planning Section Chief. Skimmers Mechanical devices used to skim the surface of water and recover floating oil. There are four basic categories of skimmers; suction heads, floating weirs, oleophilic surface units, and hydrodynamic devices. These vary in efficiency depending on the type of oil and size of spill. Slick Oil spilled on the water, which absorbs energy and dampens out surface waves, making the oil appear smoother or slicker than the surrounding water. Sorbents Materials ranging from natural products to synthetic polymeric foams placed in confined areas to soak up small quantities of oil. Sorbents are very effective in protecting walkways, boat decks, working areas, and previously uncontaminated or cleaned areas. Source Control Actions necessary to control the spill source and prevent the continued release of oil or hazardous substance(s) into the environment. Span of Control On how many organizational elements may be directly managed by one person. Span of Control may vary from three to seven, and a ratio of one to five reporting elements is recommended. SPCC Spill Prevention, Control and Countermeasures Plan March 2013 q011.1111 0 The Response Group-FAMPOPPINI Page 20 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym erm Definition Spill Management Team (SMT) The personnel required to staff the organization structure identified in a response plan to manage response plan implementation. SSC NOAA Scientific Support Coordinator SSHP Site Safety and Health Plan Staging Area The location where incident personnel and equipment are staged awaiting tactical assignment. Stakeholders Any person, group, or organization affected by, and having a vested interest in, the incident and/or the response operation. State Emergency Response Commission (SERC) A group of officials appointed by the Governor to implement the provisions of Title III of the Federal Superfund Amendments and Reauthorization Act of 1986 (SARA). The SERC approves the State Oil and Hazardous Substance Discharge Prevention and Contingency Plan and Local Emergency Response Plans. State On -Scene Coordinator (SOSC) The pre -designated State On -Scene Coordinator. STEL Short-term Exposure Level Streamers A narrow line of oil, mousse or sheen on the water surface, surrounded on both sides by clean water. Streamers result from the combined effects of wind, currents and/or natural convergence zones. Often, heavier concentrations of Mousse or Sheen will be present in the center of a streamer, with progressively lighter sheen along the edges. Streamers are also called "fingers" or "ribbons." Supervisor The ICS title for individuals responsible for directing the activities of a Division or Group. Supply Unit Functional unit within the Support Branch of the Logistics Section responsible for ordering equipment and supplies required for incident operations. Support Branch A Branch within the Logistics Section responsible for providing personnel, equipment and supplies to support incident operations. Includes the Supply, Facilities, Ground Support and Vessel Support Units. Surface Collecting Agents Those chemical agents that form a surface film to control the layer thickness of oil. Surface Washing Agent Any product that removes oil from solid surfaces, such as beaches and rocks, through a detergency mechanism and does not involve dispersing or solubilizing the oil into the water column. March 2013 © The Response Group Page 21 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym March 2013 © The Response Group Page 22 Definition T Tabletop Exercise (TTX) A tabletop exercise is an activity in which key members of the plan holder's staff with emergency management responsibilities are gathered together informally, usually in conference room, to discuss actions to be taken during an oil or hazardous substance spill, based upon the response plan and their standard operating procedures. The primary characteristic is a verbal "walk through" of a response. The tabletop exercise is designed to elicit constructive discussion by the participants, usually without time constraints, as they examine and resolve problems based on the response plan. A tabletop exercise has participants practice problem solving and resolve questions of coordination and assignment of responsibilities in a non -threatening format, under minimum stress. Tarballs Weathered oil that has formed pliable balls or patches that float on the water. Tarballs can range in diameter from a few millimeters (much less than an inch) to a foot (0.3 meters). Depending on how weathered or hardened the outer layer of the tarball is, sheen may or may not be present. Technical Assistance Support provided to State, local, and tribal jurisdictions when they have the resources but lack the complete knowledge and skills needed to perform a required activity (such as mobile - home park design and hazardous material assessments). Technical Specialist Personnel with special skills who can be used anywhere within the ICS organization. Threat An indication of possible violence, harm, or danger. Time Unit Functional unit within the Finance/Administration Section responsible for recording time for incident personnel and hired equipment. Toxic Substances Any substances that have the capacity to produce personal injury or illness to man through ingestion, inhalation or absorption through any body surface. Trajectory Analysis Estimates made concerning spill size, location, and movement through aerial surveillance or computer models. Transfer Any movement of oil to, from, or within a vessel by means of pumping, gravitation, or displacement. U UCS Unified Command System UEL Upper Explosive Limit Unit The organizational element having functional responsibility for a specific incident planning, logistics, or finance/administration activity. March 2013 © The Response Group Page 22 Marathon Oil` Piceance Operations Emergency Response Plan Appendix B: Glossary / Acronym Term Definition U (Cont'd) UST Underground Storage Tank V Volunteer For purpose of the NIMS, a volunteer is any individual accepted to perform services by the lead agency, which has authority to accept volunteer services, when the individual performs services without promise, expectation, or receipt of compensation for services performed. See, e.g., 16 U.S.C. 742f© and 29 CFR 553.101. W Waste Oil or contaminated soil, debris, and other substances removed from coastal waters, adjacent water, shorelines, estuaries, tidal flats, beaches, or marshes in response to an unauthorized spill. Waste is any solid, liquid, or other material intended to be discarded or disposed of and generated as a result of an unauthorized spill of oil. Waste does not include substances intended to be recycled if they are in fact recycled within 90 days of generation or are brought to a recycling facility within that time. Waters of the State Groundwater and surface water including all perennial, intermittent, and ephemeral defined drainages with flowing water present, NPDES discharge water after the Point of Compliance, lakes, reservoirs and wetlands which are not manmade retention ponds used for the treatment of municipal, agricultural or industrial wasters; and all other bodies of surface water, either public or private which are wholly or partially within the boundaries of the state. Weathering A combination of physical and environmental processes, such as evaporation, dissolution, dispersion, and emulsification, that act on spilled oil to change its physical properties and composition. Wetlands Those areas that are inundated or saturated by surface or groundwater at a frequency or duration sufficient to support, and that under normal circumstances do support, a prevalence of vegetation typically adapted for life in saturated soil conditions. Wetlands generally include playa lakes, swamps, marshes, bogs, and similar areas such as sloughs, prairie potholes, wet meadows, prairie river overflows, mudflats, and natural ponds (40 CFR 112.2(y)). Windrows Streaks of oil that line up in the direction of the wind. Windrows typically form early during a spill when the wind speed is at least ten knots (5.1 meters per second). Sheen is the form of spilled oil that most frequently windrows. March 2013 © The Response Group Page 23 ll°' N Marathon ©ll` Piceance Operations Emergency Response Plan Appendix C: Forms Appendix C: Forms TRG Trajectory Request Form 1 ICS Forms 3 Air Monitoring Plan 66 March 2013 0 The Response Group (i W Marathon ©W Piceance Operations Emergency Response Plan Appendix C: Forms TRG Trajectory Request Form Upon notification of a spill, Marathon personnel can initiate the trajectory mapping process by submitting a trajectory request form. The following information will need to be gathered to complete the trajectory request: Informtion for Trajectory Request ✓ Wind Speed and Direction V Current Speed and Direction ✓ Wave Heights (if applicable) ✓ Spill Volume ✓ If the release is continuous or instantaneous (status of release — ongoing or secured) V Type of Oil (API Gravity) ✓ Lat / Long (Spill Site) ✓ Duration of the Spill V Date and Time of Incident V Air and Water Temperature V Source of the Spill V High and Low tide (if applicable) V Email and Best Contact Number (for Person making the Request) Trajectory model results may be updated periodically, depending upon revised surveillance information and the latest weather updates. Upon completion of the form, the Spill Trajectory Request Form can be faxed to (281) 880-5000. This fax number is located in the left hand corner of the form. If a fax machine is not available, call the TRG 24 hour number at (800) 651-3942. Once the above information is submitted to The Response Group, the trajectory will be completed within one hour or less." March 2013 © The Response Group Page 1 The Response Group jIPP SPILL TRAJECTORY REQUEST FORM THE RESPONSE GROUP OFFICE: (281) 880-5000 EMERGENCY/24-HOUR: (800) 651-3942 CELL: (713) 906-9866 FAX: (281) 880-5005 EMAIL: trajectorygesponsegroupinc.com EFAX: (281) 596-6976 Company Name: 0 Company Contact Name: 7 7 O O Phone #: Alternate # (ie: Mobile, Pager): Fax #: Email Address: 7... -.- Source Type (Circle): Platform/Well Pipeline Vessel Facility Source Name & Location (Name/Area/Block): Latitude: Longitude: " I CO Q J Z Date 0, O - & Time of Incident (mm/dd/yy): / / (Military) Type of Product (ie: Medium Crude): API Gravity Estimated Volume of Release: Barrels or Gallons Continues Release Rate: bbls/hr How Long: hrs. I Wind Direction (From the): Wind Speed: MPH or Knots Cr = W O h. j W Z Ov Current Direction (Toward): Current Speed: MPH or Knots Air Temperature: ° C or F Water Temperature: ° C or F High Tide: Low Tide: Weather Forecast: I Date & Time of Overflight (mm/dd/yy): / / (Military) O 1:::. Leading Edge Location: 11 Longitude: ' O k Trailing Edge Location: Latitude: Longitude: 11Z Width: Feet / Yards / Length: Feet / Yards / Miles Miles O 11111 cc Slick Appearance (Percent & Estimated Length & Width) Barely Visible: % L x W: Silvery: % L x W: O Bright Color: % L x W: Slight Color: % L x W: Dull: % L x W: Dark: % L x W: THE RESPONSE GROUP 13939 Telge Rd. Cypress, TX 77429 In.!J Marathon OW Piceance Operations Emergency Response Plan Appendix Forms ICS Forms All forms have been added into the PDF. Instructions on how to use each form are included. March 2013 0 The Response Group Page The Response Group - ICS Forms IAP Cover Sheet Purpose: The Incident Action Plan (IAP) Cover Sheet documents the signature approval by Unified Command to implement the Incident Action Plan and may serve as a table of contents for the Incident Action Plan. Preparation: The Planning Section Chief and/or the Situation Unit Leader, while assembling the Incident Action Plan, complete The Incident Action Plan Cover Sheet. Distribution: Sufficient copies of the Incident Action Plan will be reproduced and to all supervisory personnel at the Section, Branch, Division/Group, and Unit leader levels. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. Incident Location Enter the location of the incident 3. Date/Time Prepared Enter the date and time prepared. (Military time) 4. Operational Period Enter the date and time interval for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 5. Approved By Signature line for Unified Command (Federal, State, Local, and Responsible Party). 6. Incident Notes Enter a brief summary of the incident. 7. Operational Period Notes Enter a brief summary of activities for the operational period The IAP should include the following forms: Incident Action Plan Cover Sheet Weather Report ICS -201 Incident Briefing (Optional) ICS -202 Response Objectives ICS -203 Organization Assignment List ICS -204 Division Assignment List ICS -205 Communications Plan ICS -206 Medical Plan Incident Map(s) (present situation, future trajectories, and plans) ICS -208 Site Safety Plan (As required) ICS -209 Incident Status Summary ICS -220 Air Operations Plan ICS -230 Meeting Schedule ICS -232 Resources at Risk Summary Other forms/sheets as needed for tactical operations Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software IAP Cover Sheet Incident Name: Prepared By: at: Period: / / : to / / : Version Name: Approved by: FOSC SOSC RPIC Incident Action Plan IAP Cover Sheet © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms GENERAL INCIDENT INFORMATION REPORT (ANNEX 1 TAB A) Purpose: The General Incident Information report provides the Incident Commander (and the Command and General Staff assuming command of the incident) with basic information regarding the incident situation and conditions. Preparation: The responder receiving the first call reporting the incident prepares the General Incident Information Report. The Situation Unit makes subsequent updates to the form. Distribution: The initial form will be given to the Incident Commander. When updated, the Planning Section Chief will duplicate the General Incident Information Report and post a copy at the Situation Display in the Command Post. Single copies may then be distributed to the Command Staff, Section Chiefs, and Joint Information Center. Incident Action Plan Software The Response Group - ICS Forms General Incident Report Incident: Incident Date/Time: Person Reporting Incident: Prepared: at: .• Person Contact Number(s): Version: Facility Information and Points of Contact Facility Name: Type of Facility: Number of People at Facility: Contact: Phone: Owner: Phone: Operator: Phone: Facility Specific Information Type(s) of Product: Equipment Involved: Incident Information Incident Location: Latitude: Longitude: Type of Casualty: Total Capacity of Common Container: Potential for Additional Spillage: Material(s) Spilled: API Gravity: Estimated Quantity Spilled: Classification: Source Secured?: Yes No If not, Estimated Spill Rate: Notes: Incident Status Injuries/Casualties: Fire: Yes No Fire Status: Fire Assistance: Notes: General Incident Report (Facility) © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms NOTIFICATION REPORT Purpose: The Notification Report is used to document each Government and Non -Government Organizations (NGO) notified and briefed on the incident. Preparation: The company representative or the Liaison Officer in the Command Staff prepares the Notification Report. Distribution: The Notification Report is a critical part of the incident briefing and the Incident Action Plan. When updated, the Situation Unit Leader will post/update the Situation Display in the Command Post. ITEM ITEM TITLE INSTRUCTIONS 1. Incident Enter the name assigned to the incident. 2. Version Name 3. Period Enter the Operational Period date and time. 4. Prepared By Enter name and title of the person preparing the form and date/time (Military Time). 5. Organization Notified Enter the name of the Organization notified. 6. Phone Number Enter the phone number of the Organization notified. 7. Date/Time Enter the date and time the notification is made. 8. Person Contacted Enter the name of the person notified. 9. Person Contacted Email Enter the email address of the person notified. 10. Case Number Enter the Case Number where applicable (e.g. NRC Case Number). 11. Follow Up Circle Yes or No if follow up is required. 12. ETA On Site Enter the estimated time of arrival of the organization if applicable. 13. Notified By Enter the name of the person making the notification. Incident Action Plan Software The Response Group - ICS Forms Notification Status Report Incident: Prepared By: at: Period: / / : to / / :• Version Name: Organization Notified Phone Date /Time Notified Person Contacted Person Contacted Email Case No. Follow Up ETA On Site Notified By Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notification Status Report © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms WEATHER REPORT Purpose: The Weather Report form provides the Incident Commander (the Command and General Staffs assuming command of the incident) with basic information regarding current incident specific weather conditions, forecast for the next twenty-four (24) and forty-eight (48) hour period. Personnel or responders at the incident location should provide real time current weather data. It also serves as a permanent record of the initial response to the incident. Preparation: The Planning Section prepares the briefing from data gathered from NOAA's National Weather Service and other sources. The information will be provided to the Situation Unit Leader so he may maintain the information on his static display. Distribution: After the initial briefing of the Incident Commander and General Staff members, the Incident Briefing is duplicated and distributed to the Command Staff, Section Chiefs, Branch Directors, Division/Group Supervisors, and appropriate Planning and Logistics Section Unit Leaders. ITEM ITEM TITLE INSTRUCTIONS 1. Incident Name Enter the name assigned to the incident. 2. Date/Time Prepared Enter date & time prepared (e.g. 09/17/1996 1500hrs.). 3. Operational Period Enter the date and time interval for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Prepared By Enter the name of the person completing the form. 5. Wind Speed Enter wind speed. (Indicate either knots or mph) 6. Wind Direction Enter the direction from which the wind is blowing. 7. Air Temperature Enter on the air temperature in °F. 8. Barometric Pressure Enter current barometric pressure in inches. 9. Humidity Enter current humidity in percent. 10. Visibility Enter visibility in miles. (Use data from surveillance aircraft) 11. Ceiling Enter ceiling in feet. (Use data from surveillance aircraft) 12. High Tide (time) Enter time for next high tide for current operational period (24 hr). 13. High Tide (height) Enter height of next high tide for current operational period (feet). 14. Sunrise Enter time of sunrise for current operational period. 15, Wave Height (feet) Enter the wave height in feet (e.g., 1-3 feet). 16. Wave Direction Enter the direction, which the waves are moving. 17. Swell Height Enter the swell height. (feet) 18. Swell Interval Enter the swell interval (seconds) 19. Current Speed Enter the speed of water current (Indicate either kts or mph). 20. Current Direction Enter the direction which the water current is moving, 21. Water Temperature Enter the water temperature in °F. 22. Low Tide (time) Enter time for next low tide for current operational period (24 hr). 23. Low Tide (height) Enter height of next low tide for current operational period (feet). 24. Sunset Enter time of sunset for current operational period. 25. Notes Enter notes (e.g. thunderstorm activity, wind shift, front movement) about weather data current operational period. 24 Hour Forecast 26. Forecast Enter forecast (e.g. thunderstorm activity, expected temperature, wind shift, front movement) for forecast period. 48 Hour Forecast 27. Forecast Enter forecast (e.g. thunderstorm activity, expected temperature, wind shift, front movement) for forecast period. Incident Action Plan Software The Response Group - ICS Forms Weather Report Incident: Prepared: at: Period: / / to / /Version Name: Present Conditions Wind Speed: Wave Height: Wind Direction From The: Wave Direction: Air Temperature: Swell Height: Barometric Pressure: Swell Interval: Humidity: Current Speed: Visibility: Current Direction Toward: Ceiling: Water Temperature: Next High Tide (Time): Next Low Tide (Time): Next High Tide (Height): Next Low Tide (Height): Sunrise: Sunset: Notes: 24 Hour Forecast Sunrise: Sunset: High Tide (Time): High Tide (Time): High Tide (Height): High Tide (Height): Low Tide (Time): Low Tide (Time): Low Tide (Height): Low Tide (Height): Notes: 48 Hour Forecast Sunrise: Sunset: High Tide (Time): High Tide (Time): High Tide (Height): High Tide (Height): Low Tide (Time): Low Tide (Time): Low Tide (Height): Low Tide (Height): Notes: Weather Report © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms INCIDENT BRIEFING (ICS FORM 201) Purpose: The Incident Briefing form provides the Incident Commander, the Command Staff and General Staff assuming command of the incident with basic information regarding the incident situation and the resources allocated to the incident. It also serves as a permanent record of the initial response to the incident. Preparation: The Initial Incident Commander prepares the briefing form for presentation to the relieving Incident Commander along with a more detailed oral briefing. Distribution: After the initial briefing of the Incident Commander and General Staff members, the Incident Briefing is duplicated and distributed to the Command Staff, Section Chiefs, Branch Directors, Division/Group Supervisors, and appropriate Planning and Logistics Section Unit Leaders. The sketch map and summary of current action portions of the briefing form are given to the Situation Unit while the Current Organization and Resources Summary portion are given to the Resources Unit. ITEM ITEM TITLE INSTRUCTIONS 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter name of person completing form and the date & time prepared (e.g. 09/17/1996 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. ICS 201-1 Map Sketch Show the Areas of Operations, the incident site, overflight results, trajectories, impacted shorelines, or other graphics depicting situation and response status on a sketch or attached map. 6. ICS 201-2 Summary of Current Actions Brief paragraph on: 1. What, when, and how the incident occurred 2. Surveillance & weather information 3. Overall initial response objectives 4. Timeline of major events or actions that have taken place. 7. ICS 201-3 Current Organization Enter on the organization chart the names of the individuals assigned to each position. Modify the chart as necessary. 8. ICS 201-4 Resources Summary Track the following information about the resources allocated to the incident. Name of supplier providing the resource 2. Resource Type (e.g. fire truck, boom, skimmer) 3. Description (e.g. size, name, capacity) 4. Quantity or amount of resource(s) 5. Area of Operation — destination of the resource (e.g. staging area, division, group, task force) 6. Status of each resource (e.g. Standby, En -route with Estimated time of arrival, At Staging, Assigned, & Out of Service). Incident Action Plan Software The Response Group - ICS Forms ICS 201-1 - Incident Briefing Map/Sketch Incident: Prepared By: at Period: / / to / /• Version Name: Current Situation: ICS 201-1 Incident Briefing Map/Sketch © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 201-2 - Summary of Current Actions Incident: Prepared By: at: Period: / / : to / / : Version Name: Incident Information Initial Incident Objectives Summary of Current Actions Date/Time Action/Note ICS 201-2 Summary of Current Actions © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 201-3 - Current Organization Incident: Prepared By: at: Period: / / : to / / :• Version Name: Federal State Incident Commander Unified Command Safety Officer Liaison Officer Information Officer 1 1 1 I OPS Section Chief Planning Section Chief Logistics Section Chief Finance Section Chief Branch/Div./Grp./TF Situation Unit Leader V i Resource Unit Leader / Branch/Div./Grp./TF Documentation Unit / Branch/Div./Grp./TF Environmental Unit / Branch/Div./Grp./TF / Branch/Div./Grp./TF / Branch/Div./Grp./TF ICS 201-3 — Current Organization © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 201-4 - Resource Summary Incident: Period: / / : to / / . ID Supplier Resource Type Description Quantity Size Area of Operation Status Status Date/Time ICS 201-4 Resource Summary © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 201-5 Site Safety and Control Analysis Incident: Prepared By: at: Period: Version Name: Site Control 1. Is Site Control set up? ■ Yes ■ No 2. Is there an on -scene command post? If so, where? • Yes • No 3. Have all • Yes personnel • No been accounted • Don't Know for? Injuries: Unaccounted: Fatalities: Trapped: 4. Are observers planned? Observers: involved, • Yes or rescue ■ No Rescuers: attempts • Yes • No 5. Are decon areas setup? If so, where? • Yes • No Hazard identification, immediate signs of: (if yes, explain in Remarks) 1. Electrical line(s) down or overhead? • Yes 1 No 2. Unidentified liquid or solid products visible? • Yes ■ No 3. Wind direction across Wind Speed: incident: • Towards position • Away position from your your 4. Is a safe approach possible? ■ Yes • No 5. Odors or smells? • Yes • No 6. Vapors visible? • Yes ■ No 7. Holes, ditches, fast water, cliffs, • Yes • etc. No nearby? 8. Fire, sparks, sources of ignition nearby? • Yes ■ No 9. Is local traffic a potential problem? ■ Yes ■ No 10. Product placards, color codes visible? • Yes ■ No 11. Other Hazards? ■Yes • No 12. As you approach the scene from the upwind change in the status of any of the above? side, IN Yes IN do you note a No Hazard Mitigation: have you determined the necessity for any of the following? 1. Entry Objectives: 2. Warning sign(s), barriers, color codes in place? • Yes • No 3. Hazardous material being monitored? 3a. Sampling Equipment: 3b. Sampling location(s): 3c. Sampling frequency: 3d. Personal exposure monitoring: • Yes • No 4. Protective gear / level: 4a. Gloves: 4b. Respirators: 4c. Clothing: 4d. Boots: 4e. Chemical cartridge change frequency: 5. Decon 5a. Instructions: 5b. Decon equipment and materials: 6. Emergency escape route established? Route? ■ Yes • No 7. Field responders briefed on hazards? • Yes ■ No 8. Remarks: ICS 201-5 Site Safety and Control Analysis © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms RESPONSE OBJECTIVES FORM (ICS FORM 202) Purpose: The Response Objectives Form describes the basic incident strategy, control objectives, and safety considerations for use during the next operational period. Preparation: The Response Objectives Form is completed by the Planning Section Chief following each formal Planning Meeting conducted in preparation for the Incident Action Plan. Distribution: The Response Objectives Form will be reproduced with the IAP and given to all supervisory personnel at the Section, Branch, Division/Group and Unit leader levels. NOTE: ICS 202, Response Objectives, serves as part of the IAP, which is not considered complete until attachments are included. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Version Name 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Prepared By Enter the name of the Planning Section Chief or person completing the form and the date & time prepared (e.g. 09/17/1996 1500hrs). 5. Overall Incident Objective(s) What you plan to do in priority order. Enter short, clear and concise statements of the objectives for managing the response. The overall incident objectives usually apply for the duration of the incident. (e.g. Contain and Recover Spilled Material) 6. Tactical Objectives for specific Operational Period How you plan to accomplish objectives. Enter short, clear and concise statements of the objectives for the incident response for this operational period. Include alternatives. (e.g. Deploy containment boom at appropriate collection areas) 7 Safety Messages for the specified Operational Period Enter information such as known safety hazards and specific precautions to be observed during this operational period. If available, a safety message should be referenced and attached. Incident Action Plan Software The Response Group - ICS Forms ICS 202 - General Response Objectives Incident: Prepared By: at: Period: / /to — / / Version Name: Overall and Strategic Objectives Assigned to: Status 1. Ensure the Safety of Citizens and Response Personnel la. Identify hazard(s) of spilled material 1 b. Establish site control (hot zone, warm zone, cold zone, & security) 1 c. Consider evacuations if needed ld. Establish vessel and/or aircraft restrictions 1 e. Monitor air in impacted areas if. Develop site safety plan for personnel & ensure safety briefings are conducted 2. Control the Source of the Spill 2a. Complete emergency shutdown 2b. Conduct firefighting 2c. Initiate temporary repairs 2d. Transfer and/or lighter product 2e. Conduct salvage operations, as necessary 3. Manage a Coordinated Response Effort 3a. Complete or confirm notifications 3b. Establish a unified command organization and facilities (command post, etc.) 3c. Ensure local and tribal officials are included in response organizations 3d. Initiate spill response Incident Action Plans (IAP) 3e. Ensure mobilization & tracking of resources & account for personnel & equip 3f. Complete documentation 4. Maximize Protection of Environmentally -Sensitive Areas 4a. Implement pre -designated response strategies 4b. Identify resources at risk in spill vicinity 4c. Track oil movement and develop spill trajectories 4d. Conduct visual assessments (e.g., overflights) 4e. Development/implement appropriate protection tactics ICS 202 General Response Objectives © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 202 - General Response Objectives Incident: Prepared By: at: Period: / / : to / / : Version Name: Overall and Strategic Objectives Assigned to: Status 5. Contain and Recover Spilled Material 5a. Deploy containment boom at the spill site & conduct open -water skimming 5b. Deploy containment boom at appropriate collection areas 5c. Evaluate time -sensitive response technologi (e.g., dispersants, in-situ burning) 5d. Develop disposal plan 6. Recover and Rehabilitate Injured Wildlife 16a. Establish oiled wildlife reporting hotline 6b. Conduct injured wildlife search and rescue operations 6c. Setup primary care unit for injured wildlife 6d. Operate wildlife rehabilitation center 6e. Initiate citizen volunteer effort for oiled bird rehabilitation 7. Remove Oil from Impacted Areas 17a. Conduct appropriate shoreline cleanup efforts 7b. Clean oiled structures (piers, docks, etc.) 7c. Clean oiled vessels 8. Minimize Economic Impacts 8a. Consider tourism, vessel movements, & local economic impacts I 1813. Protect public and private assets, as resources permit I 18c. Establish damage claims process 9. Keep Stakeholders and Public Informed of Response Activities 9a. Provide forum to obtain stakeholder input and concerns 9b. Provide stakeholders with details of response actions 9c. Identify stakeholder concerns and issues, and address as practical 9d. Provide timely safety announcements I 19e. Establish a Joint Information Center (JIC) 9f. Conduct regular news briefings 9g. Manage news media access to spill response activities 9h. Conduct public meetings, as appropriate ICS 202 General Response Objectives © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ORGANIZATION ASSIGNMENT LIST (ICS FORM 203) Purpose: The Organization Assignment List provides ICS personnel with information on the units that are currently activated and the names of personnel staffing each position/unit. It is used to complete the Incident Organization Chart (ICS Form 207), which is posted on the Incident Command Post display. Preparation: The list is prepared and maintained by the Resources Unit under the direction of the Planning Section chief. Distribution: The Organization Assignment List is duplicated and included in the Incident Action Plan. NOTE: An Organization Assignment List may be completed any time the number of personnel assigned to the incident increase or decrease or a change in assignments occurs. IItem Item Title Instructions l 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Resources Unit member or person preparing the form and the date & time prepared (e.g. 09/17/1996 1500hrs). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 6. Title 7. Name Name of person staffing the position Phone, Fax, Radio, Other List the numbers where the person staffing can be reached at or information can be sent to. Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software ICS 203 - Organization Assignment Incident: Prepared By: at: Period: / / : to / / : Version Name: Incident Commander and Command Staff Operations Section Incident Commander Operations Section Chief Operations Section Deputy Dep. Incident Commander Staging Area Manager Safety Officer Public Information Officer Liaison Officer Agency/Organization Representatives Planning Section Planning Section Chief Planning Section Deputy Resource Unit Leader Situation Unit Leader Documentation Unit Leader Environmental Unit Leader Documentation Unit Leader Logistics Section Logistics Section Chief Logistics Section Deputy Support Branch Director Support Unit Leader Finance Section Facilities Unit Leader Finance Section Chief Ground Support Unit Finance Section Deputy Communications Unit Time Unit Leader Medical Unit Leader Procurement Unit Leader Food Support Unit Leader Comp./Claims Unit Leader Cost Unit Leader ICS 203 Organization Assignment © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ASSIGNMENT LIST (ICS FORM 204) Purpose: The Assignment List(s) is used to inform Operations Section personnel of Incident assignments. Once the Incident Command and General Staff agree to the assignments, the assignment information is given to the appropriate Units/Divisions/Groups. Preparation: The Operations & Planning Staff will prepare the Assignment List(s) using guidance from the Response Objectives (ICS Form 202), the Operational Planning Worksheet (ICS Form 215) and Resource Unit Leader. The Planning Section Chief will approve the Assignments List. When approved, it is included in the Incident Action Plan. Distribution: The Assignment List is duplicated and included in the Incident Action Plan. In some cases, assignments may be communicated via radio. NOTE: A separate sheet is used for each Division or Group. Item Item Title Instructions 1. Branch Enter the Branch name. 2. Division/Group Enter the Division/Group name. 3. Incident Enter the name assigned to the incident. 4. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 5. Area Map (optional) 6. Tactical Objective Enter a brief statement o f the tactical objective to accomplish for the specified area. 7. Description of Work Enter a brief description of work to be accomplished to meet the objective specified for the area. 8. Location of Work Enter directions how to access the site or work area. 9. Safety Message Enter information such as known safety hazards and specific precautions to be observed in the area. 10. Environmental Considerations Enter any environmental issues or areas to consider. 11. Operational Personnel, Phone, Radio, & Pager Enter the operational personnel in charge of the area along with contact information for each. 12. Equipment Resources Enter the resource information for each resource assigned to the area or site such as supplier, resource type, description, quantity, and status. 13. Manpower Resources Enter the manpower assigned to the area or site such as supplier, resource type, description, quantity, and status. 14. Prepared By Enter the name of the Resources Unit Member or person completing the form. 15. Approved By Enter the name of the person approving the form (usually the Planning Section Chief). 16. Date/Time Approved Enter the date/time the form was approved. Incident Action Plan Software The Response Group - ICS Forms ICS 204 - Assignment List Incident: Branch: Period: / / : to / /• Division: Operations Personnel Title Name Affiliation Contact Number(s) Operations Section Chief Branch Director Division/Group/STAM Incident Resources — Equipment Supplier Resource Type Description Quantity Size Status Assignments Special Instructions for Division/Group Communications Name/Function Radio: Frequency/System/Channel Phone Cell/Pager Emergency Communications Medical Evacuation Other Prepared by (Resource Unit Leader): Approved by (Planning Section Chief): Date/Time Approved: ICS 204 Assignment List © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software ICS 204 - Assignment List Incident: Branch: Period: / / : to / / : Division: Prepared by Signature: Task Force: Approved by Signature: Group: Tactical Objective Description of Work Location of Work Work Assignment Special Instructions Special Equipment/Supplies Needed for Assignment Special Environmental Considerations Special Site -Specific Safety Considerations Shoreline Cleanup Assessment Team (SCAT) Considerations Prepared by (Resource Unit Leader): Approved by (Planning Section Chief): Date/Time Approved: ICS 204 Assignment List © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms COMMUNICATIONS PLAN (ICS 205) Purpose: The Communications Plan provides, in one location, information on all phone & radio frequency assignments for each operational period. Information from the Communications Plan on phone and frequency assignments is normally placed on the appropriate Assignment List (ICS Form 204). Preparation: The Communications Plan is prepared by the Communications Unit Leader and given to the Planning Section Chief. Distribution: The Communications Plan is duplicated and given to all recipients of the Incident Action Plan including the Incident Communications Center. Information from the plan is normally placed on the appropriate Assignment List(s) (ICS Form 204). Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Communications Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs. ). 3. Operational Period Enter the date and time interval for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. _ Phone Listing Enter the phone numbers assigned to each person to be used on the incident. Name Enter the name of the person Phone, Fax, & Radio Enter the phone, fax, and radio number assigned to each person Radio Utilization Enter the radio channel/frequency assigned to each person, place, or resource used on the incident. _ 6. - - - System Enter the name of the communication system Channel Enter the radio channel being utilized Function Enter what function the frequency is being used for Frequency Enter the frequency being utilized Assignment Enter the communication system assignment Notes Enter any notes or comments about the system Incident Action Plan Software The Response Group - ICS Forms ICS 205 - Communications Plan Incident: Prepared By: at: Period: / / : to / / :• Version Name: Basic Radio Channel Use System Channel Function Frequency Assignment Notes ICS 205 Communications Plan © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 205a - Communications List Incident: Prepared By: at: Period: / Version Name: Incident Assigned Position Name Phone Other Number — Desc. Email Address ICS 205a Communications List © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms MEDICAL PLAN (ICS FORM 206) Purpose: The Medical Plan provides information on incident medical aid stations, transportation services, hospitals and medical emergency procedures. Preparation: The Medical Plan is prepared by the Medical Unit Leader and reviewed by the Safety Officer. Distribution: The Medical Plan may be an attachment to the Response Objectives Form (ICS 202), or information from the plan pertaining to incident medical aid stations and medical emergency procedures may be taken from the plan and placed on the Assignment list(s) (ICS Form 204). Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Medical Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Operational Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. First Aid Stations Enter name, location, and contact information for the incident medical first aid stations (e.g. Staging Area, Camp Ground) and indicate if paramedics are located at the site by entering "Yes" or "No" in the Paramedics (EMT) field. 6. Transportation Ground Ambulance Services List name and address of ambulance services (e.g. Shaeffer, 4358 Brown Parkway, Corona). Provide phone numbers and indicate if ambulance company has paramedics by entering "Yes" or "No" in the Paramedics (EMT) field. 7. Air Ambulance Services List name and address of ambulance services (e.g. Shaeffer, 4358 Brown Parkway, Corona). Provide phone numbers and indicate if ambulance company has paramedics or doctors by entering "Yes" or "No" in the Doctor and Paramedics (EMT) field. 8. Hospitals List hospitals, which will serve this incident. Hospital name, address, phone number, radio and enter "Yes" or "No" to indicate whether the hospital has a burn center and/or helipad. 9. Medical Emergency Procedures Note any special emergency instructions for use by incident personnel. Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software ICS 206 - Medical Plan Incident: Prepared By: at: Period: / / to / / Version Name: First Aid Stations Name Location EMT (On -Site) Phone Radio Transportation (Ground and/or Ambulance Services) Name Location EMT Phone Radio Air Ambulances Name Location Doctor/Nurse EMT Phone Radio Hospitals Name Location Helipad Burn Center Phone Radio Special Medical Emergency Procedures ICS 206 Medical Plan © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms INCIDENT ORGANIZATION CHART (ICS FORM 207) Purpose: The Incident Organization Chart is used to indicate what ICS organizational elements are currently activated and the names of personnel staffing each element. The attached chart is an example of the kind of Organizational Chart used in the ICS. Personnel responsible for managing organizational positions would be listed in each box as appropriate. Preparation: The organization chart is prepared by the Resources Unit and posted along with other displays at the Incident Command Post. A chart is completed for each operational period and updated when organizational changes occur. Distribution: When completed, the chart is posted on the display board located at the Incident Command Post. Wall Size Chart. The ICS Form 207 WS is a large chart that is primarily used to post on the command post display board for better visibility. Incident Action Plan Software The Response Group - ICS Forms ICS 207 Organization Chart Incident: Prepared By: at: Period: / / • to / / Version Name: INCIDENT COMMAND — Information Officer Federal Safety Officer State , Liaison Officer Incident Commander _ _ _ _ Indicates initial Operations Section Chief Planning Section Chief Loaistics Section Chief Finance Section Chief I Operations Section Deputy Planning Section Deputy Lo.istics Section De.ut Finance Section Deputy •n -Scene Commander Staging Area Manager Resource Unit Leader Su. •ort Branch Dir Cost Unit Leader Recover & Prot. Branch Emergency Resp. Branch Wildlife Branch Situation Unit Leader Supply Unit Leader Comp./Claims Unit Leader Pr • • • • Wildlife Rehab NRDA Representative Securit Unit Leader On Water Grou• Recovery of Supv I Doc. Unit Leader Services Branch Dir Disposal Group Air O•s Branch J Environmental Unit Food Unit Leader Decon Group Air Support Group -� Check -In Status Recorder Medical Unit Leader ICS 207 Organization Chart © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms SITE SAFETY AND HEALTH PLAN (ICS FORM 208) Purpose: The Site Safety and Health Plan (SSHP) is a site-specific document required by state and federal OSHA regulations and specified in the Area Contingency Plan. The SSHP, at minimum addresses, includes, or contains the following elements: health and safety hazard analysis for each site task or operation, comprehensive operations work plan, personnel training requirements, PPE selection criteria, site-specific medical monitoring requirements, air monitoring plan, site control measures, confined space entry procedures (if needed), pre -entry briefings (tailgate meetings), pre -operations commencement health and safety briefings for all incident participants, and quality assurance of SSHP effectiveness, Preparation: The Safety Officer prepares the SSHP with input from the Industrial Hygienist and Medical Unit Leader. Distribution: The SSHP is distributed to the Operations Section Chief for implementation and promulgation to all operational groups and responding agencies. A copy is provided to the Incident Commander, the Command Staff, and the General Staff. Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software ICS 208 - Site Safety Plan Incident: Prepared by: at: Period: / / : to / / : Version Name: Revision: Applies To Site: Products: (Attach MSDS) SITE CHARACTERIZATION Wave Height: Current Speed: Weather: Wind Speed: Pathways for Site Hazards Boat Safety Chemical Cold Stress Confined Drum handling Equipment Electrical Fatigue Other Water: Wave Direction: Direction: Direction: burning utilities Current Land: Use: Temp: Wind Dispersion: hazards Spaces operations operations Fire, explosion, in-situ Heat stress Helicopter operations Lifting Motor vehicles Noise Overhead/buried Plants/wildlife Other Pump hose Slips, trips, and falls Steam and hot water Trenching/Excavation UV Radiation Visibility Weather Work near water Other Air Monitoring %02: ppm H2S: %LEL: ppm Benzene: Other (Specify): CONTROL Engineering Personal Additional MEASURES Controls Source of release secured Site secured Protective Equipment Impervious suit Inner gloves Outer gloves Flame resistance clothing Hard hats Control Measures Decontamination Sanitation Illumination Medical Surveillance Valve(s) closed Facility shut down Stations established Facilities provided Facilities provided Provided Respirators Eye protection Personal Boots Other Energy source locked/tagged out Other floatation ICS 208 Site Safety Plan © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 208 — Site Safety Plan Incident: Prepared By: at: Period: / / : to / / : Version Name: WORK PLAN Booming Skimming Heavy Equip Sorbent pads Other Vac trucks Patching Pumping Excavation Hot work Appropriate permits used TRAINING Verified site workers trained ORGANIZATION Title Name Telephone/Radio Incident Commander: Deputy Incident Commander: Safety Officer: Public Affaire Officer: Other: EMERGENCY PLAN Alarm system: Evacuation plan: First aid location Notified Hospital Phone: Ambulance Phone: Air ambulance Phone: Fire Phone: Law enforcement Phone: Emergency response/rescue Phone: PRE -ENTRY BRIEFING Initial briefing prepared for each site INCLUDING ATTACHMENTS/APPENDICES Attachments Appendices Evaluation Checklist Entry Checklist Hypothermia Consideration Stings, and Poisonous Plant Contact for Oily Bird Rehabilitation Briefing System Site Map Hazardous Substance Information Sheets Site Hazards Monitoring Program Training Program Confined Space Entry Procedure Safe Work Practices for Boats PPE Description Decontamination Communication and Organization Site Emergency Response Plan ❑ Site Safety Program ❑ Confined Space ❑ Heat Stress Consideration ❑ Cold Stress and ❑ First Aid for Bites, ❑ Safe Work Practice ❑ SIPI Site Pre -Entry ❑ Personnel Tracking ICS 208 — Site Safety Plan © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms INCIDENT STATUS SUMMARY (ICS FORM OS -209 — OIL SPILL) Purpose: The Incident Status Summary serves the following purposes: 1. Used by Situation Unit personnel for posting information on Status Boards. 2. When duplicated and provided to Command Staff members, it provides them with basic information for use in planning for the next operational period. 3. It provides information to the Information Officer for preparation of media releases. 4. It summarizes incident information for local and off-site coordination centers. Preparation: The Situation Unit prepares the Incident Status Summary. Resources information should be obtained from the Resources Unit. It is scheduled for presentation to the Planning Section Chief and other General Staff members prior to each Planning Meeting and may be required at more frequent intervals by the Incident Command or Planning Section Chief. Distribution: When completed, the form is duplicated and copies are distributed to the Incident Command and staff, and all Section Chiefs, Planning Section Unit Leaders, and the Joint Information Center. It is also posted on a status board located at the ICP. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Situation Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs. ). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Spill Status Enter the estimated amounts in barrels or gallons for each category. 6. Mass Balance Enter the estimated amounts in barrels or gallons for each category initially using a trajectory model or the NOAA Adios model. Actual numbers reported by operations should be used when available. 7. Waste Management Enter the estimated amounts in barrels or gallons for each category based on report from operations. 8. Shoreline Impacts Enter the total miles of shoreline oiled categorized by the degree of oiling(light, medium, heavy). 9. Wildlife Impacts Indicate the number of oiled wildlife. 10. Safety Status Indicate the number of serious injuries. 11. Onshore Equipment Resources Indicate which types are deployed, are expected on scene, and their availability. 12. Offshore Equipment Resources Indicate which types are deployed, are expected on scene, and their availability. 13. Personnel Resources Indicate the numbers of personnel assigned by agency. 14. Comments Use this area for other information Incident Action Plan Software The Response Group - ICS Forms ICS 209 (Oil SpiII) - Incident Status Summary Incident: Prepared By: at: Period: / / : to / / : Version Name: SpiII Status (Estimated, BBLs) Equipment Resources Source Status: Secured: Remaining Potential: Type Ordered Available/ Staged g Assigned Out -of - Service UnSecured: Rate of Spillage: Last 24 Hours Total Mass Balance/Oil Budget Since Last Report Total Quantity Volume Spilled/Released Recovered HAZMAT/Oil Evaporation/Airborne Natural Dispersion Chemical Dispersion Burned Floating, Contained Floating Uncontained Onshore Total spilled product accounted for: Waste Management (Estimated BBLs) Type Recovered Stored Disposed of Oil Oily Liquid Liquid Oily Solid Solid Personnel Resources Shoreline Im acts p Organization People in the Field People in Cmd. Post Total People on Scene Degree of Oiling Miles Affected Miles Cleaned Miles Remaining to be Cleaned Federal Light State Medium RP Heavy Local Total Wildlife Impacts Type Captured Cleaned Released DOA Died in Facility Total Response Personnel: Bird Comments Mammal Reptile Fish Other Total Safety Status ' Type Last 24 Hours Total Responder Injury Public Injury Other ICS 209 (Oil SpiII) Incident Status Summary © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms CHECK IN LIST (ICS FORM 211) Purpose: Provides written documentation as to when personnel and equipment arrive at various incident locations. Check-in consists of reporting specific information, which is recorded on the Check -In List. Initiation of Form: The Check-in List is initiated at a number of incident locations including: Staging areas, base, camps, helibases, and ICP. Managers at these locations record the information and give it to the Resources Unit as soon as possible. Distribution: Check -In Lists, which are completed by personnel at the various check-in locations, are provided to both the Resources Unit and the Finance Section. The Resources Unit maintains a master list of all equipment and personnel that have reported to the incident. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. Check-in Location Check the appropriate location. 3 Operational Period Enter the date and time interval for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4 Date/Time Prepared Enter date & time prepared (e.g. 09/17/2000 1500hrs.). 5. Prepared By Enter the name of the Resource Unit Leader or person preparing the form. 6. Name Enter name (last, first). 7. Classification Enter job classification (e.g. spill tech, supervisor...). 8. Company Enter name of individual's employer. 9. Check -In Date/Time Enter date and time entering site (01/01/01 / 0600 hr). 10. Check -Out Date/Time Enter date and time exiting site (01/01/01 / 0600 hr). 11. Home Base Location at which the resource/individual is normally assigned. (May not be departure location). 12. Method of travel Means of travel to incident (bus, truck, engine, personal vehicle, etc.) 13. Assigned Position Assignment at time of dispatch. Incident Action Plan Software The Response Group - ICS Forms ICS 211p - Check -In List (Personnel) Incident: Prepared By: at: Period: / / : to / / :• Version Name: Check -In Location - - Command Post Staging Area Other: -- > Location Name: Personnel Check -In Information Name (Last, First) & Contact Information Classification & Company/Agency Assigned Section & Position quantity Check -In Date/Time Check -Out Date/Time/Destination ICS 211P Check -In List (Personnel) © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 211e - Check -In List (Equipment) Incident: Prepared By: at: Period: / / : to / / : Version Name: Check -In Location: Command Post Staging Area Other -- > Location Name: Equipment Check -In Information Equipment Description & Identifier Supplier & Contact Information Quantity & UOM Size & UOM Check -In Date/Time Check -Out Date/Time/Destination ICS 211e Check -In List (Equipment) © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms REQUISITION (ICS FORM 213) REQUESTOR: The requestor must fill in Blocks 1 through 8. Item Item Title Instructions 1. Requested by Person requesting resource(s). 2. Priority Low, Medium, High, or Immediate. This information is needed for the ordering official. This will be considered routine or low priority unless otherwise indicated. 3 Approval This must be approved by the Section Chief or Deputy Section Chief. 4 Requested Delivery Date/Time When resources need to be delivered. 5. Requested Delivery Location Initial delivery location for resources (Staging Areas). 6. Final Destination Where resources will be deployed. 7. Notes Suggested Sources: Enter applicable information if known. 8. Items requested Must include quantity, resource type, detailed description of requirements, estimated time needed (for rentals), and estimated price. BE AS SPECIFIC AS POSSIBLE. LOGISTICS SECTION: The following blocks are to be filled out be the Supply Unit. 9. Checked Out By Person fulfilling request. 10. Checked Out Date/Time 11. Supplier This information is needed for Credit Card purchases and/or Purchase Orders, and Resource Tracking. 12. Items procured Must include detailed description resource, quantity, estimated time of arrival, unit price, and rental/purchase. Incident Action Plan Software The Response Group - ICS Forms ICS 213 Resource Request Incident: Prepared By: at: Period: / / to / / Version Name: Requisition Number: Created Date/Time: Requested Delivery Date/Time: Requested Delivery Location: Final Destination: Requested By: Requestor Phone: Priority: Completed By: Notes: Requested (Requestor) Procured (Logistics) Quantity Resource Type Description Size Supplier Quantit Size ETA Rental? ( Unit Price P.O. # Yes/No Yes/No Yes/No Yes/No Yes/No Yes/No Yes/No Yes/No Supplier Contact Information Supplier Contact Name Phone 1 Phone 2 Fax Email Approvals Name/Position Name/Position Name/Position ICS 213 Resource Request © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms UNIT LOG (ICS FORM 214) Purpose: The Unit Log is used to record details of unit activity including specialized team activity (e.g., Strike Team). The file of these logs provides a basic reference from which to extract information for inclusion in any after -action report. Initiation of Form: A Unit Log is initiated and maintained by Command Staff members, Division/Group Supervisors, Air Operations Groups, Strike Team/Task Force Leaders, and Unit Leaders. Completed logs are forwarded to supervisors who provide copies to the Documentation Unit. Distribution: The Documentation Unit maintains a file of all Unit Logs. It is necessary that one copy of each log be submitted to the Documentation Unit. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Unit Name/Designators Enter the title of the organizational unit or resource designator (e.g., Facilities Unit, Safety Officer, Strike Team). 6. Unit Leader Enter the name of the individual in charge of the Unit. 7. Personnel Roster Assigned List the name, position, and home base of each member assigned to the unit during the operational period. 8. Activity Log Enter the time and briefly describe each significant occurrence or event (e.g., task assignments, task completions, injuries, difficulties encountered, etc.) Incident Action Plan Software The Response Group - ICS Forms Incident: Period: / / ICS 214 Unit Log Prepared By: at: : : to Version Name: Personnel Roster Assigned Name ICS Position i Home Base Activity Log Date/Time I Events/Notes ICS 214 Unit Log © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ICS 214a Individual Logs Incident: Prepared By: at: : Period: / / : to / / Version Name: Activity Log Date/Time 1 Events/Notes ICS 214a Individual Logs © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms OPERATIONAL PLANNING WORKSHEET (ICS FORM 215) Purpose: The purpose of this form is to communicate the decisions made during the Planning Meeting concerning resource assignments to the Resources Unit. The Worksheet is used by the Resources Unit to complete Assignment Lists and by the Logistics Section Chief for ordering resources for the incident. Initiation of Form: The Operations & Planning Section Chiefs initiate this form at each Planning Meeting. It is recommended that the format be drawn on the chalkboard, and when decisions are reached, the information is recorded on the form. Distribution: When the division work assignments and accompanying resource allocations are agreed to, the form is distributed to the Resources Unit to assist in the preparation of the Assignment Lists. The Planning Section will use a copy of this worksheet for preparing requests for resources required for the next operational period. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. Date / Time Prepared Enter date (e.g. 09/17/1996) and time (e.g. 1530) prepared. 3. Operational Period Enter the time interval for which the information applies (e.g. 1800 09/17/1996 to 0600 09/18/1996). 4. Area of Operation Enter the Division letter or location of the work assignment for the resources. 5. Work Assignments Enter the specific work assignments given to each of the Divisions. 6. Resource Complete resource headings, both for kind and type appropriate for the incident. Enter, for the appropriate resources, the number of resources by type (engines, crew, etc.) required "REQ", and the number of resources available "HAVE" to perform the work assignment. The number of resources needed "NEED" is automatically calculated. 7. Reporting Location Enter the specific location the "needed" resources are to report for the work assignments (staging area, etc.). 8. Requested Arrival Time Enter time resources are requested to arrive at the reporting location (e.g. 1530). 9. Total Resources Required, On Hand, Needed Enter the total number of resources by type (crew, dozers, etc.) required, on hand). The number of resources needed is automatically calculated. 10. Prepared By Record the name and position of the person completing the form. Incident Action Plan Software The Response Group - ICS Forms ICS 215 Operational Planning Worksheet Incident: Prepared By: at: Period: / / to / / Version Name: Branch/ Division/Area of Operation Work Assignments Reporting Location Requested Arrival Date/Time Resource Req Have Need Req Have Need Req Have Need Req Have Need Req Have Need Req Have Need Req Have Need Req Have Need Req Have Need ICS 215 Operational Planning Worksheet © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms INCIDENT ACTION PLAN SAFETY ANALYSIS (ICS FORM 215A -CG) Purpose: This form communicates to the Operations and Planning Section Chiefs safety and health issues identified by the Safety Officer. The Worksheet is used by the Resources Unit to complete ICS 204 Forms and Operations briefings. Preparation: This form is principally crafted by the Safety Officer. Use additional sheets, as needed. Distribution: When the safety analysis is completed, the form is distributed to the Resources Unit to help Prepare Operations briefing packages. All completed original forms MUST be given to the Documentation Unit. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. Date / Time Prepared Enter date (e.g. 09/17/1996) and time (e.g. 1530) prepared. 3. Operational Period Enter the time interval for which the information applies (e.g. 1800 09/17/1996 to 0600 09/18/1996). 4. Area of Operation Enter the Division letter or location of the work assignment for the resources. 5. Work Assignments Obtain specific work assignments from Operations given to each of the Areas of Operations. 6. Blank Risk Header Enter appropriate title for risk. 7. Blank Risk Mitigation Header Enter appropriate title for risk mitigation. 8. Blank Risk Cells Enter an X to indicate a risk type of concern in a Division/group. 9. Blank Risk Mitigation Cells Enter an X to indicate mitigation for risk to Division or group. 10. Prepared By Record the name and position of the person completing the form. Incident Action Plan Software The Response Group - ICS Forms Incident Action Plan Software ICS 215a — CG: Safety Analysis Incident: Prepared By: at: Period: / / : to / / : Version Name: Hazards Controls Area/Division/Group Work Assignment Gain S E V E R I T Y P R 0 B E X P 0 S U R E G A R Human Health • Security ■ Environment ❑ Economy ❑ Human Health • Security ■ Environment ❑ Economy ❑ Human Health • Security ■ Environment ❑ Economy ❑ Human Health • Security ■ Environment ❑ Economy ❑ Operational Risk Management Key Scale 1 2 3 4 5 GAR Scale r # 1-19 20-39 40-59 60-79 80-100 Severity Slight Minimal Signif- icant Major Catas- Trophic Risk Color Action Slight Green Possibly Acceptable Possible Amber Attention Needed Substantial Red Correction Required High Red Immediate Correction Very Hi.h Red Discontinue/ Stop Probability Remote Unlikely 50/50 >50% Very Likely Exposure Below Avg Avg Above Avg Great N/A ICS 215a -CG: Safety Analysis © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms Support Vehicle/Equipment Inventory (ICS Form 218) Purpose: The Support Vehicle/Equipment Inventory (ICS 218) provides an inventory of all transportation and support vehicles and equipment assigned to the incident. The information is used by the Ground Support Unit to maintain a record of the types and locations of vehicles and equipment on the incident. The Resources Unit uses the information to initiate and maintain status/resource information. Preparation: The ICS 218 is prepared by Ground Support Unit personnel at intervals specified by the Ground Support Unit Leader. Distribution: Initial inventory information recorded on the form should be given to the Resources Unit. Subsequent changes to the status or location of transportation and support vehicles and equipment should be provided to the Resources Unit immediately. Item Item Name Instructions 1. Incident Name Enter the name assigned to the incident. 2. Incident Number Enter the number assigned to the incident. 3. Date/Time Prepared Enter the date (month/day/year) and time (using the 24-hour clock) the form is prepared. 4. Vehicle/Equipment Category Enter the specific vehicle or equipment category (e.g., buses, generators, dozers, pickups/sedans, rental cars, etc.). Use a separate sheet for each vehicle or equipment category. 5. Vehicle/Equipment Information Record the following information: Incident Identification Number Enter any special incident identification numbers or agency radio identifier assigned to the piece of equipment used only during the incident, if this system if used (e.g., "Decontamination Unit 2." or "Water Tender 14"). Type Enter the specific vehicle or equipment classification (e.g., bus, backhoe, Type 2 engine, etc.) as relevant. Make Enter the vehicle or equipment manufacturer name (e.g., "GMC," "International"). Capacity, or Size Enter the vehicle or equipment category/kind/type, capacity, or size (e.g., 30- person bus, 3/4 -ton truck, 50 kW generator). Owner Enter the operator name and/or contact information (cell phone, radio frequency, etc.). Location & Release Date/ Time Enter where the vehicle or equipment will be located at the incident and its function (use abbreviations per discipline or jurisdiction). Incident Action Plan Software The Response Group - ICS Forms ICS 218 - Support Vehicle Inventory Incident: Prepared By: at Period: / / : to / / :• Version Name: Vehicle Information Type Make Capacity or Size Owner ID Number Location Release Date/Time ICS 218 - Support Vehicle Inventory © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms AIR OPERATIONS SUMMARY (ICS FORM 220) Purpose: This form provides Air Operations Unit with the number, type, location and specific assignments of helicopters and fixed -wing aircraft. Initiation of Form: The Unit Leader of the Air Operations Unit or Logistics Section Chief completes the summary during each Planning Meeting. The Air and Fixed -Wing Support Groups provide specific designators of the air resources assigned to the incident. Distribution: After the summary is completed by Air Ops. Personnel, the form is given to the Air Support Group Leader and Fixed Wing Support Personnel. These personnel complete the form by indicating the designators of the helicopters and fixed -wing aircraft assigned missions during the specified operational period. This information is provided to Air Operations personnel who, in turn, give the information to the Resources Unit. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Air Operations, Logistic Section Chief, or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Type of Aircraft Enter the type of aircraft being used for the incident. (e.g. Helo Bell 206, Fixed Wing DC -4) 6. Operating Base Enter the base (helibase, helispot, fixed -wing base) from which each air resource is expected to initiate operations. 7. Aircraft Company Enter the name of the company providing the aircraft. 8. Passenger Capacity Indicate the numbers of passengers the aircraft will accommodate. 9. Purpose Indicate the function or role the aircraft is being used for the incident. 10. Scheduled Flights Indicate when aircraft will be available for use and when flights are scheduled. Incident Action Plan Software The Response Group - ICS Forms ICS 220 - Air Operations Incident: Prepared By: at: Period: / / : to / / : Version Name: Personnel and Communications Title/Position Name Air/Air Frequency Air/Ground Frequency Phone Planned Flight Information Type Of Aircraft Operating Base Aircraft Company Passenger Capacity Purpose Scheduled Flights Notes (Special Instructions, Safety Notes, Hazards, Priorities) ICS 220 - Air Operations © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms DEMOBILIZATION CHECK OUT (ICS FORM 221) Purpose: The Demobilization Check Out form is used to provide information to the Planning Section about resources that are released from the incident response. Preparation: The Demobilization Unit Leader or the Planning Section Chief prepares the Demobilization Check Out form. The Demobilization Unit Leader completes the top portion of the form after the resource supervisor has given written notification that the resource is no longer needed. Distribution: The individual resource will have the unit leader initial the appropriate box(es) in item 5 prior to release from the incident. After completion, the form is returned to the Demobilization Unit Leader or the Planning Section. All completed original forms MUST be given to the Documentation Unit. For each released resource, enter the unit/personnel released, released time/date, resource type, description, supplier, quantity and size. Use more than one line per resource if necessary. Obtain the appropriate signatures for authorization. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Demobilization Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Unit/Personnel Released Enter the specific name of the resource being released. 6. Released Date/Time Enter the date and time the resource was released (e.g. 09/17/2000 1500hrs.). 7. Resource Type Enter the type of the resource released. 8. Description Enter a description of the resource released 9. Supplier Enter the name of the company that provided the resource. 10. Quantity Enter the quantity of the resource released. 11. Size Enter the size of the resource released (if applicable). Incident Action Plan Software The Response Group - ICS Forms ICS 221 - Demob. Check Out Incident: Prepared By: at: Period: / / : to / / : Version Name: Unit/Personnel Released: Released Date/Time: You and your resources have been released, subject to signoff from the following: Resources Resource Type Description Supplier Quantity Size Signatures Comments ICS 221 Demobilization Check Out © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms The Daily Meeting Schedule (ICS FORM OS -230) Purpose: The Daily Meeting Schedule is use to record daily scheduled meeting activities, for information purposes. PREPARATION: THE SITUATION UNIT LEADER AND PLANNING SECTION CHIEF PREPARE THE DAILY MEETING SCHEDULE COORDINATED THROUGH THE INCIDENT COMMAND FOR DAILY MEETING SCHEDULE (ICS FORM OS -230) each Operational Period or as needed. Distribution: After coordination with the Incident Command, the Situation Unit Leader will duplicate and post a copy at the command post and distribute to the Command Staff, Section Chiefs, Branch Directors, Division/Group Supervisors, and appropriate Unit Leaders. For each scheduled meeting, enter the time, meeting name, purpose and location. Use more than one line per meeting if necessary. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Situation Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Meeting Date/Time Enter the date/time the meeting is planned for. 6. Meeting Name Enter the meeting name. 7. Purpose Enter the purpose of the meeting. 8. Attendees Enter who should attend the meeting. 9. Location Enter the location the meeting will be held. Incident Action Plan Software The Response Group - ICS Forms ICS 230 - Daily Meeting Schedule Incident: Prepared By: at: Period: / /: to / / : Version Name: Meeting Name & Date/Time Purpose Attendees Location ICS 230 — Daily Meeting Schedule © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms RESOURCES AT RISK (ICS FORM OS -232) Purpose: The Resources at Risk Summary is used to record and identify details of the Situation Unit including Technical Specialist activity. It also serves as the Environmental Operations Plan. Preparation: The Situation Unit Leader in coordination with the Scientific Support Coordinator (SSC) Specialist, with input from the Resources at Risk (RAR) Technical Specialists, and other resources trustees, will complete this form for each Operational Period. Distribution: Each Operational Period, a copy must be forwarded to the Planning Section Chief for the Incident Command to serve as an Environmental Operations Plan (part of the Incident Action Plan). The SSC Specialist must also maintain a copy. Item Item Title Instructions 1. Incident Enter the name assigned to the incident. 2. Prepared By Enter the name of the Environmental Unit Leader or person preparing the form and the date & time prepared (e.g. 09/17/2000 1500hrs.). 3. Period Enter the date and time interval of the operational period for which the form applies (e.g. 0600 09/17/2000 to 0600 09/18/2000). 4. Version Name 5. Site Number Enter number assigned to site. 6. Priority Enter priority as it relates to degree of sensitivity. 7. Site Name &/or Location Enter the site name and the physical location of the site. 8. Site Issues Enter a narrative clarifying the sites and wildlife issues described for each. Incident Action Plan Software The Response Group - ICS Forms ICS 232 - Resources at Risk Incident: Prepared By: at: Period: / / : to / / : Version Name: Environmentally Sensitive Areas and Wildlife Issues Site # Priority Site Name and/or Physical Location Site Issues Notes: Notes: Notes: Notes: Notes: Archaeo-cultural and Socio-economic Issues Site # Priority Site Name and/or Physical Location Site Issues Notes: Notes: Notes: Notes: ICS 232 Resources at Risk © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms ACP SITE INDEX (ICS FORM 232A -OS) Special Note: This optional form is designed to be a key to the site numbers or site names shown on the Situation Map. The information on priorities for environmentally -sensitive areas and archaeo-cultural and socio-economic issues from the ICS form 232 -OS may be transferred to ICS form 232a - OS, which provides more information on the Area Contingency Plan (ACP) or Geographic Response Plan (GRP) site numbers or names shown on the Situation Map. Purpose: If used, this form is posted next to the Situation Map, providing a key to the ACP/GRP sites shown on the map. Preparation: The Situation Unit personnel responsible for the Situation Map prepare this form, using ICS form 232 -OS prepared by the Environmental Unit. Distribution: This form is posted next to the Situation Map and copies of this form should accompany any distributed copies of the Situation Map. All completed original forms MUST be given to the Documentation Unit. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident 2. Operational Period Enter the time interval for which the form applies Record the start and end date and time. 3. Index to ACP/GRP sites shown on Situation Map Enter site information from the Area Contingency Plan (ACP) or Geographic Response Plan (GRP) or other sources specified to this incident 4. Site Number Can come from an Area Contingency Plan (ACP) of Geographic Response Plan (GRP) or can be created during an incident. 5. Priority Priority specific to this incident. 6. Site Name and/or Physical Location Name of the site (e.g., Marsh Point., Glacier Creek, etc.) and/or physical location (e.g., address, lat/long, landmarks, etc.) 7. Action Actions to be taken for designated protection and collection strategies or for other sites identified specifically for this incident. 8. Status Status of site action implementation (e.g., scheduled, in progress, completed). 9. Prepared By Date/Time Enter name and title of the person preparing the form. Enter date (month, day, year) and time prepared (24-hour clock). Incident Action Plan Software The Response Group - ICS Forms ICS 232a - ACP Site Index Incident: Prepared By: at: Period: / / to / / : Version Name: Index to ACP/GRP sites shown on Situation Map Site # Priority Site Name and/or Physical Location Action Status Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: Notes: ICS 232a ACP Site Index © 1997-2012 TRG/dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms OPEN ACTION TRACKER (ICS 233) Purpose: Open Action Tracker 1. Is used by the Incident Commander/Unified Command (IC/UC) to assign and track tasks/actions to IMT personnel that do not rise to the level of being an Incident Objective. 2. Is duplicated and provided to Command and General Staff members, giving them the open tasks/actions needing to be completed and a means to track the open tasks/actions they have been assigned. Note: This form may also be used by Command and General Staff for tracking tasks/actions within a Section/Staff element. Preparation: The Planning Section Chief (PSC) is responsible for maintaining the Open Action Tracker for the IC/UC and typically utilizes the Documentation Unit Leader (DOCL) to assist in this forms development and updating. The PSC should ensure all Command and General Staff are prepared to discuss their assigned tasks/actions during the Command and General Staff and Planning Meetings. Distribution: When completed. The form is duplicated and copies are distributed to the Unified Command and Command and General Staff. It is also posted on a status board located at the ICP. All completed original forms MUST be given to the Documentation Unit. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. No. Enter number of task in sequential order (1,2,3,...). 3. Item Enter short descriptive of the task/action to be completed. Task/Actions are important to be completed but are not an Incident Objective which are documented on the ICS -202 form. 4. For/POC Enter the Point of contact (POC), the responsible person/section. 5. Briefed to POC Enter "X" when the task/action has been briefed to the POC/responsible person. This is to ensure that tasks/actions identified outside of the POC's presence (during Unified Command Meeting for example) are briefed to and acknowledged by the identified POC. 6. Start Date Enter the date the task/action was initially assigned under "Start Date." 7. Status Enter Status of item. For example: "Awaiting Le Gear", Updated needed", "Awaiting Feedback". When the item is completed, the word "completed" is entered and if working in MS Excel, the task is cut and pasted into the worksheet labeled "COMPLETED." 8. Target Date Enter deadline task/action should be completed. In the Excel Worksheet, there is a hidden formula that shows green, yellow and red blocks. When the target date is one day away, the block turns yellow. When it is overdue it turns red. When the block is yellow, it serves as a reminder to the UC/POC that the target date is nearing and the POC needs to complete the task or the target date needs to be updated. 9. Actual Date Enter actual date task/action completed Note: In order to ensure the red and yellow reminders work for new tasks, the user simply copies a task line, inserts it into the worksheet and overtypes the new task information. Incident Action Plan Software The Response Group - ICS Forms ICS 233 - Open Action Tracker Incident: Prepared By: at: Period: / / : to / / : Version Name: Item Number Description Responsible Section/Person Status Start Date Briefed Target Date ICS 233 — Open Action Tracker © 1997-2012 dbSoft, Inc. Incident Action Plan Software The Response Group - ICS Forms WORK ANALYSIS MATRIX FORM INSTRUCTIONS (ICS FORM 234) Purpose: The Work Analysis Matrix is designed to help select the best strategies and tactics to achieve the operational objectives. This optional form assists staff in carrying out incident objectives by outlining the who, what, where, when, and how of the response. The tactics from this form carry forward to the "Work Assignment" on the ICS -215. Another purpose of the ICS -234 is that it presents alternative (or what -if) strategies and tactics to respond to bad weather, sudden changes in operational conditions. etc. This form is simply a formalized version of how OSCs tend to think in order to turn objectives into tactical field work. Preparation: The Work Analysis Matrix, if used, is usually completed by the Operations Section Chief and Planning Section Chief prior to the Tactics Meeting. Distribution: All completed original forms must be submitted to the Documentation Unit. Item Item Title Instructions 1. Incident Name Enter the name assigned to the incident. 2. Operational Period Enter the time interval for which the form applies. Record the start and end date and time. 3. Operational Objectives Enter the relevant Operational Objectives from the ICS 202, with numbers. 4. Operational Strategies Enter all strategies that could be used to meet the objective ("how") 5. Tactics/Work Assignments Enter details, including as much as possible, who, what, where, and when. Of work assignments to carry out Operational Strategies. 6. Prepared By Enter the name and position of the person preparing the form. 7. Date/Time Enter the date and time (24-hour format) the form was prepared. Incident Action Plan Software The Response Group - ICS Forms ICS 234 - Work Analysis Matrix Incident: Prepared By: at: Period: / / :• to / / : Version Name: Objectives Operations Objectives Optional Strategies Tactics/Work Assignments ICS 234 — Work Analysis Matrix © 1997-2012 dbSoft, Inc. Incident Action Plan Software /r 1J Marathon OW Piceance Operations Emergency Response Plan Appendix Forms Air Monitoring Plan March 2013 © The Response Group Page 66 Marathon Oil Company Air Monitoring Plan INCIDENT INFORMATION FORM Incident Name: Location: Date/Time Prepared: Prepared by: Date/Time of Incident: Type of Incident: (spill, gas/vapor release, fire, etc.) Product(s) of Concern: (Attach MSDS) Product Components of Concern Exposure Limit Test Method ❑ Benzene 1 ppm Ultra RAE/GC ❑ Hydrocarbons (VOC's) Multigas/PID ❑ LEL 10% Multigas ❑ Oxygen <19.5% or >23.5% Multigas ❑ Hydrogen Sulfide 10 ppm Chemical sensor/Detector Tube ❑ Hydrogen Fluoride 3 ppm Chemical sensor/Detector Tube ❑ Carbon Monoxide 25 ppm Chemical sensor/Detector Tube ❑ Sulfur Dioxide 2 ppm Chemical sensor/Detector Tube ❑ Ammonia 25 ppm Detector tube Other Contaminants o CI El CURRENT SITUATION Incident Status (Source Control & Response: Environmental Conditions: ❑ Ice ❑ Rain Temp. ° F ❑ Snow Wind: Direction Hg ❑Other MPH Barometric Pressure inches Relative Humidity ok SITE SAFETY PLAN (attach ICS 208) Employee Impact: Community Impact: 1 Incident Information, Page 2 Initial Air Monitoring Data: % 02 % LEL ppmH2S ppm Benzene Other: Personal Protective Equipment Required: ❑ Impervious suits ❑ Respirators ❑ Gloves ❑ Eye Protection ❑ Flame resistant clothing ❑ Personal flotation ❑ Hard hats ❑ Boots ❑ Hearing Protection ❑ Other Monitoring Personnel Required: Monitoring Equipment Required: (including where equipment is being sourced from): Diagram with impacted areas, landmarks, wind direction, etc. indicated: 2 EXPOSURE ASSESSMENT PLAN Incident Name: Location: Date/Time Prepared: Prepared by: Exposure to: (Attach related MDSD) Purpose of Plan: Personnel Exposure Monitoring Prioritized Work Task and Location Planning Cycle Indicate 8 hrs 12 hrs Other No. of Employees On Task No. of Employees To Monitor Monitoring Method (OVM/Sorbent Tube/Other) Area/Residential Exposure Monitoring Exposure Monitoring Method Code Location Description (Including background samples) Monitoring Method Code Frequency A — AreaRAE B — Handheld Multigas 02 C — Handheld PID/VOCs D — Benzene Specific PID/GC E — Detector Tube: F — OVM (3M3520) G — Sorbent tube: H — Grab (Summa Can. Or Bag) 0 - Other J — Other (See reverse side) 3 Exposure Assessment Plan, page 2 Diagram of Area Monitoring Locations (Notating potentially sensitive areas; indicating monitoring methods) Resources Air Monitoring Teams Name/Organization Name/Organization Work hours Monitoring Equipment Manufacturer Model Cal. Gas Required Expendables Required Included Attachments/Appendices ❑ Map(s) ❑ Real -Time Air Monitoring Field Data Form(s) ❑ Marathon Urine Phenol Protocol ❑ Residential Clearance Monitoring Form(s) ❑ Hydrocarbons Exposure Assessment Procedure ❑ Hydrogen Sulfide/Toxic Gases Exposure Procedure ❑ Particulate Exposure Assessment Procedure ❑ Environmental Noise Exposure Assessment Procedure ❑ OVM Protocol ❑ PID Protocol ❑ Summa Canister Protocol ❑ Area RAE Protocol ❑ Other: ❑ Other: ❑ Other: ❑ Other: 4 INDUSTRIAL HYGIENE SAMPLE FORM Incident Name: Sampler Name: Date: Environmental Ace Conditions Temp. Barometric of ❑Rain ❑snow ❑Other Wind: Direction inches Hg Relative MPH Pressure Humidity % Employee Name Component/Contractor ID No. Start Stop Badge No. PPE Worn Specific Area Worked/ Task 5 Page of AIR MONITORING TEAM FIELD DATA FORM Incident Name: Sampler Name: Date: Monitoring For: Equipment Used (Circle Appropriate): UltraRAE Detector Tubes Multigas/LEL Other: UltraRAE (VOC) UltraRAE (Benzene) Multigas/LEL Other Detector Tubes Serial No. Serial No. Mfg/Model: Mfg/Model: Mfg: Pre -Cal. Date/Time: Pre -Cal. Date/Time: Serial No: Serial No: Tube Type: Post -Cal. Date/ Time: Post -Cal. Date/Time: Pre -Cal. Date/Time: Pre -Cal. Date/Time: Tube Range: Calibration Gas Lot: Calibration Gas Lot: Post -Cal. Date/Time: Post -Cal. Date/Time: RAE -SEP Tube Batch# Calibration Gas Lot: Calibration Gas Lot: Monitoring Results Location ID Location Description/GPS Coordinates Time VOC (ppm) Benzene (ppm) LEL% H2S Other (List) Observations/Comments 6 Page of AIR MONITORING TEAM FIELD DATA FORM Monitoring Results Location ID Location Description/GPS Coordinates Time voc (ppm) Benzene (ppm) LEL% H2S Other (List) Observations/Comments 7 HOT ZONE PERSONNEL TRACKING (Any personnel entering /departing a work area shall report to the site supervisor or designated representative). NAME & COMPANY LOCATION TIME-ENTRY/EXIT 8 INSTRUMENT CALIBRATION CHECK Calibration Results must be in the following range: LEL: % to % 02: % to % PID: ppm to ppm Other: ppm to ppm Other: ppm to ppm Other: ppm to ppm Other: ppm to ppm If instruments cannot be calibrated to the above manufacturer's listed ranges, the instrument must be taken out of service and repaired. Instrument ID Date Time Calibration Results Name Comments LEL % 02 c yo PID ppm ppm ppm ppm LEL % 02 PID ppm ppm ppm ppm LEL % 02 % PID ppm ppm ppm ppm LEL % 02 % PID ppm ppm ppm ppm LEL % 02 % PID ppm ppm ppm ppm LEL % 02 % PID ppm ppm ppm ppm LEL % 02 PID ppm ppm ppm ppm 9 MARATHON OIL COMPANY/CONTRACTOR EMPLOYEES URINE PHENOL RESULTS Incident Name: Location: Collection Date /Time Accession Number* Results (mg/I) OSHA Limit — End of Shift Determination 75 mg/L *Accession numbers are provided to maintain medical confidentiality. This is the unique number of an individual's laboratory report. 10 PERSONAL EXPOSURE MONITORING RESULTS Incident Name: Location: Date Employee Name Component/Contractor ID No. Sample Duration (Minutes) Monitoring Results (ppm) Exposure Limits (ppm) 11 PHOTOGRAPH LOG Incident Name: Location: Photographer(s): Date: Time: Sequence or ID# of this photograph: Location of the subject within the area: General compass direction of the orientation of this photograph: General description of this subject: Sequence or ID# of this photograph: Location of the subject within the area: General compass direction of the orientation of this photograph: General description of this subject: Sequence or ID# of this photograph: Location of the subject within the area: General compass direction of the orientation of this photograph: General description of this subject: 12 RESIDENTIAL MONITORING FORM Incident Name: Location: Date: Time: Occupant Name: Address: Survey Team: MPC/Contractor Representative: MPC/Contractor Representative: Diagram Floor Location Measurement Location VOC Conc. (ppm)' Benzene Conc. (ppm)' First Floor Second Floor Basement 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11 12. Note: If garage is present, note location at appropriate level and record sample point. X Measurement location on diagram Observations: Odors: Containers No Yes If yes, describe: of VOC sources: Indication Comments: of Smoking in residence: No Yes Note: Equipment S/N and Calibration information recorded on calibration forms. 13 SAMPLING PUMP CALIBRATION LOG Incident Name: Location: Equipment ID Mfg/Model Serial No. Date Time Flowrate {ml/min or Ipm} Method of Calibration Sampling Media Calibration by 14 Marathon Oil` Piceance Operations Emergency Response Plan Appendix D: Diagrams Appendix D: Diagrams Piceance Basin, CO March 2013 © The Response Group List ofi• r=.1'` a • s for Piceance Basin, CO V Piceance Basin — Overview Map ✓ Piceance Basin — Detailed Overview Map 1 ✓ Piceance Basin — Stormwater Management Vicinity Map 1 ✓ Piceance Basin — Pipeline Map ✓ Piceance Basin — Well Pad and Tower Locations ✓ Piceance Basin — Marathon Leasehold with Surface Ownership ✓ Piceance Basin — Facilities with American Peregrine Falcon Activity ✓ Piceance Basin — Facilities with Sage Grouse, Eagle and Raptor Activity ✓ Piceance Basin — Greater Sage -grouse Lek Sites March 2013 © The Response Group Marathon Oil` Piceance Operations Emergency Response Plan Appendix E: Waterline Maps Appendix E: Waterline Maps March 2013 © The Response Group V Piceance Overall Waterline Map 1 1 ✓ Piceance Northern Waterline Map 1 1 ✓ Piceance Southern Waterline Map 1 1 ✓ Piceance Eastern Waterline Map 1 ✓ Piceance Western Waterline Map ✓ Piceance Central Waterline Map ✓ Piceance Waterline and Valve Can Location Map ✓ Piceance Waterline and Cathodic Test Station Location Map ✓ Piceance Waterline and Coupler Location Map March 2013 © The Response Group Marathon Oil` indY Piceance Operations Emergency Response Plan Appendix F: Oil SpiII Waste Management & Disposal Plan Appendix F: Oil SpiII Waste Management & Disposal Plan TABLE OF CONTENTS 1.0 PURPOSE AND SCOPE OF WASTE MANAGEMENT AND DISPOSAL PLAN 1.1 Typical Reclaimable Materials and Waste Streams 1.2 General Waste Management Practices 1.3 Waste Handlers 2.0 WASTE DESIGNATION 2.1 Waste Characterization 2.2 Waste Sampling Procedures 2.3 Sampling Guidelines 2.4 General Management Guidelines 2.5 Accumulation of Hazardous Waste 2.6 Management of RCRA-Regulated Waste 3.0 INTERIM STORAGE, SEGREGATION AND TRACKING 3.1 Locations for Temporary Waste Storage Areas 3.2 Waste Storage Area Construction Materials and Supplies 3.3 Waste Segregation, Containerization and Inventory 3.3.1 Contaminated Soil 3.3.2 Oiled Debris 3.3.3 Contaminated Sorbent Material and PPE 3.3.4 Contaminated Rinsate Water from Decontamination Stations 3.3.5 Hazardous Waste 3.3.6 Non -Oiled Waste Generated from SpiII Response Activities 3.3.7 Sewage/Sanitary Waste from SpiII Response Activities 3.4 Tracking of Waste Types and Amounts 3.5 Agency Approval of Temporary Waste Storage Areas 4.0 WASTE DISPOSITION AND FINAL DISPOSAL 4.1 Available Disposal Options 4.1.1 Incineration 4.1.2 Land filling 4.1.3 Bioremediation and Off -Site Biodegradation 4.2 Final Report March 2013 © The Response Group Page 1 in.)! Marathon Oil` Piceance Operations Emergency Response Pla Appendix F: Oil SpiII Waste Management & Disposal Plan LIST OF ATTACHMENTS Attachment A Attachment B Attachment C Attachment D Attachment E Attachment F LIST OF TABLES Table 1 Table 2 Staging Area(s) LIST OF FIGURES Figure 1 Figure 2 Figure 3 NOTE: Approved Oil Reclamation Contractors and Disposal Facilities Oil Spill Waste Management Disposal Plan Form Hazardous Waste Manifest Land Disposal Restriction Notification Daily Survey Waste Tabulation Form Field Survey Waste Removal/Transfer Form Hazardous Waste Accumulation Area Inspection Form Summary of Construction Materials and Equipment for Temporary Waste Waste Staging Area Schematic Waste Staging Area Site Location Map Incident Status Summary - ICS Form 209 Associated materials not included herein: Supplemental SpiII Response Documents March 2013 © The Response Group Page 1 in.)! Marathon Oil` Appendix F: Piceance Operations Oil SpiII Waste mergency Response Plan Management & Disposal Plan OIL SPILL WASTE MANAGEMENT AND DISPOSAL PLAN Incident Name: Responsible Party: Spilled Material: SpiII Volume (estimate): SpiII Location: SpiII Date / Time: Report Update Time: Disposal Plan Authorization This plan is written at the request of the FOSC or SOSC. The responsible party will recover the maximum feasible amount of oil spilled during the above named incident. In addition an unknown quantity of oily waste debris (including plastics, sands, etc.) will be recovered. When disposing of this material, the responsible party will abide by all applicable state, local and federal laws and regulations. Disposed material will be tracked to provide an accurate means of estimating total oil recovered. This plan may be amended as necessary to ensure compliance with all applicable laws and regulations. Amendment may occur only upon mutual agreement of the responsible party, the Federal OSC (USCG/EPA), and/or the State OSC. Submitted By: Waste Management Specialist Approved By: Environmental Unit Leader March 2013 © The Response Group Page 1 Ve.J1 Marathon Oil` Piceance Operations mergency Response Plan Appendix F: Oil SpiII Waste Management & Disposal Plan 1.0 PURPOSE AND SCOPE OF WASTE MANAGEMENT AND DISPOSAL PLAN This is an incident -specific plan to address management of oily wastewater and solid waste materials during the emergency phase of a marine or other oil spill response. Wastes generated during a spill response effort are collected, containerized, and managed by the Operations Section. The Environmental Unit in the Planning Section provides guidance on waste management and makes waste disposal decisions. The Incident Management Team roster and ICS organization chart should be used to identify roles and responsibilities. The goal of the spill response effort is to remove oil from impacted areas as soon as possible and to treat, recycle, or dispose of recovered oily material in the most efficient and environmentally sound manner. This plan provides guidance on how to manage the waste generated during an oil spill response effort and forms to document actions taken. A final report or incident action plan (IAP) should be developed at the conclusion of response activities detailing what waste was generated, and how it was disposed of/and or treated. The information generated during the spill response effort should provide this information. 1.1 Typical Reclaimable Materials and Waste Streams SpiII respillir cleanup, and decont. lowin • wastes and reclaimable material ✓ Recovered oil (crude or refined petroleum product) from the release / Oily residue from vessels, debris, and other oiled material ✓ Oily water (oil and seawater or oil and fresh water), including decontamination and wash water ✓ Oil -saturated booms and sorbents from clean-up of the spilled oil ✓ Other debris, including oil contaminated sand, vegetation, and soil that may become waste 1.2 General Waste Management Practices The following management practices must be followed in the management of .stes generated in a spill response effort: Dispose or manage wastes and recoverable materials in permitted or otherwise ✓ authorized locations and facilities only. Unauthorized disposal or management will not be tolerated. Reduce waste generation whenever practical. This is known as waste minimization or pollution prevention. Reuse or recycle materials whenever practical. This not only lowers consumption of raw materials; it also eliminates the need for waste disposal. Recycling and reuse of recovered oil and oily water is the preferred option. Avoid co -mingling wastes of different classifications. For example, never place non- hazardous wastes in the same container as hazardous waste. In addition, keep recyclable material separate from non -recyclable waste. It may be difficult or impossible to separate wastes after they are generated. © The Response Group Ve.J1 Marathon Oil` Piceance Operations mergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan 1.2 General Waste Management Practices (Cont'd) e wastes following management practices must be follow a management generated in a spill response effort: ✓ Maintain good housekeeping practices. Employees and contractors should maintain neat, clean work areas to reduce the need for additional clean up and the wastes it would generate. ✓ Properly store wastes, especially hazardous wastes, to avoid releases to soil, water, or air, until they can be appropriately managed. ✓ Clearly identify waste containers. Use a label or other means to clearly identify the contents of containers of hazardous, non -hazardous and inert wastes. ✓ Document quantities and disposition of all hazardous and non -hazardous wastes as instructed in this plan. Waste tracking can help to manage costs, and is required for all hazardous wastes. This information will be included in the final report developed at the conclusion of response activities. ✓ Recovered liquids (oil, water, sludge) should be collected and stored in as large a container as possible (Department of Transportation [DOT] drum, tote tank, frac tank, or barge) to maximize decanting potential, facilitate uninterrupted recovery, and to minimize equipment decontamination requirements. ✓ Communicate your ideas for waste minimization or waste management improvements to supervisors and fellow employees in different areas. 1.3 Waste Handlers Liquid materials recovered will be collected for proper disposal or recycling by one of the approved contractors listed in Appendix A of this plan. March 2013 © The Response Group Page 3 Ve.J1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan 2.0 WASTE DESIGNATION The process of classifying waste as solid or hazardous waste is termed "waste designation." Petroleum products such as diesel generally do not designate as hazardous waste. Recovered oily liquids and other materials contaminated by oil that are not designated as hazardous waste may be recycled, burned, or blended for fuel without following the requirements for management of hazardous waste. Recovered oily liquids and other materials contaminated by oil that cannot be recycled, burned or blended for fuel are considered solid waste and subject to designation as a hazardous waste as determined through testing. If they do not designate as a hazardous waste they are classified and managed as a solid waste. 2.1 Waste Characterization Wastes that can typically be identified as non -hazardous via operator or generator knowledge include non -oiled waste from the response activities and minimally oiled wastes such as some discarded decontaminated or personal protective equipment (PPE). Knowledge of the material spilled, (e.g., marine diesel fuel) can be used to classify all of the released material. Marine diesel fuel -impacted material would be classified as 100 percent non -hazardous. Some oiled waste material may be tested to determine if the waste is a federal or state hazardous waste. If the waste is designated as not hazardous, testing will identify if the waste concentration is low enough in total oil and grease or total organic carbon to be accepted in the local landfill or Resource Conservation and Recovery Act (RCRA) Class III disposal facility. Spent oiled boom and sorbent material as well as contaminated soil, sand or other loose, natural material would be composite sampled as means to classify the material. All oily waste streams will be characterized to ensure the wastes are managed in accordance with federal and state hazardous waste regulations. The testing results will determine the final disposition and disposal of the waste. A minimum of 10 percent of a waste stream (e.g. oily waste bags) will be tested if operator knowledge indicates hazardous waste may be present. Sample analyses will include toxicity characteristic (benzene only), reactivity, ignitability; and other analyses, as necessary. 2.2 Waste Sampling Procedures Samples will be collected in pre -cleaned glass containers and stored and transported in specially designated portable coolers. These supplies will be provided by accredited analytical laboratory. See list of approved laboratories in Appendix A of this plan. Containers will be labeled with date and time, sample type, sample location (waste storage area number), unique sample number, and the samplers' signature. The contract analytical laboratory will provide labels. Samples will be collected with the assistance of a clean scooping device such as a hand trowel (either a one-time disposable or a device that can be decontaminated between each sample). Reusable sampling equipment will be decontaminated with isopropyl alcohol and water between collection of each sample. Nitrile gloves will be worn during the collection of each individual sample and changed between samples. The samples will be stored in the field in chilled coolers (4° C). The samples then will be moved to a refrigerator or delivered to an analytical laboratory within the sample holding time specified for the analytical methods selected. Proper chain of custody protocol will be followed. © The Response Group Ve.J1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan 2.3 Sampling Guidelines For oil sam • lin • exercises, the followin • • uidelines will be use •;' the ✓ ✓ Third party contractors will be used to collect all neat and contaminated material samples. V Third party contractors will be used to gauge all tanks containing oil -water mixtures. ✓ Samples will be collected in pre -cleaned glass containers provided by an accredited analytical laboratory. ✓ Containers will be labeled with information such as the date, sample type, and sample location. ✓ Solid material type samples (e.g., PPE) will be collected with the assistance of a utility knife or scissors. ✓ Liquid type samples will be collected with the assistance of an appropriate liquid sampling device. ✓ Sampling equipment will be decontaminated with isopropyl alcohol and water and thoroughly rinsed between each sample collected. ✓ Nitrile gloves will be used for sample collection, and changed between samples to prevent cross contamination. ✓ All spent sampling equipment and contaminated material associated with sampling will be consolidated, containerized and moved to the waste staging area. V Proper chain of custody protocol will always be followed. 2.4 General Management Guidelines d e • • o spill res • onse efforts should be mana • ed the ✓ following guidelines: Solid waste will be placed in a lined/bermed area for subsequent off-site transport, treatment and disposal. ✓ Temporary storage of oil -contaminated materials will be in closed -top, 55 -gallon drums, sealed plastic bags or roll -off boxes, all segregated within the lined/bermed containment areas. ✓ Wastes accumulated in temporary storage locations will be categorized, segregated, inventoried and transported off-site for recycling or disposal. V Ultimate disposal of recovered materials will be determined, in part, by the cleanup criteria established by the regulatory agency with jurisdiction over the event. The Company's responsible person (RP) and the unified command (U.C.) will determine the most feasible disposal alternative for recovered materials that meets federal, state, and local requirements. ✓ Testing of accumulated materials will be performed in accordance with appropriate regulatory guidelines. ✓ Necessary permits will be obtained for transportation to and disposal of any wastes at approved landfills. March 2013 © The Response Group 11 \14.11 Marathon Oil` Piceance Operations Emergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 2.5 Accumulation of Hazardous Waste No permits are needed for collection and temporary storage of hazardous waste in an emergency oil spill clean-up as long as waste is properly contained, labeled, and stored. Storage requirements for hazardous waste are more stringent than for non -hazardous waste. A hazardous waste storage area inspection form, provided as Table 1, should be used to document that waste was appropriately managed. Generators of hazardous waste must obtain a state/Environmental Protection Agency (EPA) identification number since hazardous waste may not be shipped off- site without an identification number. Use the Oil Spill Waste Management Disposal Plan Form in Attachment B to summarize the event and site-specific implementation of this waste management and disposal plan. Hazardous waste manifest requirements will be fulfilled to transport the waste off site. Examples of Hazardous Waste Manifest and Land Disposal Restriction Notification Forms are provided in Attachments C and D, respectively. Originals of these forms must be completed and accompany waste transported off-site for disposal. Forms from Attachments B, C, and D and portions or portions of this plan may be submitted as part of the IAP for this response activity. Materials safety data sheet (MSDS) information should be included in the IAP with the Waste Management Disposal Plan to facilitate residuals management decision-making by the U.C. 2.6 Management of RCRA-Regulated Waste Many hydrocarbon products contain benzene, which can be considered a hazardous waste under the RCRA toxicity characteristic rule. As a result, oily waste (excluding marine diesel fuel - contaminated wastes) that cannot be recycled or reclaimed will be analyzed for hazardous characteristics before choosing a treatment or disposal option. The Company will use standard procedures approved by RCRA regulations for sampling, analyzing, and monitoring oil and oily waste material. Representative samples will be collected and analyzed for hazardous characteristics (ignitability, corrosivity, reactivity, or toxicity) by the Toxicity Characteristic Leaching Procedure (TCLP) to determine if the waste should be handled as hazardous. If oily waste is determined to be hazardous under RCRA, the wastes will be sent to an EPA- or state -permitted hazardous waste management facility for treatment and disposal. If the material spilled is itself a RCRA-listed hazardous waste, any resulting spill residue is automatically a RCRA-listed hazardous waste. Use the Oil Spill Waste Management Disposal Plan Forms contained in Attachment B to summarize the event and site-specific implementation of this Oil Spill Waste Management and Disposal Plan. Forms from Attachment B, and portions or this entire plan, should be submitted as part of the IAP for this response activity. MSDS information should be included in the IAP with the Waste Management Disposal Plan to facilitate residuals management decision-making by the U.C. March 2013 © The Response Group 11 \14.11 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan 3.0 INTERIM STORAGE, SEGREGATION, AND TRACKING This section provides information on the interim storage of spill -generated waste, includes guidance on the segregation of different types of waste to facilitate proper and efficient management, and provides waste disposition tracking forms. 3.1 Locations for Temporary Waste Storage Areas Temporary waste staging areas (Waste Staging Areas) will be established in the following locations. A. Waste Staging Area Location Number 1: B. Waste Staging Area Location Number 2: C. Waste Staging Area Location Number 3: It is important to show how each site will be constructed, bermed, or covered to minimize rainwater infiltration and leaching. Maps should be provided to locate the Waste Staging Areas for the IAP. Describe below the measures that will be taken following completion of spill response activities to return the waste staging areas to their original condition. Include in the discussion, at a minimum, efforts to: classify and containerize materials used to construct the temporary storage areas; decontaminate the location; and collect and dispose of wash down/rinsate that may evolve during temporary waste staging area decommissioning. 3.2 Waste Storage Area Construction Materials and Supplies edec, for constructing a Waste Stagin •j ✓ Reinforced visqueen or rolled polyethylene liner ✓ Railroad ties, hay bales, or other berm material for under visqueen ✓ Roll -off boxes and/or dumpsters (empty containers used to accumulate waste collected in satellite accumulation areas) ✓ Yellow caution or "Do Not Enter" tape ✓ Temporary fencing and/or barricades, if needed / Traffic cones ✓ Absorbent materials and pads ✓ Wooden pallets for drum storage ✓ Drums ✓ Plastic bags (55 -gallon drum size) ✓ Decontamination equipment (potable water, soap, brushes, tubs, etc.) in portable totes ✓ PPE A tally of construction material and supplies needed for this event is presented in Table 2. A schematic diagram of the Waste Staging Area(s) is presented in Figure 1. A site map that presents Waste Staging Area locations appears as Figure 2. Hazardous Waste Operations and Emergency Response (HAZWOPER) requirements for personnel entering the waste staging area are summarized in the Site Safety Plan contained in the IAP. © The Response Group 11 \14.11 Marathon Oil` Piceance Operations mergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 3.3 Waste Segregation, Containerization and Inventory All loads moving into the temporary Waste Staging Area should be weighed prior to off-loading the waste. Oiled sand/soil should be placed into visqueen-lined dump trucks or roll -off boxes and transported off-site or to the non -liquid waste storage section in the temporary Waste Staging Area. All loads of oily sand and soil must be weighed and documented. The on-site weighing location for waste management during this spill response is described below. Label all containers (bags, drums, roll -off boxes, totes, dumpsters, etc.) with th followin • information: ✓ Type of material (oiled boom, absorbent pads, etc.) ✓ Location (waste generation site) ✓ Date ✓ Name and phone number of contact person ✓ Include the term "Recovered Oil- (put type of material here, such as sand, PPE, debris) Contaminated Material." Oily wastes will be placed in leak -proof containers to prevent leakage during handling and transportation. The containers may be 55 -gallon drums, portable tanks, tank trucks, roll -off boxes, dumpsters, storage barges, or containers that can be sealed and covered to prevent spillage. Double -walled plastic bags may be used for this purpose or all oil -contaminated materials can be double -bagged and tied or closed with duct tape. Not more than 20 pounds of debris are to be placed in each double bag. Each container of collected debris will be labeled as to its contents (tar balls, oily debris, or non -oily rubbish). Similar waste types should be staged together as a key task in the spill response waste segregation strategy. All equipment used to excavate the sand or soil must be decontaminated and the wash waters managed per the procedures provided in the Decontamination Plan included in the IAP. The management of recovered oil and oil/water mixtures will be addressed in the Recovered Oil and Water Management Plan. This section includes the segregation and management of contaminated soil, oiled debris, oiled sorbent material and PPE, rinsate water from decontamination stations, hazardous waste, non -oiled waste and sewage/sanitary waste generated from spill response activities. Where possible, waste should be segregated according to media and degree of toxicity, as described below. March 2013 © The Response Group 11 \14.11 Marathon Oil` Piceance Operations Emergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 3.3.1 Contaminated Soil Contaminated soil and shell material can be stockpiled in designated lay -down areas near cleanup activities. Paved areas or areas prepared for stockpiling impacted materials are preferred. Stockpile areas underlain with visqueen and covered with visqueen or other sheeting may be required to prevent rainfall infiltration and runoff. Stockpiling of contaminated soils should be viewed as a temporary measure, as the soil will eventually be containerized for off- site treatment and/or disposal. Soil will be characterized and stored as per direction from the Environmental Unit. 3.3.2 Oiled Organic Debris Oiled organic debris includes wood, grasses, aquatic vegetation, and similar organic matter that cannot be treated and restored. Oiled organic debris should be segregated from dissimilar debris and containerized in clear plastic bags so the contents inside can be viewed. This material typically is designated for disposal at an approved solid waste landfill. 3.3.3 Oiled Debris Oiled debris includes equipment and materials that are not deemed to be treatable or material that cannot be returned to its original service. This may include oiled wooden material from beaches, oiled nets and floats; buoys, oiled trash collected from the beach, and oiled equipment. Oiled debris will be containerized in 55 -gallon drums or roll -off boxes and/or dumpsters. This material typically is designated for disposal at an approved solid waste landfill. See Attachment A or disposal facilities intended for use during the response. 3.3.4 Contaminated Sorbent Material and PPE Contaminated sorbents (absorbent booms, pads, wipes, etc.) will be transferred from decontamination areas to the nearest waste staging area. Oiled sorbents and PPE will be containerized in plastic bags, drums, roll -off boxes, or dumpsters as appropriate. Plastic bags, taped closed and stored in roll -off boxes is the preferred technique. 3.3.5 Contaminated Rinsate Water from Decontamination Stations Contaminated rinsate from personnel or equipment decontamination areas will be containerized in open top 55 -gallon drums fitted with bung -sealing lids. Contaminated rinse water and other oily water generated during the spill response typically will be transported by vacuum truck from points of generation to frac tanks and portable oily water storage tanks supplied by the oil spill response organization or oily water reclamation contractor. The frac or Baker tanks typically will be co - located with the Waste Staging Areas. See Figure 2 for site-specific frac/Baker tank locations. March 2013 © The Response Group 11 \14.11 Marathon Oil` Piceance Operations Emergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 3.3.6 Hazardous Waste Hazardous waste will be kept in designated areas within the temporary waste staging areas. Hazardous waste will typically be containerized in drums or visqueen-lined roll -off boxes with volatile organic compound (VOC) controls, if necessary. Hazardous waste will not be co- mingled with non -hazardous waste. An example of a hazardous waste manifest, needed for transportation and disposal of any hazardous waste, is provided in Attachment C. Attachment D contains an example Land Disposal Restriction Notification that must be filled out and accompany the waste and waste manifest. 3.3.7 Non -Oiled Waste Generated from Spill Response Activities Non -oiled waste material includes trash generated at the on-site oil spill response center(s), trash generated from response boats, and packing material that cannot be recycled. Non -oiled waste may be kept in plastic bags at the Waste Staging Area, but must be clearly identified as non- hazardous garbage (e.g., using color -coded plastic bags or color -coded bag tags). 3.3.8 Sewage/Sanitary Waste from Spill Response Activities Oil spill cleanup operations produce large amounts of liquid sewage wastes that originate from domestic sources such as toilets, laundry and shower facilities, cooking, and gathering centers. This waste must be characterized by type and disposed of properly. 3.4 Tracking of Waste Types and Amounts Daily Survey Waste Tabulation and Field Survey Waste Removal/Transfer Forms are provided in Attachments E and F to document the amount of waste generated during the spill response effort. Continually reporting and updating the Situation Unit with waste management data is a crucial aspect of response. Waste management data are used to assess the progress of the response and to determine potential response needs. Typically waste management data will be summarized on ICS Form 209 (Figure 3), which includes total volumes recovered, stored, and disposed. The Environmental Unit in conjunction with the Situation Unit must assure that this information is accurately reported. Clear lines of communication must be quickly established with Operations to assure that an adequate tracking system is in place. Waste disposal plans should describe the waste tracking system. The use of waste disposition tracking forms is highly recommended. 3.5 Agency Approval of Temporary Waste Storage Areas Agencies such as the State Department of Environmental Protection request consultation and approval to maintain a Temporary Waste Storage Area (TWSA). The following information will be provided to IC/UC and gain approval for the TWSA operation continuance: Location of TWSA Materials managed Summary of TWSA oversight Rationales for continuing operation Anticipated duration Approval signature of FOSC or SOSC 0 The Response Group Page 10 Ve.J1 Marathon Oil` Piceance Operations mergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 4.0 WASTE DISPOSITION AND FINAL DISPOSAL The waste management data for this spill response effort should be summarized on ICS Form 209 (Figure 3). This form includes total volumes recovered, stored, and disposed of. Other waste disposition forms provided in this document can also be used to complement ICS Form 209. Following the collection of information needed to estimate the quantity of recovered oil, absorbent materials affected by the released oil and other oily waste debris such as oily solids, oil -stained rock and soil/sand mixtures, tar balls, and other miscellaneous combustible wastes, it must first be determined that all proper tracking forms have been completed. Once tracking of waste generated has been confirmed, waste may be disposed of through on or more of the following methods: (1) incineration, (2) land filling, and (3) off-site bioremediation. Copies of receipts from disposal facilities must be kept with the completed ICS Form 209. 4.1 Available Disposal Options Information for each of these disposal methods, including possible permitting requirements, is provided below. 4.1.1 Incineration Incineration can be used to dispose of oily waste materials (including oily wood, oiled debris, PPE, sorbents, and other organic material) collected during cleanup operations) if a facility is within a logistically feasible transportation distance. Permitting, transportation and facility availability issues should be addressed and approved by the Incident Command. The debris will be transported from the interim storage site by to Transporter(s) Facility 4.1.2 Land filling Land filling of waste materials produced as part of a spill response will occur only at a commercial facility permitted for the disposal of hazardous and non -hazardous solid waste. Coordination with the landfill is required to 1) verify that appropriate waste characterization analyses have been completed, 2) verify that the landfill is permitted to receive the waste, and 3) identify the labeling, transportation, and manifesting requirements for the landfill to receive the waste. The following transporters will transport waste suitable for land farming to the identified facilities. Transporter(s) Facility March 2013 © The Response Group Page 11 11 \14.11 Marathon Oil` Piceance Operations mergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan 4.1.3 Bioremediation and Off -Site Biodegradation Bioremediation involves adding nutrients (nitrogen and phosphorous) to enhance indigenous microbial activity to degrade the hydrocarbon -impacted material. Successful bioremediation can accelerate the cleanup of a spill and reduce the amount of oily wastes requiring disposal. Bioremediation can be conducted either in-situ (where the spill occurred) or ex situ (remove the contaminated material and place into a biotreatment area designed and built for that purpose). This technique is limited to impacted soils and sediments. Ex -situ land farming is a preferred method of oily waste management. In land farming, oily sludges are spread on a selected site and then combined with soil, moisture and nutrients in the presence of oxygen to promote bacterial degradation of the hydrocarbon components. Smaller items, such as sand, pebbles, short seaweed (less than 6" long) sludges, and contaminated soils can also be processed this way. This method requires approval by the SOSC and/or FOSC, a permit, and monitoring. Often the treated soils can be placed back into the area from which they were excavated. 4.2 Final Report A final report must be developed at the conclusion of response activities. The final report should state in detail the types of waste generated as well as the amount of each waste type generated, disposed of, or treated. Other forms used here can be attached to supplement this information. March 2013 © The Response Group Page 12 11101 Marathon Oil` Appendix F: Piceance Operations Oil Spill Waste Emergency Response Plan Management & Disposal Plan ATTACHMENT A: Approved Oil Reclamation Contractors See Appendix A of this plan. APPROVED DISPOSAL FACILITIES See Appendix A of this plan. March 2013 © The Response Group Page 13 11101 Marathon Oil` A Appendix F: Piceance Operations Oil SpiII Waste ;r Emergency Response Plan Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM Page 1 of 10 Incident Name: Date Prepared: Time Prepared: Location(s)/Division(s) Covered By Plan: ACP/Other References Consulted: GENERAL INFORMATION Source of SpiII: Total Amount Spilled: Total Amount At Risk: Type of Material Spilled: AGENCY INFORMATION Lead Agency: Agency Representative(s): Telephone(s): Comments: March 2013 © The Response Group Page 14 li Nur Marathon Oil` Appendix F: Piceance Operations Oil Spill Waste Emergency Response Plan Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 2 of 10 VARIANCES Inquiry Made to Obtain Variances on: Individual(s) Contacted for Variances: Telephones(s): Comments: SAMPLES Media(s)/Date(s) Sampled: Sample(s) Sent Via: Laboratory Name(s): Sampling/Analysis Plan(s) Attached? Chain of Custody Form(s) Attached? Comments: Yes Yes No No March 2013 © The Response Group Page 15 Ii''t►./1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 3 of 10 SOLIDS TYPE Oiled Natural Inorganic (Sand, pebbles, etc.) Oiled Natural Organic (Driftwood, seaweed, etc.) Man -Made Materials (PPE, sorbents, etc.) Unoiled Solids Other(s) Description(s) Estimated Volume(s) Suspected Hazardous Waste? Determination By Generator Knowledge? Hazardous Waste Code: Comments: Yes No Yes 1 I No March 2013 © The Response Group Page 16 li Nur Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 4 of 10 March 2013 © The Response Group Page 17 IQUIDS (Descri •tion) i STIMATED VOL(s) Oil/Water Mixtures Uncontaminated Petroleum Products Waste Water Spent Solvents / Fuels Other(s) March 2013 © The Response Group Page 17 li Nur Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 5 of 10 Suspected Hazardous Waste? 1 Determination By Generator Knowledge? Hazardous Waste Code(s): 1 Yes Yes Rlo No Comments: TEMPORARY WASTE STORAGE Estimated Storage Required (roll -offs, tanks, etc.): Storage Type Estimated Capacity/Number Required March 2013 © The Response Group Page 18 li Nur Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 6 of 10 Preferred Location(s): Permit(s) Required For Temporary Storage: Ground/Runoff Protection Required For Storage Area? Liners/Cover Protection Required For Storage? Comments: Yes Yes No No March 2013 © The Response Group Page 19 li Nur Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 7 of 10 ATTACHMENT B: WASTE TRANSPORTATION Proposed Transportation Method (s): Waste Type/Description Permit(s)/license(s) required for transportation: Proposed Transport Method Liners/cover protection required for transportation? Comments: Yes I No March 2013 © The Response Group Page 20 ifVe. ) Marathon Oil` Appendix F: Piceance Operations Oil Spill Waste mergency Response Plan Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 8 of 10 DISPOSAL METHOD(S) Meth"= Waste Type / Description j vailable / Selected Natural Degradation / Dispersion Wastewater Treatment Plan Landfill Land Farms In Situ Burning Open Pit Burning Portable Incineration Process Incineration Reprocessing Recycling Well Injection Other Comments: li Nur Marathon Oil` Piceance Operations mergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 9 of 10 DISPOSAL RESOURCE (S) Proposed resources(s) for disposal method(s) selected (landfill operators, incinerator facilities, etc.): Disposal Method Permit(s) required for disposal: Comments: Resource (s) March 2013 © The Response Group Page 22 HEALTH AND SAFETY PROCEDURES li Nur Marathon Oil` Appendix F: Piceance Operations Oil Spill Waste Emergency Response Plan Management & Disposal Plan OIL SPILL WASTE MANAGEMENT DISPOSAL PLAN FORM (Cont'd) Page 10 of 10 Health/Safety Plan Attached? Yes Comments: No ADDITIONAL COMMENTS CONTACTS AND APPROVALS Contact For Further Information: Approved By: Time/Date: March 2013 © The Response Group Page 23 1i' C9 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan HAZARDOUS WASTE MANIFEST Insert copy of Hazardous Waste Manifest March 2013 © The Response Group Page 24 1i' C9 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan LAND DISPOSAL RESTRICTION NOTIFICATION Insert Restrictions if any: March 2013 © The Response Group Page 25 1i'r�11 Marathon Oil` Piceance Operations Emergency Response Plan =.4 Appendix F: Oil Spill Waste Management & Disposal Pian DAILY SURVEY WASTE TABULATION FORM A detailed survey of the wastes will be undertaken to identify appropriate management options. The following list summarizes the type of data to be collected: What is it? • Origin or source of the waste: Where is it and how much is there? • Location(s): • Number of people working and hours worked: Container No. Contents Capacity/Mass Sample s Drums Red/Orange Oily Bags Blue, Regular Trash Bags Clear Bags for Oiled Dumpsters March 2013 © The Response Group Page 26 Ii' te./1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan ATTACHMENT F FIELD SURVEY WASTE REMOVAL TRANSFER FORM What is it? • Origin or source of the waste: • Type of waste: Where is it and how much is there? • Location (s): • Volume of weight that must be managed: • Means of containerization (e.g., in drums, barges, bags): • Drums: • Roll -off: • Dumpsters: • Bags: 5 March 2013 © The Response Group Page 27 in.)! Marathon Oil` Piceance Operations Emergency Response Plan F Appendix F: Oil SpiII Waste Management & Disposal Plan HAZARDOUS WASTE ACCUMULATION AREA INSPECTION FORM Inspector's Name: Inspection Location Inspector's Title Inspection Date / Time: Item Area -Specific Information Acceptable Not Acceptable Recommendation Container Placement Access, drums on concrete, aisle spacing Container Condition Drum condition, bungs in place, liquid residue Container Labeling Proper labels and accumulation date Incompatible Waste Acids vs. bases, oxidizers, flammables Area Security Limited access Fire Extinguisher Accessible, charged, inspected SpiII Control Equipment Absorbent, shovel, etc. Shower/Eye Wash Functioning properly, regular inspections Warning Signs No smoking, hazardous waste area, etc. PPE & Other Equipment Gloves, goggles, level of PPE Signature: Comments: March 2013 © The Response Group Page 28 Ii' te./1 Marathon Oil` Piceance Operations Emergency Response Pla Appendix F: Oil Spill Waste Management & Disposal Plan TABLE 2 SUMMARY OF CONSTRUCTION MATERIALS AND EQUIPMENT FOR TEMPORARY WASTE STAGING AREA(S) Visqueen (square feet) Railroad Ties or Bails (feet) Roll -Off Boxes or Dumpsters (#) Caution Tape (feet) Temporary Fencing / Barricades (feet) Traffic Cones (#) Absorbent Pads (#) Total March 2013 © The Response Group Page 29 11101 Marathon Oil` A Appendix F: Piceance Operations Oil Spill Waste mergency Response Plan Management & Disposal Plan Table 3 — Environmental Unit Summary SENSITIVE SITES/RESPONSE ACTIONS Priority Site ID Site Description Assignment Action Status Status Board I Date: Time: I Page of March 2013 © The Response Group Page 30 11101 Marathon Oil` Piceance Operations Emergency Response Plan Appendix F: Oil Spill Waste Management & Disposal Plan Figure 1 Waste Staging Area Schematic Insert Information on Site Layout Figure 2. Waste Staging Area Site Location Map Insert Maps of Waste Staging Locations Additional Comments or Information: March 2013 © The Response Group Page 31 Ii' te./1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix G: WCEM Appendix G: Well Control Emergency Management Well Control Emergency Management Document Below: March 2013 © The Response Group Page 1 Ii' te./1 Marathon Oil` Piceance Operations Emergency Response Plan Appendix H: Inland Spills Response Tactics Guide Appendix H: Inland Spills Response Tactics Guide See Guide Below - March 2013 © The Response Group Page 1 Marathon Oil Piceance Operations Emergency Response Plan Appendix D: Diagrams Appendix D: Diagrams Piceance Basin, CO Lis o to •ram/Ma . s for Piceance Basin, CO ✓ Piceance Basin — Overview Map V Piceance Basin — Detailed Overview Map ✓ Piceance Basin — Stormwater Management Vicinity Map V Piceance Basin — Pipeline Map V Piceance Basin — Well Pad and Tower Locations ✓ Piceance Basin — Marathon Leasehold with Surface Ownership I ✓ Piceance Basin — Facilities with American Peregrine Falcon Activity I ✓ Piceance Basin — Facilities with Sage Grouse, Eagle and Raptor Activity ✓ Piceance Basin — Greater Sage -grouse Lek Sites January 2013 © The Response Group 79201 5280 2640 CP JACK RABBIT N•1 PAD 090.29A P UJOMJTS tied , PAO 596-30C PAD BBB -TBC 2640"1-"5280 7920- •D.MPPNEI PAO 59•910 --Ipito 69•9401 PAD 686960 r CP9IYATT IPUNP STATION CIRCLE COT • - QUARRY 2$$ • N16 tale • PAO 887-10 I. WP YfR a CP VALLEY 890097-110 790697-112 PAD 697-14C PAO 897-20X PAO 897-29A PAD 688-1SA 0 01.14. I C31 PAO 697-21A —_ v�D�697-x1o_D cP 80041 CP TEMP 'PADE97-2M AU 697-260 PAD 897-n•I TONER3 ;PAD697-20C 890787.29 —PAO 79740 PAO 797-20 PAD 787.110 IPAD 797-110 PAD 797-11C TAD 70.'14A CP MULL CP TONERS EXISTING ROADS iiPfe- EXISTING 2 -TRACK ROADS PROPOSED ACCESS ROADS PROPOSED MAIN CORRIDOR PROPOSED WATER LINES PROPOSED GAS LINES A CONTROL POINTS • FOUND SECTION CORNERS . WELL LOCATIONS A0788.7A .' +�'�a l'; WILLIAM H. SMITH AND ASSOCIATES P.C. SURVEYING CONSULTANTS GREEN RIVER. WYOMING 82935 Phone: (307) 875-3638 Fax: (307) 875-3640 SURFACE OWNERSHIP MAP MARATHON OIL COMPANY 5555 SAN FELIPE HOUSTON, TX. 77056 DATE: SCALE: MIDI BY: JOB N0. 06/11/08 noted CED 26099 SHEET 1OF 1 r,11:.1,;40,41Vi7;striivAium:. rgiltr".01 a 6 '1'4 fa rg �► igttlr 0414 it 4r4r re 21e. Tv it rill:. Al 6 Project Location Legend Marathon Well Pad Location ❑ Proposed ■ Existing 0 1.25 2.5 5 Miles (IM, Marathon Oil Company Stormwater Managment Vicinity Map R.:t Buys &:Lmrxhsles, Inc. oy a 5 «q a 4 3 2 1 9 10 12 16 1�( 21 5S..97W 14 28 25 1 13 27 19 36 5 8 11 / 1\I 1 1 / • • \ • 1 S * * • • • • • • • 6 5 tr 4 3 2 7 W 11 * 5S 96W 13 020574 20101114 HBO • 020574 .n 20101114- T� la 020574 1 20101114 \>. 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HBp Savage . +r/Koe •, \•-/ Ilei IN 020575 "20101114 '`HB0 020575 20101114 HBO Savage / Prather / Koehic: 020570 20091023 °H80 , J 020575 20101114* r�H80 A 27 34 020574 20101114.44/'I HBO 020575 20701114 H80 i a 420574 /20101114 HBO 020571 20101114 yHBO CDP - Central _ Delivery Point• * * 020567 20090730 H80 5 8 •\ f7 i .• i i J t 4 f.'; 020571 a /=20101114 d i _'y H80 ad 17 / 8 rac / ft # .i I C i 4 * t v— i-_ , * 1I j / 020575 2014‘1114 1-180 / 020563 20991114 HBO i 32 33 6 7 18 8 17 9 4 * 020575 20701114 HBO 3 10 7S 97W 35 * * ** * �. t * * * \`y 25 T q 020563 20991114 1-180 021473 20170630 PD 36 22 13 2b 25 * 020571 20101114 H80 19 4 6 20 25 is 4 Cr 6 5 7 8 * 19 e } * a * * * * 31 1s 3 3 9 3 2 10 ti 6S° 96W 21 22 it 24 25 020571 20101114 HBO * * * 18 * 8 33 4 9 3 11 2 is • • • • • • a " 4 17' * * * 20 14 7S 96W 1 36 MI 23 * 1=f --I .,._1-___1 I'i--H I :t r I I , If 1 I i -r 1 y—r .f *-7- 1 Fav,. I l • • �e r r Lek #2100 New Lek Lek #283 DOW Greater Sage -grouse Lek Sites 2006 WestWater Engineering September 2006 Legend • Active Grouse Leks (2006) • Inactive Grouse Leks (2006) Marathon Oil Piceance Operations Emergency Response Plan Appendix E: Waterline Maps Appendix E: Waterline Maps List of Waterline Ma• V Piceance Overall Waterline Map / Piceance Northern Waterline Map ✓ Piceance Southern Waterline Map / Piceance Eastern Waterline Map ✓ Piceance Western Waterline Map ✓ Piceance Central Waterline Map ✓ Piceance Waterline and Valve Can Location Map ✓ Piceance Waterline and Cathodic Test Station Location Map ✓ Piceance Waterline and Coupler Location Map January 2013 © The Response Group 6000 4000 2000 1000 500 EXISTING 19C LATERAL 0 5001000 2000 4000 6000 1 cjS (19 ROPOSED AD 596- A EXISTING 20CLATERAL-- EXISTING PAD 596-20C EXISTING 1NOgRTgHTERN PIPEUNE� 1-4"POLYLINES EXISTING PAD 596-19C EXISTING 91A LATERAL EXISTING 91C LATERAL -ie., EXISTING PAD 596-29C PROPOSED PAD 596-20A et. 0 STING `-I NORTHERN PIPELINE 2-4"POLY LINE ASt 542 PROP ' rGs PAD 598-294 EXISTING PAD 596-81A 4,sR - 31-' EXISTING PAD 596.31C EXISTING a2c LATERAL a32 1 1 EXISTING PAD 596-320 EXISTING POND A EXISTING POND C EXISTING LATHAM LAYDOWN EXISTING` PAD 59633C 1 EXISTING NORTHERN PIPELINE 1- 8" STEEL UNE 1-4" POLY LINE Abs' rROPOSED ' PAD 596-33A EXISTING L AYDOWN UNE 1 -• 4" POLYL NEE PROPOSED Pra 6974A I .1 -I 6SR, ------ A. L EXISTING NORTHERN PIPEUNE 2-8"STEEL LINE -1- 4" POLY LINE 1 X34 EXISTING PAD 598340 EXISTING 35D LATERA. EXISTING — PAD697-1C O PAD 6 7-1A seiRl--- 1 1 ISTG 344D IAT 3LATERALERAL STING PAD 596-35D - PROPOSED PAD 695-A -�/ ---( I � 1 PROPOSED PROPOSED PAD 606-5A (STING 10 LATERAL EXISTING PAD 897-20 EXISTING 2C LATERAL COP EXISTING PAD 697-1X ISTING 1X LATERAL PROPOSED PAD 897 -22A -- I 97 -22A -I r ; EXISTING PAD 697-21A 4OPOSED PAD 697-220-7 - 4Ov /v CASCADE LATERAL" 2 -4" POLY LINES 01 0 PROPOSED 658 EXISTING 1 .PAD 697-11X 1 1 EExiSTING_ /1X ERAL PADoS GARDEN GU 2-4"POLYL EXISTING 12A LATERAL STING EXISTING CENTRAL PIPEUNE lk 11 -4" POLY U LINE PAD 697-12A 1 R 1 EXISTING cDSD B96 5c A GARDEN GULCH LATERAL -4" POLY LINES] I ROPOSED PAD 696-6C CH LATERAL NES PROPOSED 1¢' AD 697-14C PAD 697-110 1f Thik7 FISTING AD 697-23X EXISTING CENTRAL PIPELINE +p„1 -4" POLY LINES 1• 4. EXI CENTRASTINGL PIPELINE 1- 8" STEEL UNE i - 4" POLY LINES EXISTING _.PAD 2 -28A rROPOSED PAD 697-21 0-0 ISTING 23X LATERAL EXISTING. CENTRAL PIPELINE 1 -8" STEEL LINE 1 -4" POLY LINES cos A, PAD 697-23Dm L ..P CASCADE LATERAL 2-4"POLYUNES HAYSTACK LATERAL r =' 2-4"POLYUNES PROPOSED PAD 697-23C PROPOSED 28 PAD 697-28A 1 EXISTING PAD 697-2SC X33 1 1 2'7* ,34r PROPOSED i EXISTING CENTRAL PIPELINE 1-8" STEEL UNE 1-4" POLY LINES EXISTING PAD 697-180 EXISTING / ray LA7AL; EXISTING 18C EXTENSION UNE 1 -4" POLYLINE 1 0 Nri EXIS 140 18C EXTENSION UNE 1 -4" POLYLINE 24* PROPOSE PAD 697-264 C 264 PRO +SED PAD 697-28B� PAD 697-260 PROPOSED- (? 6997-35A tcbsikp 35i r7 PROPOSED I --I PAD 797-2A PROPOSED PAD 797-29 N, I I 2- HAYSTACKLATERAL -4""POLYOLY LINES ...iVOSED PAD 797-20 7O97—ar-1 1 I LJ PROPOSED PAD 791-110 L r N MCA 11-t Rd PROPOSED PAD 797-11 D SRO A0 HAYSTACK LATERAL 2-4"POLY UNES EXISTING IPA D 896-1 BA e 1 ^vim IEA LATERAL EXISTING 16C LATERAL EXISTING PAD 696-18C j - 4 3 1 k-\\45, 797-14 PR�OSEDA J PAD I 14 1 13 ch LEGEND O EXISTING VALVE CAN EXISTING WATER LINES ■ EXISTING PAD LOCATION EXISTING ROADS WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 560 BAST SWORD NOR'R PHONE` 307-075-3838 GRBSN RTYER. WY 307-075-3639 nw vhemlthpo. oom WATER LINE MAP AND VALVE CAN LOCATIONS ENTIRE PROJECT AREA MARATHON OIL COMPANY P.O. Box 3128 5555 San Felipe Houston, TX 77253 Houston, TX 77056 DRAWN BY: CED DATE: 03/25/2010 CHECKED 8Y: WI -ID JOB NO: 26099 SCALE NOTED SHEET 1 OF 1 REVISIONS: 1000 2000 3000 EXISTING 19C LATERAL\ EXISTING 31C LATERAL NORTHERN PROJECT AREA PROPOSED AD 5961A eX!STING 20C LATERA 410PEXISTING� PAD 598-20C EXISTING NORTHERN PIPELINE 1 - 8" STEEL LINE 1 -4" POLY LINE T 9. EXISTING PAD 596-19C EXISTIN PAD 596-31C GIA PROPOSED PAD 598.30A PROPOSED PAD 598-34C EXISTING 31A LATERAL EXISTING PAD 598-29C PROPOSED PAD 598-20A PROPOSED PAD 596-29A EXISTING NORTHERN PIPELINE 2i 4" POLY LINE EXISTING ..1"—rr PAD 596-31A PROPOSED PAD 598-32A EXISTING 32C LATERAL A,bS EXISTING PAD 596-32C EXISTING NORTHERN gggg���� EEEEPIIP��ELIN E 1-4"POLYLINEE EXISTING 3, 3 LAYDOWN LINE 2 - B" STEEL LINE 1 -4" POLY UNE EXISTING; PONDC EXISTI LATHAM LAYDOWN PkOPOSED PAD 697-2A EXISTING PAD 596-33C PROPOSED PAD 598-33A EXISTING NORTHERN PIPELINE 2 - 8" STEEL LINE 1 4" POLY LINE 24' EXISTING PAD 697-2C EXISTING 2C LATERAL EXISTING PAD 697-1C 0 CDP SEE MAP 2 EASTERN ROJECT AREA STINGI 1C LATERAL PROPXSED PAD 897-1A ROPOSED PAD 697-11A SEE MAP 3 CENTRAL PROJECT AREA EXISTING PAD 897-12A PROe''. PAD BJv -:. WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 560 EAST SECOND NORTH PROMs 307-875-3838 GREEN RIVER WY 307-875-3839 www. whemtthpc.com DRAWN BY: CED JOB NO: 26099 DATE: 03/25/10 LEGEND Q EXIS77NG VALVE CAN ■ EXISTING PAD LOCATION EXISTING WATER LINES EXIS77NG ROADS WATER LINE MAP AND VALVE LOCATIONS OF THE NORTHERN PROJECT AREA SCALE: I A = 2000' MAP PREPARED FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOUSTON, TX 77056 MAP 1 3000 2000 1V 1000 SOUTHERN PROJECT AREA ROPOSED AD 897-14C EXISTING PAD 697-23X EXISTING 7-23A 1000 20001 3000 PAD POSED7 22 I EE MAP 3 CENTRAL, PROJECT AREA WWESTTEAR 4 PROJECT AREA HAYSTACK LATERAL 2 -4" - OLY LINES PROPOSED PAD 697-23C I 4-27 PROPOSED PAD 7-26 234 - PROPOSED PAD 697-23D PROPOSED PAD 697-26C �e)s,P 26 P OPOSE- 8 2A X35 PROPOSEI PAD 797-2A PROPOSED PAD 797-2B PROPOSED PAD 797-11 B PROPOSED PAD 797-11 C lbs 24' I HAYSTACK LATERAL 2 -4" POLY LINE x'36' HAYSTACKLATERAL 2-4' POLYY LINES PROPOSED PAD 787-20 ic\ 1 s RDA 11 As I PROPOSED PAD 797-110 WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 560 EAST SECOND NORTH PROMs 307-875-3838 GREEN RIVER WY 307-875-3839 www. whemtthpc.com DRAWN BY: CED JOB NO: 26099 DATE: 03/25/10 LEGEND Q EXIS77NG VALVE CAN ■ EXISTING PAD LOCATION EXISTING WATER LINES EXIS77NG ROADS WATER LINE MAP AND VALVE LOCATIONS OF THE SOUTHERN PROJECT AREA SCALE: 1 A = 2000' MAP PREPARED FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOUSTON, TX 77056 MAP 5 1500 1000 500 LOT 4 LOT 8 LOT 9 LOT 18 -�f 500 1000 1500 SEE MAP 1 NORTHERN PROJECT A -EA LOT 2 LOT 12 LOT 13 EXISTING PAD 697-1C GARDEN GULCH LATERAL 2 - 4" POLY LINES LOT 15 LOT 1 LOT 6 PROPOSED PAD 697-1A LOT 9 LOT 16 EASTERN PROJECT AREA LOT 4 LOT 5 LOT 12 1 EXISTING PAD 596-34D LOT 3 L EXISTING 340 LATERAL lI LOT 6 lI EXISTING PAD 596-35D EXISTING 35D LATERAL LOT 1 LOT PROPOSED PAD LOT 8 LOT 5 LOT 10 LOT 11 LOT 9 EXISTING 1X LATERAL LOT 13 EXISTING PAD 697-1X SEE MAP 2 CENTRAL PROJECT AREA EXISTING 12A LATERAL EXISTING PAD 697-12A PROPOSED PAD 696-8C LOT 14 LOT 15 GARDEN GULCH LATERAL 2-4" POLY LINES LOT18 LOT 18 N N LOT 12 LOT 21 LOT 23 LOT 3 PROPOSED LOT 2 LOT 6 LOT 7 LOT 11 EXISTING PAD 696 -5C - LOT 14 LOT 19 LOT 10 LOT 15 LOT 18 DRAWN BY: CED WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 550 EAST SECOND NORTH PHONE: 307-875-3638 GREEN RIVER, WY 307-875-3639 www. whsmiihpc. com JOB NO: 26099 DATE: 03/25/70 LEGEND Q EXISTING VALVE CAN ■ EXISTING PAD LOCATION EXISTING WATER LINES EXISTING ROADS WATER LINE MAP AND VALVE LOCATIONS OF THE EASTERN PROJECT AREA SCALE: 7" = 70DD' MAP PREPARED FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOUSTON, TX 77056 MAP 2 1500 1000 500 500 1000 1500 WESTERN PROJECT AREA EXISTING PAD 697-21A 2 PROPOSED -PAD 697-22C PROPOSE PAD 697-22A I ti bS EXISTING PROPOSED _Y PAD 697-23X PAD 697-14C PROPOSED 1 PAD 697 -21C -D CASCADE LATERAL 2 - 4" POLY LINES EXISTING PAD 697-2SC \PROPOSED PAD 697-26A CASCADE LATERAL 2 - 4' POLY LINES WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 550 EAST SECOND NORTH PHONE: 307-875-3638 GREEN RIVER, WY 307-875-3639 www. whsmiihpc. com DRAWN BY: CED JOB NO: 26099 DATE: 03/25/70 LEGEND Q EXISTING VALVE CAN ■ EXISTING PAD LOCATION EXISTING WATER LINES EXISTING ROADS PROPOSED PAD 697-268 SEE MAP 3 CENTRAL PROJECT AREA SEE MAP 5 SOUTHERN PROJECT AREA PROPOSED PAD 697-23C WATER LINE MAP AND VALVE LOCATIONS OF THE WESTERN PROJECT AREA EXISTING PAD 697-23A PROPOSED PAD 697-23D 3 SCALE: 7" = 70DD' MAP PREPARED FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOUSTON, TX 77056 MAP 4 CENTRAL PROJECT AREA - SEEMAPI NORTHERN! PROJECT AREA EXISTING PAD 697-2C CDP SEEMAP2 EASTERN PROJECT AREA J PROPOSED PAD 695-60 EXISTING CENTRAL PIPE 1- 8" STEEL LIN EXISTING 1- 4" POLY LIN PAD 897-12A PROPOIED PAD 697-11C EXISTING gCE$NTgR�AEL PIPELINE 1E -4"POLYLINES EXISTING PAD 696-18A EXISTING BA LATERAL 18 EXISTING 8C LATERAL 97-140 EXISTING CENTRAL PIPELINE 1 - B' STEEL LINE IG 1 -4' POLY LINES T -23X , EXISTING �P i= 3A EXISTING PAD 696-18C EXISTING. CENTRAL PIPELINE 1- 8" STEEL LINE 1- 4" POLY LINES SR9 23 I PROPOSED SEE MAP 5 PAD 697-23D SOUTHERN PROJECT AREA PROPOSED PAD 897-28C DRAWN BY: CED WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 550 EAST SECOND NORTH PHONE: 307-875-3638 GREEN RIVER, WY 307-875-3639 www. whsmiihpc. com JOB NO: 26099 DATE: 03/25/70 LEGEND Q EXISTING VALVE CAN ■ EXISTING PAD LOCATION EXISTING WATER LINES EXISTING ROADS WATER LINE MAP AND VALVE LOCATIONS OF THE CENTRAL PROJECT AREA SCALE: T" = 2000' MAP PREPARED FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOUSTON, TX 77056 MAP 3 COUPLER # LATITUDE LONGITUDE ELEVATION 100 39°29'31.51335 108°13'45.72422 8254.5 101 39°29'30.6908 108°13'45.89787 8269.9 102 39°30'31.80067 108°13'3.126 8373.5 103 39°32'57.86323 108°10'32.63472 8367.5 104 39°35'54.03057 108°12'47.1225 8413.8 105 39°33'56.34408 108°8145.6746 8045.1 106 39°33'46.40999 108°8'56.43913 8082.1 107 39°33137.26639 108°92.20686 8135.1 108 39°3320.10851 108°9'14.78751 8213.6 109 39°31'15.62023 108°10'40.28531 8274.3 110 39°31'22.89 108°10'33.53866 8332.6 111 39°30'19.62967 108°11'23.30681 8488.3 112 39°30'6.91281 108°11'4.80942 8419.7 113 39°30'5.7612 108°11'3.84485 8436.1 114 39°29'49.77728 108°10'48.18385 8359.0 115 39°29'50.2898 108°10'48.75253 8342.4 116 39°29'51.7332 108°10'50.35545 8294.0 117 39°29'53.23198 108°10'51.98368 8324.6 118 39°29'30.75484 108°10'46.98029 8418.8 119 39°29'30.10332 108°10'47.09513 8426.5 120 39°29'11.52051 108°10'42.67292 8396.4 121 39°29'12.95385 108°10'42.55206 8394.4 122 39°29'12.10565 108°10'42.63398 8393.8 123 39°28'52.54344 108°10'44.50238 8489.0 124 39°28'51.43171 108°10'44.70447 8477.0 125 39°30'56.1947 108°10'40.45006 8410.2 126 39°33'01.62835 108°09'41.40137 8308.0 127 39°28'31.93377 108°10'44.68087 8453.3 128 39°28'15.64613 108°10'38.36679 8441.8 129 39°28'13.38274 108°10'39.68647 8455.4 130 39°28'3.75539 108°10'44.3656 8455.3 131 39°27'56.13354 108°10'46.99656 8430.7 132 39027'53.72226 108°10'47.8092 8440.2 133 39027'38.17844 108°10'49.70522 8474.1 134 39°27'35.68356 108°10'46.72767 8440.9 135 39°30'3.79715 108°112.91878 8448.6 136 39°30'3.99555 108°11'2.97178 8448.1 137 39°30'2.57813 108°112.9802 8448.5 138 39°30'52.14146 108°1247.66624 8397.7 139 39°30'34.17689 108°13'0.42658 8385.6 140 39°30'37.46904 108°12'57.3855 8410.8 141 39°30'11.67245 108°11'11.5966 8442.7 142 39°30'11.58492 108°11'11.50122 8441.5 143 39°30'17.00513 108°13'16.95059 8313.9 144 39°30'11.65426 10801320.19071 8360.1 145 3902953.76264 108°1331.56727 8338.0 146 39°30'51.1571 108°12'45.25144 8394.6 147 3902821.07918 108°10'37.67436 8384.5 148 3902820.46543 1081 0'37.85639 8389.1 149 39°27'39.65546 108°10'51.66195 8465.3 150 3903027.22582 108°13'4.80988 8346.1 151 39°30'27.71844 108°13'3.77555 8359.2 152 39°29'58.07007 108°1329.93429 8311.6 153 39°29'58.95776 108°13'29.54902 8310.2 154 39°32'48.72722 108°10'5.19424 8347.8 155 3903244.27356 108°10'13.20264 8393.5 156 39°29'43.85319 108°13'45.07732 8254.4 157 3902944.26691 108°13'44.44924 8280.2 158 3903040.23545 1081 230.31014 8309.4 159 39°33'15.65995 108°9'12.15773 8250.6 160 39°33'15.76157 108°9'12.49508 8250.0 161 39°32'42.34203 10801021.17308 8361.7 162 39°33'2.06631 108°9'41.81158 8306.3 163 39°30'29.94732 108°12'10.67091 8232.9 164 39030'33.31833 108°12'18.47177 8248.5 165 39°3316.53095 108°12'33.90305 8435.0 166 39036'7.9621 108°12'26.94929 8399.4 167 39036'13.2991 108013'0.10631 8496.4 168 3903241.76222 10801021.77072 8365.1 169 39°36'15.37935 108°12'52.64075 8527.7 170 390362.84308 108°12'19.05103 8345.9 171 39°36'2.98318 10801221.50059 8347.4 172 39034'31.75561 108°10'59.86427 8269.8 173 39°34'5.61114 108°11'37.78539 8328.5 174 39°33'21.97577 108°8'11.67342 8110.0 175 3903421.99943 108°12'40.10416 8403.6 176 39°34'33.12343 108°12'33.65459 8417.2 177 39°34'36.69962 108°12'30.34149 8413.4 178 39°33'29.6503 108°9'6.85045 8161.5 179 39°32'48.68418 108°10'39.78187 8328.2 180 39°33'35.28272 108°8'26.82327 8170.3 181 39°33'38.72235 108°826.79426 8186.6 182 39°33'37.47456 108°8'26.49544 8170.8 183 39°33'15.93908 108°9'9.46716 8228.5 184 39035'54.43342 108°12'17.04588 8344.8 185 39°35'57.17689 108012'03.65927 8260.3 186 39°35'56.69507 108012'01.75844 8260.0 187 39°35'56.28832 108°12'00.89032 8259.9 188 39°35'05.86589 108°11'52.79521 8219.6 189 39°35'06.28048 108°11'52.86495 8221.7 190 39034'34.10248 108°1232.50019 8430.9 191 39°34'33.47655 108°12'32.75193 8432.1 192 39°33'01.62835 108°09'41.40137 8308.0 193 39°32'43.48613 108010'31.08030 8403.2 194 39°32'43.47017 108°10'31.02171 8402.9 WATER LINE & COUPLER LOCATION MAP 0 5001000 2000 4000 6000 105 106 PAD 596-20C PAD 696-31 fr PAD 596-32C PAD 596-34 13 PAD 596-350 PAD 69? -5C Y T PAD 697-2C 1 GARDEN GULCH ROAD OWER GUARD SHACK 1 PAD 697-23X 141 11. PAD 697-23A 187 18 189 19 155 156 157 160 161 162 163 LEGEND M.O.C. WATERLINE ASBUILT IN GROUND M.O.C. WATERLINE LOCATED WITH METRO -TECH M.O.C. WATERLINE BASED ON GASLINE N COUPLER ROAD WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 550 EAST SECOND NORTH PHONE: 307-875-3838 GREEN RIVER WY 307-875-3639 mrn: whsmithpc.com WATER LINE MAP AND VALVE CAN LOCATIONS ENTIRE PROJECT AREA MARATHON OIL COMPANY P.O. Box 3128 5555 Son F&tps Houston, TX 77056 Houston, TX 77253 DRAWN BY: AKT CHECKED BY: CED SCALE: NOTED DATE: 03/25/2010 JOB NO: 26099 SHEET 1 OF 1 REVISIONS: 1 Marathon Oil Piceance Operations Emergency Response Plan Appendix G: WCEM Appendix G: Well Control Emergency Management Well Control Emergency Management Document Below: January 2013 © The Response Group Page 1 a WELL CONTRO' EMERGENCY MANAGEMENT PLAN {' Marathon Oil Corporation. June 9, 2011 Description Page ■ice,�1 Document No.: Well Control Emergency Management Plan Marathon 011 Section: Table of Contents Corporation. Title: Table of Contents TABLE OF CONTENTS Section 1.0 Introduction 2 2.0 Well Control Emergency Management Plan Policy Statement 4 3.0 Incident Command Structure 5 3.1 WCEMP Structure 5 3.2 On -Site Response Team 8 3.3 Relief Well Team 9 3.4 WWCI Emergency Contact List 18 4.0 Incident Response Levels 19 5.0 Intervention Action Plan 23 6.0 On -Site Response Team Roles and Responsibilities 24 7.0 Equipment List for Large -Scale Events 37 Appendix A Data Acquisition Forms 38 Appendix B National Incident Management System Abbreviations 50 Appendix C Oil and Gas Abbreviations 51 Appendix D H2S Operations 54 Appendix E Voluntary Well Ignition 69 Appendix F Intervention Equipment List 90 Appendix G Air Monitoring Requirements 99 Appendix H Local Responder Information 103 Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 1 Wild Well Control, Inc. *A Document No.: Well Control Emergency Management Plan Marathon 00 Section: 1.0 — Introduction Marathon Title: 1.0 — Introduction INTRODUCTION PURPOSE This Well Control Emergency Management Plan (WCEMP) is intended to supplement existing operations' Emergency Management Plans. Local Emergency Management Plans include all spill and emergency response guidelines and contacts, as well as Company -specific Incident Command System roles, responsibilities, and guidance, for responding to hazards and emergencies in each operating area. Local Emergency Management Plans are available in each operation's area office through the Health Environment Safety and Security (HES&S) department. Procedures for handling emergencies are absolutely essential to ensure the protection of life, property, and the environment. Wild Well Control, Inc.'s (WWCI) Engineering Division has developed this WCEMP for the Company. The equipment and procedures specified in this WCEMP address various well control incidents ranging from routine well control operations to incidents involving a total loss of well control necessitating the immediate mobilization of intervention equipment and personnel. This WCEMP is system -wide in nature and is intended for use in any operational area. This document addresses drilling, workover, and production operations, and it assumes that adequate Oil Spill Response Plans are in place. The primary objective of the WCEMP is to establish a process for responding to and safely managing well control emergencies. OBJECTIVES The primary objective of the WCEMP is to establish a process for responding to and safely managing well control emergencies using a standard, uniform approach. This process includes the following responsibilities: 1. Protect the personnel at the site in case of a well control emergency. 2. Define the notification protocols and methods. 3. Prevent further environmental or facility damage or personnel injury while adequate equipment and personnel are being mobilized. Issue Date Revision No. Revision Date i Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 2 Wild Well Control, Inc. nDocument No.: Well Control Emergency Management Plan Marathon 011 Section: 1.0- Introduction Marathon Title: 1.0 - Introduction 4. Define the critical information that is required in order to determine the appropriate response level and strategies. 5. Organize personnel and provide guidelines for their role in the emergency response and subsequent management. 6. Preselect sources and develop mobilization plans for personnel, equipment, material, and services typically required for implementation of well control procedures. 7. Normalize the incident and bring it under control. The WCEMP is not intended to replace sound judgment. Modification of the mobilization plan and intervention strategy might be necessary depending on the circumstances of the incident. Well control incidents require common sense and professional judgment on the part of the person or persons in charge of operations, and no operation should be undertaken if it involves unreasonable risk to personnel. Information is essential to implement an effective well control incident management system. Recommendations are included for the information to be gathered both at the well site and from office records. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 3 Wild Well Control, Inc. (i Marathon 011 Document No.: Well Control Emergency Management Plan Section: Corporation. Title: 2.0 — Well Control Emergency Management Plan Policy Statement 2.0 — Well Control Emergency Management Plan Policy Statement WELL CONTROL EMERGENCY MANAGEMENT PLAN POLICY STATEMENT The Company is committed to continual readiness of the WCEMP processes, thereby promoting safety as well as the protection of environmental and Company assets during well control emergencies. Commitment to this policy is demonstrated by the signature of the Source Control Unit Leader: Full and complete support is expected by all employees, contractors, and vendors. The WCEMP Policy is composed of several foundational principles operating together to facilitate a coordinated and effective response to well control emergencies. PREPAREDNESS Develop plans to provide guidance and direction. Provide clear assignment of roles and responsibilities. COMMUNICATIONS Provide concise communication of references and lists. Inform workforce through training and communication. RESOURCE MANAGEMENT Provide descriptions of possible required resources and equipment. Document location and availability of equipment and resources. COMMAND AND MANAGEMENT Define the Incident Command Structure (ICS). Ensure full and effective participation and deployment. ONGOING MANAGEMENT AND MAINTENANCE Provide revision control maintaining accuracy and reliability. Issue Date Revision No. r Revision Date Prepared By Approved By Page 4 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. ADocument No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure Corporation. Title: 3.1— WCEMP Structure WCEMP STRUCTURE The Well Control Emergency Response Plan (WCEMP) provides an integrated and systematic approach to well control incident management. This system provides the policies and procedures that are designed to provide guidance to the Company employees, contractors, and other persons in the case of a well control emergency. DOCUMENTATION STRUCTURE The structure of the WCEMP is generally aligned with integrated elements of major international standards such as National Incident Management System (NIMS), American Petroleum Institute (API), International Organization for Standardization (ISO), Occupational Health and Safety Advisory Services (OHSAS), and others. This helps to ensure that the WCEMP comprehensively addresses each of the well control emergency elements systematically and completely. INCIDENT COMMAND STRUCTURE The NIMS of the Federal Emergency Management Agency (FEMA) is a systematic approach for preventing and reacting to emergency situations. Within the system, the ICS is a standard method for organizing and naming the job positions that would be required in the case of an incident. This provided a well-developed organizational structure, which is crucial to an effective emergency response. This WCEMP uses an ICS that has been developed specifically for responding to well control emergencies. The organizational structure for the management of well control emergencies is called the Emergency Response Organization, which comprises the Well Control Emergency Response Team (WCERT) and the On -Site Response Team (ORT), all reporting to the Incident Commander. This WCEMP covers the duties and responsibilities of the ORT. COMMAND AND MANAGEMENT The WCEMP provides effective and efficient incident management and coordination. This is accomplished by providing a standardized response structure that coordinates on-site and off-site management structures along with vital well control expertise provided by contractors. Issue Date Revision No. r Revision Date Prepared By Approved By Page 5 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. ADocument No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure Corporation. Title: 3.1— WCEMP Structure PREPAREDNESS This WCEMP provides the framework to help manage well control incidents. Every emergency is different, but being prepared with a comprehensive and systematic approach, and working in conjunction with appropriate well control expertise, provides the best opportunity for an optimum and favorable outcome. COMMUNICATIONS AND INFORMATION MANAGEMENT The roles and responsibilities for key well control response personnel are clearly defined. Specific and accurate contact information is consolidated and made accessible to well control personnel and other stakeholders. Information management includes processes ranging from the collection and formatting of information prior to the incident via the use of forms and data sheets. This is done to capture and preserve information that develops during the course of the incident, as well as postincident evaluation, leading to system and process enhancement. RESOURCE MANAGEMENT Resource management is a vital need during the entire well control incident. The WCEMP provides equipment listings that help maximize the effectiveness of well control efforts. ONGOING MANAGEMENT AND MAINTENANCE Ongoing management and maintenance of the WCEMP is critical to its utility as an effective tool to help mitigate well control incidents. It must be kept current to the project's needs. A Management of Change (MOC) process should be used to ensure that any changes to the WCEMP, due to a change of contact data, well or site information, or other items, as well as any adjustments that might be generated from a periodic or annual review, are reflected in an accurate and timely fashion. The Person in Charge (PIC) for each work site should review the content of the WCEMP and determine which of the required plans, programs, and procedures listed in this manual are applicable to their operation. This review should be conducted at least once each year or when the WCEMP is updated, whichever is more frequent. An optional WCEMP review meeting is described and documented to help ensure that the plan is kept current to ongoing project and operational conditions as well as to incorporate any additional lessons learned on this or other projects that could enhance the effectiveness or utility of the WCEMP. Issue Date Revision No. Revision Date Prepared By 6/9/2011 R. B. Davis Approved By Bryan Beautz Page 6 Wild Well Control, Inc. ' Document No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure Corporation. Title: 3.1— WCEMP Structure ON-SITE RESPONSE TEAM ORGANIZATION CHART Relief Well Unit Leader Facility/Rig Manager Marathon ICS Source Control Unit Leader Operations Personnel ORT Operations WWCI Team Support Contractors WWCI Technical Specialists Figure 3.1— On -Site Response Team Organization Chart Issue Date Revision No. � Revision Date Prepared By Approved By Page 7 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon011 Document No.: Section: Corporation, Title: Well Control Emergency Management Plan 3.0 — Incident Command Structure 3.2 — On -Site Response Team ON-SITE RESPONSE TEAM The ORT comprises Company and contract personnel on a 24-hour callout who have the experience to deal with well -control -related emergencies. It will also have additional vendor support personnel to assist in the emergency. The ORT will be managed by the Source Control Unit Leader, who will direct the actions of the team. The ORT will be responsible for on-site activities. Primary Objectives of the ORT 1. Have specific members of the staff immediately available in the event of an incident. 2. Help plan and implement the well intervention. Primary Duties of the ORT 1. Secure the incident site and determine status of all personnel. 2. Provide medical assistance as required. 3. Make initial assessment of emergency situation. 4. Provide notification to the Company and WCERT. 5. Mobilize locally available equipment and services. 6. Determine equipment and services required for operations and safety. 7. Establish on-site operations, communications, and medical facilities. 8. Provide regular updates to the Company and WCERT member section chiefs. 9. Establish project work files and implement document control/record-keeping procedures. 10. Establish and implement the well intervention plan. 11. Maintain documentation. Issue Date Revision No. r Revision Date Prepared By Approved By Page 8 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. 1_9 Document No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team RELIEF WELL TEAM — PERSONNEL ORGANIZATION The relief well planning and implementation team comprises personnel from various disciplines within the Operator's organization, the directional drilling contractor, the drilling rig contractor, Vector Magnetics, WWCI, and other contractor personnel as required. The organizational diagram for the planning team is shown in the following figure. Project Team Leader (Operator) Drilling Contractor Management Drilling Contractor ► Technical Personnel Drilling Engineering (Operator) WWCI Vector Magnetics Directional Drilling Contractor Geology/Reservoir (Operator) Staff Reservoir Engineers (Operator) Staff Geologists (Operator) Figure 3.2 — Relief Well Planning Team Organizational Chart Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 9 Wild Well Control, Inc. 1_9 Document No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team RELIEF WELL TEAM — PROJECT ORGANIZATION (PLANNING PHASE) The planning phase of the project will be divided into four interrelated groups: 1. Directional Drilling and Intercept 2. Drilling Engineering/Planning 3. Kill/Plug and Abandon (P&A) Operations 4. Hazard Assessment Personnel from the planning team as well as outside contractors and specialists will be asked to work on various groups associated with the planning phase. The tasks associated with each group are discussed in the following sections. DIRECTIONAL DRILLING AND INTERCEPT TASKS The goals of the Directional Drilling and Intercept Group are listed in the following paragraphs without regard to priority or importance. Surface Location A preliminary surface location will be chosen based on drilling trajectory, intercept, and safety issues (such as gas dispersion and radiant heat). WWCI will review the proposed surface location in terms of safety. WWCI, along with Vector Magnetics, will review the proposed surface location in terms of the required directional drilling trajectory and approach angle. A memo will be issued listing the results of the review. The plan survey will resolve the relative distance and direction between the blowout well and relief well surface locations. Uncertainty should be reduced to below 1 m and several (redundant) surveys should be planned. Gross errors in the relative position between the two surface locations cannot be tolerated. Trajectory Preliminary trajectories will be developed by the Directional Drilling Contractor. WWCI and Vector Magnetics will review the proposed trajectories in terms of initial search depth, intercept angle, proximity logging program, and so on. A memo will be issued listing the findings and recommended modifications, if any, that result from the review. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 10 Wild Well Control, Inc. Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team Drilling Tools Determine the most appropriate directional drilling assemblies, measurements while drilling/logging while drilling (MWD/LWD), near -bit inclination/azimuth tools, surveying tools, and procedures. Issue a memo stating recommendations and provide supporting logic. Intercept Method Determine the most appropriate method of intercepting the blowout wellbore. Consider kill/plugging operations. Plan all required tools to accomplish the intercept, including mills and deep-penetrating/oriented tubing conveyed perforator (TCP) guns. Determine relative position of last casing seat if a direct intercept is to be made. Plan to minimize the open -hole section between the last casing seat and the intercept point, within safe limits. Evaluate whether LWD or other methods are required to identify formation tops for casing -seat placement near the intercept. Issue a memo describing proposed intercept method, specialized tool requirements, and supporting logic. Intercept Point Determine the most appropriate depth for the intercept in order to accomplish the relief well goals. Evaluate the nature (competency) of the formation at the proposed intercept point and the potential for fluid loss, sloughing, or hole collapse. Issue memo specifying intercept depth and provide supporting logic. If direct intercept/reentry is required, evaluate bulk density and hardness of formations (rate -of -penetration log) near intercept point for best possible side -loading resistance. Survey Uncertainty Develop a model of the position uncertainty for the blowout well and the relief well. These uncertainty models will be used to review the proposed directional trajectory and, especially, the initial search depth. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 11 Wild Well Control, Inc. Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team DRILLING ENGINEERING/PLANNING TASKS The goals of the Drilling Engineering/Planning Group are listed in the following paragraphs without regard to priority or importance. Casing Design (Tubulars) Develop the most appropriate casing tubular design to meet the requirements of the relief well. Evaluate burst, collapse, tensile, and triaxial stresses. Recommend appropriate size, connection, weight, and grade of casing. Consider the additional stresses imposed by pumping ambient temperature fluids, in case a high -rate kill becomes necessary (rates and pressures will be provided by WWCI after kill modeling). Consider the potential for abnormal charging as identified by the Hazard Assessment Group. Develop recommendations and contingencies as required. Evaluate the need for additional casing string to combat potential hole problems or abnormal charging. Issue memo detailing tubular design, with safety factors and contingencies stipulated. Casing Design (Seat Selection) Develop the most appropriate casing seat design based on pore pressure, fracture gradient, and mechanical properties of the casing. Consider the potential for abnormal charging as identified by the Hazard Assessment Group. Develop recommendations and contingencies as required. Evaluate the need for additional casing string to combat potential hole problems or abnormal charging. Issue a memo detailing casing seat design, with kick margins and trip margins stipulated. Cementing Recommendations Develop the most appropriate cement jobs for all casing strings. Consider thermal stresses that might be imposed by high -rate ambient temperature fluid injection. Evaluate casing cement jobs in view of possible second intercept and sidetrack (window or section milling). Issue memo detailing cement design recommendations and design factors. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 12 Wild Well Control, Inc. Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team Mud Program Develop the most appropriate mud program for each hole section. Consider all normal design factors. Recommend adequate inventories of mud chemicals and weighting material. Recommend appropriate and adequate volumes of lost -circulation material (LCM) for drilling phase and intercept/P&A operations. Mud Logging Recommend appropriate mud -logging program and vendor. Rig Selection Locate and contract suitable rig for the relief well operations. Base initial criteria on conventional drilling -related parameters. WWCI will make an assessment of all candidate rigs to determine suitability in terms of well control systems and other aspects related directly to the relief well and kill operations. Consideration should be given to whether the drilling contractor will require additional insurance coverage for the relief well operations (sometimes required for such operations). KILL/P&A OPERATIONS TASKS The goals of the Kill/P&A Operations Group are listed in the following paragraphs without regard to priority or importance. Kill Modeling WWCI will perform multiphase dynamic kill modeling (using the Dyn-X® computer model) to define the pump rates, expected friction pressures, and hydraulic horsepower (HHP) requirements for various kill scenarios. A memo will be issued detailing the findings of the dynamic kill modeling, including basis of design, scenario descriptions, and HHP requirements, with recommended redundancies. Contingencies Various scenarios will be developed so that adequate hazard mitigation and operational practices can be developed to ensure the reliability of the relief well drilling and kill operations. Scenarios might include limited injection capabilities, disruption of annular bridges, or premature intercept. Issue Date Revision No. i Revision Date i Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 13 Wild Well Control, Inc. Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team A memo will be issued detailing the results of the scenario planning efforts. The memo will contain discussions of the probabilities, consequences, and mitigating measures associated with each reasonable scenario. Diagnostics An investigation will be conducted to determine whether diagnostic procedures such as noise/temperature logs, thermal decay time (TDT) logs, pumping, or pressure testing are feasible or warranted based on the particular incident. These kinds of diagnostic measures are sometimes warranted to evaluate or ensure the adequacy of the kill or plugging operations. A memo will be issued discussing the various aspects, applicability, and need for such diagnostic measures. For those measures that are recommended, a discussion of the equipment and services required, as well as the impact on relief well planning and implementation, will be included. Kill Equipment The equipment, material, and services required to undertake all kill operations (including contingency operations) will be stipulated. A memo will be issued describing the required HHP, fluid volumes, specialized tools, low-pressure fluid transfer, pump lines, and blowout preventer (BOP) stack modifications for the kill operations. P&A Planning Both the blowout well and the relief well will require proper plugging and abandonment after the kill operations. The relief well might be used as a replacement well after kill and plugging operations have been concluded. A memo will be issued detailing the equipment, services, and procedures required for proper plugging and abandonment of the two wells. HAZARD ASSESSMENT TASKS The goals of the Hazard Assessment Group are listed in the following paragraphs without regard to priority or importance. Shallow Seismic A determination will be made as to whether additional seismic work is required in order to define the boundaries of shallow gas accumulations. This determination will be based Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 14 Wild Well Control, Inc. Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team on the circumstances of the blowout and the potential for charging of shallow, porous zones. A memo will be issued with recommendations as to whether further investigation is warranted. If so, the memo will include equipment and services required, along with operational procedures to be implemented. Charging The potential impact of abnormal charging on relief well design and operations will be investigated based on geological column and blowout circumstances (such as open flow versus bridged). A memo will be issued discussing the results of the investigation and proposed changes to well design, surface location, or other aspects of the relief well. Surface Hazards Surface hazards are generally more applicable to offshore incidents. However, gas accumulations from surface vents, abandoned wellbores, and pipelines, or other hazards to the relief well operations will be evaluated. A memo will be issued discussing any unusual hazards found and proposed methods to mitigate their effects. Shallow Gas If shallow charging is confirmed (or absence cannot be confirmed), enhanced shallow gas procedures will be implemented for the top -hole portion of the relief well. A memo will be issued that defines the equipment and methods proposed for the shallow gas handling procedures. SimOps A Simultaneous Operations (SimOps) plan will be developed for operations that should be implemented in order to configure the blowout well for kill operations. This might include additional diversion or monitoring devices. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 15 Wild Well Control, Inc. 1_9 Document No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure 11 Corporation. Title: 3.3 — Relief Well Team RELIEF WELL TEAM — OPERATIONAL PHASE The operational phase will consist of conventional drilling operations enhanced by the necessary hazard mitigation measures for shallow gas or abnormal charging, and precise directional control based on proximity logging results. WWCI will provide expert guidance on well -control -related issues, as well as assistance with directional control. This support will consist of a two-man team comprising one Senior Well Control Specialist and one Senior Well Control Engineer stationed at the drill site on a full-time basis. As the relief well nears the intercept point, both WWCI specialists will focus on the intercept and kill -operations planning. The relief well will be separated into three distinct phases, based on relief well proximity. Each phase will have a defined status for kill equipment and personnel status. Typical phases are described below. PHASE 1 — SPUD TO INITIAL SEARCH DEPTH Operations: Drill to a preplanned point in space that positions the relief well sufficiently close to the blowout well magnetic target. Make initial proximity search and plan pass -by for triangulation (if deemed necessary) or approach path. Kill -Equipment Status: Not required under normal circumstances. PHASE 2 — INITIAL SEARCH DEPTH TO APPROACH Operations: Kill -Equipment Status: Determine the relative position between relief well and blowout well. Directional corrections to follow blowout well to intercept point. Spot-checks with proximity logs to determine relative positions as required. MIRU and test kill equipment when drilling within 50' 3-D distance. Kill equipment and personnel are to be on standby status. All high-pressure and low-pressure kill pumping equipment is to be pressure- and rate -tested. Coordination and control procedures are to be in place. Personnel assignments and kill procedures, including limiting pressures, contingencies, and other related matters, are to be documented, distributed to all involved parties, and understood. Issue Date 6/9/2011 Wild Well Control, Inc. Revision No. Revision Date 1 Prepared By R. B. Davis Approved By Page Bryan Beautz 16 'MN Document No.: Well Control Emergency Management Plan Marathon 011 Section: 3.0— Incident Command Structure Marathon Title: 3.3 — Relief Well Team All kill -related equipment will remain on 24-hour standby (while drilling), capable of implementing kill procedure within 15 minutes of notification. Kill mud should be monitored 24 hours per day, agitated, and kept ready for kill implementation. PHASE 3 -APPROACH TO INTERCEPT POINT Operations: Kill -Equipment Status: Make directional corrections as required to follow blowout well to intercept point. Perform spot checks with proximity logs as required. Make final alignment for setting casing to within 40'-60' of intercept point, or aligned with blowout wellbore within 1 m for perforating operations. Alignment at casing shoe must be appropriate for intercept method. Set casing and drill out for intercept/kill operations. All kill -related equipment will be running and manned 24 hours per day, unless otherwise instructed. Kill procedure should be implemented without delay upon intercept. All monitoring and supervisory personnel should be on ready status, with a communication system in place; operations and status should be checked every half hour. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 17 Wild Well Control, Inc. Irk!, Document No.: Well Control Emergency Management Plan Marathon Oil Section: 3.0— Incident Command Structure Corporation. Title: 3.4 — WWCI Emergency Contact List WILD WELL CONTROL, INC. EMERGENCY CONTACT LIST For Well Control Emergencies CALL: +001.281.784.4700 USA Answered 24 Hours/Day by a WWCI Employee Check local contact lists to find contact information for additional well control companies. Wild Well Control, Inc. 2202 Oil Center Court, Houston, TX 77073 Telephone: +001.281.784.4700/Fax: +001.281.784.4750 E-mail: wildwell@wildwell.com, Website: www.wildwell.com Issue Date Revision No. � Revision Date Prepared By Approved By Page 6/9/2011 R. B. Davis Bryan Beautz 18 Wild Well Control, Inc. Drilling Superintendent L 1 Production Team Leader L 1 (Mil Mar thon011 Corporation. Document No.: Section: Title: Well Control Emergency Management Plan 4.0 — Incident Response Levels 4.0 — Incident Response Levels INCIDENT RESPONSE LEVELS Figure 4.1 is a summary of the incident response levels. These response levels are intended as guidelines and can be used on various types of wells. Well Control Incident Driller/Crew Drilling Manager Drilling Supervisor Tool Pusher 7 1 -- Evaluate Incident and Provide Information 1 Response Level Determined Production Supervisor Level 1 7 • Insufficient mud stocks • Small kick • Mild to moderate loss of circulation • Casing wear • BOP, wellhead, or surface leaks • Sustained casing pressure < 50% of burst rating Level 2 • BOP failure • No pipe in hole • Pipe off bottom • Large -volume kick • High-intensity kick • Simultaneous losses • Bit plugged • DP washout • High surface pressure • Choke failure/plugged • Sheared DP • Production/surface casing pressure > 50% burst rating • Failure of subsurface safety valve Figure 4.1— Incident Response Levels Level 3 Initiate Emergency Response Issue Date Revision No. r Revision Date Prepared By Approved By Page 6/9/2011 I R. B. Davis Bryan Beautz 19 Wild Well Control, Inc. Situation Deteriorates 10, ' Document No.: Well Control Emergency Management Plan Mar thou 011 Section: 4.0— Incident Response Levels Corporation. Title: 4.0 — Incident Response Levels LEVEL 1 INCIDENT Level 1 Incident Kick Intensity <1ppg Emergency Event Leaks Can Be Isolated Production Casing Pressure <50% of Burst Mild or No Losses Intermediate Casing Pressure <25% of Burst Figure 4.2 — Level 1 Incident Level 1 Incident Level 1 Actions Operator and Dri II ing Contractor Notification EvaluateSituation Use Appropriate Kill Method Implement Well Kill Keep Al Parties Informed Figure 4.3 — Level 1 Actions Declare Level 2 Incident Kill Successful End of Incident Issue Date Revision No. � Revision Date Prepared By 6/9/2011 R. B. Davis Approved By Bryan Beautz Page 20 Wild Well Control, Inc. ADocument No.: Well Control Emergency Management Plan Mar thou 011 Section: 4.0— Incident Response Levels Corporation. Title: 4.0 — Incident Response Levels LEVEL 2 INCIDENT Level 2 Incident Emergency Event Leaks Cannot Be Isolated Protective Casing Pressure>0 psi Production Casing Pressure>50% of Burst Severe Losses Intermediate Casing Pressure >25% of Burst Figure 4.4 — Level 2 Incident Level 2 Incident Level 2 Actions Operator and Dri II ing Contra ctor Notification Eval uate Situation Reduce Rig Crew and Nonessential Personnel Contact/Mobi I i ze WWCI Declare Level3 Incident Situation Deteriorates Evaluate Need for Special Equipment C Volumetric Control Wait and Weight Method Implement Well Kill Keep All Parties I nformed Figure 4.5 — Level 2 Actions Kill Successful End of Well Kill Issue Date Revision No. r Revision Date Prepared By 6/9/2011 R. B. Davis Approved By Bryan Beautz Page 21 Wild Well Control, Inc. ' Document No.: Well Control Emergency Management Plan Mar thou 011 Section: 4.0— Incident Response Levels Corporation. Title: 4.0 — Incident Response Levels LEVEL 3 INCIDENT Level 3 Incident Surface Blowout Emergency Event Surface Pressure> Equipment Rating Underground Blowout Any Dangerto Personnel, Equipment, or Environment Figure 4.6 — Level 3 Incident Level 3 Incident Level 3 Actions Evacuate and Secure Site 11, Account for All Personnel Medevac Injured Personnel Notifications Shut Down Equipment If Possible Contact and Mobilize WWCI Notify ► Governmental Authoriti es Contact Operations Personnel Figure 4.7 — Level 3 Actions Fire Watch Event log Evaluate/Gather Information Issue Date Revision No. � Revision Date Prepared By 6/9/2011 R. B. Davis Approved By Bryan Beautz Page 22 Wild Well Control, Inc. Irk Marathon 011 Document No.: Well Control Emergency Management Plan Section: 5.0 — Intervention Action Plan Corporation. Title: 5.0 — Intervention Action Plan INTERVENTION ACTION PLAN This section of the WCEMP is intended to detail an action plan for a Level 3 incident (or possibly a Level 2 with significant probability of escalation). Figure 5.1 (Response Process Flowchart) illustrates the major activities recommended for an immediate response (first 12 to 24 hours) and the Interim Actions that will be required to establish on-site operations. CDay 1 Response J CDay 2 to Completion (Well Control Event On -Site Initial Response Evacuation, Medevac Secure the Site Mobilize Fill Equipment Gather and Distribute Initial Information Initiate Fire Watch and Event Log On Site J Continue Firefighting and Asset Protection Plan and Conduct On -Site Assessment Continue Fire Watch Provide Updates to Teams Report Significant Changes to Team Leaders Establish On -Site Command Center Arrange Adequate Communications Initiate Daily Site Operations, Planning, and Reporting Protocol Assist with Development of Intervention Plan Support Initial Response Assemble and Brief Teams Mobilize WWCI Secure the Area Activate Pollution Control Provide HR Assistance Source Local Equipment Gather Incident Information External Notifications Support Teams J Gather Office Data Plan and Conduct On -Site Assessment Plan and Execute Equipment Logistics Develop and Issue Assessment Report Develop and Issue Incident Report Develop and Issue Capping Plan Develop and Issue ReliefWell Plan Establish Daily Planning Protocol Figure 5.1— Response Process Flowchart Issue Date Revision No. r Revision Date Prepared By Approved By Page 23 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon C11 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.1— Source Control Unit Leader Primary: Reports to: SOURCE CONTROL UNIT LEADER Rig Foreman/Drilling Contractor Deputy Incident Commander GENERAL DUTIES AND RESPONSIBILITIES 1. Coordinate personnel -accounting efforts and evacuation of personnel. 2. Isolate the emergency site and initial notifications. 3. Provide primary assessment. 4. Mobilize locally available equipment and services as required. 5. Gather initial field information. 6. Above all, ensure the safety of on-site personnel during the initial stages of the intervention. 7. Following the initial response, work with the Well Control Operations Team and contractors to plan and implement intervention measures. SPECIFIC DUTIES MAKE initial assessment of incident and, if time allows, confer with Deputy Incident Commander and WWCI on remedial measures and appropriate response level. ORDER evacuation of rig and oversee evacuation procedures. Account for all personnel. ASSESS the need for medical assistance, Medevac, and search -and -rescue operations. Notify Company and advise of assistance required. RENDER first aid, as required. INITIATE any required search -and -rescue efforts that need to be undertaken. SHUT DOWN fired equipment, if possible. Issue Date Revision No. r Revision Date Prepared By Approved By Page 24 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon C11 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.1— Source Control Unit Leader SECURE site, if possible. ENSURE that the proper information has been gathered, as follows, so that an adequate response can be formulated: 1. Determine the status of the incident. 2. Determine the number of injuries and need for assistance. a. Names of injured personnel and employer b. Extent of injuries c. Medevac dispatched (if required) d. ETA of injured/evacuated personnel to staging area or hospital 3. Ensure that medical care and evacuation are proceeding, and that all personnel are accounted for. ESTABLISH and supervise the following: 1. Firefighting (FIFI) and asset protection 2. Fire watch and event log 3. Well control operations at the site PROVIDE frequent updates to Deputy Incident Commander during the WWCI initial mobilization. COORDINATE with drilling contractor representative, WWCI Team Leader, and Well Control Safety Specialist to ensure all hazards have been properly addressed before initial assessment or intervention measures are implemented. PROVIDE assistance in support of response and intervention efforts. 1. Establish exclusion or work zones. 2. Assess hazards and implement mitigation measures. 3. Establish On -Site Command Center. Issue Date Revision No. r Revision Date Prepared By Approved By Page 25 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon C11 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.1— Source Control Unit Leader COORDINATE with Well Control Safety Specialist to ensure all necessary personal protective equipment (PPE) has been provided. PROVIDE cost estimates/commitments to Planning Section Chief for tracking and processing. CONDUCT daily operations and planning meetings at the site. INITIATE and maintain accurate documentation of all conversations and actions. Issue Date Revision No. � Revision Date Prepared By Approved By Page 26 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon C11 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.2 — Relief Well Unit Leader Primary: Reports to: RELIEF WELL UNIT LEADER Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Provide technical assistance to ORT and Operations and Planning Section Chiefs for evaluation, planning, and implementation of a relief well. 2. Coordinate and communicate with the WCERT. SPECIFIC DUTIES ASSESS the need for relief well planning and initiate in conjunction with Well Control Team Leader as required. PROVIDE input into development of the Incident Action Plans for each work period, coordinating with Well Control Team Leader. ATTEND planning and briefing meetings on a regular basis. INITIATE and maintain a log of all conversations and actions. Issue Date Revision No. r Revision Date Prepared By Approved By Page 27 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. /Mg Marathon 01! Document No.: Well Control Emergency Management Plan Section: Corporation. Title: Primary: Reports to: 6.0 — On -Site Response Team Roles and Responsibilities FACILITY/RIG MANAGER 6.3 — Facility/Rig Manager Drilling Contractor Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Ensure the health, safety, and welfare of all persons at the installation. 2. Ensure the safety of the installation. 3. Make the initial notifications to installation parent company. 4. Coordinate reports to governmental agencies with the WCERT so there is no miscommunication. 5. Above all, ensure the safety of all on-site personnel during the initial stages of the intervention. 6. Ensure that the Company and governmental safety and environmental regulations are enforced. SPECIFIC DUTIES MAKE initial assessment of incident and, if time allows, confer with the Company Man on remedial measures and Response Level. ORDER evacuation of rig and oversee evacuation procedures. Account for all personnel. ASSESS the need for medical assistance or Medevac. RENDER first aid as required. SHUT DOWN fired equipment, if possible. SECURE rig, if possible. Issue Date Revision No. r Revision Date Prepared By Approved By Page 28 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. /Mg Marathon 01! Document No.: Well Control Emergency Management Plan Section: Corporation. Title: 6.0 — On -Site Response Team Roles and Responsibilities 6.3 — Facility/Rig Manager ENSURE that the proper information has been gathered, as follows, so that an adequate response can be formulated: 1. Determine the status of the incident. 2. Determine the number and type of injuries and need for additional assistance. a. Names of injured personnel and employer b. Extent of injuries c. Medevac dispatched (if required) d. ETA of injured/evacuated personnel to staging area or hospital 3. Ensure that medical care and evacuation are proceeding and that all personnel are accounted for. ESTABLISH and supervise the following: 1. FIFI and asset protection 2. Fire watch and event log COORDINATE notification of governmental agencies with the Operator when required by law. PROVIDE frequent updates to the Company Man and Drilling Contractor Management. COORDINATE with Source Control Unit Leader, ORT Leaders (Safety and Well Control Operations), and Well Control Engineer to ensure all hazards have been properly addressed before initial assessment or intervention measures are implemented. Issue Date Revision No. r Revision Date Prepared By Approved By Page 29 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. /Mg Marathon 01! Document No.: Well Control Emergency Management Plan Section: Corporation. Title: 6.0 — On -Site Response Team Roles and Responsibilities 6.3 — Facility/Rig Manager PROVIDE assistance in support of response and intervention efforts. 1. Establish exclusion or work zones. 2. Provide hazard assessment and implement mitigation measures. 3. Establish On -Site Command Center. COORDINATE with Well Control Safety Specialist to ensure all necessary PPE has been provided. INITIATE and maintain a log of all conversations and actions. Issue Date Revision No. r Revision Date Prepared By Approved By Page 30 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon011 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.4 — Well Control Safety Specialist Primary: Reports to: WELL CONTROL SAFETY SPECIALIST WWCI Well Control Safety Specialist Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Advise the WCERT, on-site personnel, and staging area on health and safety. 2. If suitably qualified, the Well Control Safety Specialist will also provide advice on tactical FIFI and rescue procedures. 3. Assess hazards associated with the incident and help ensure the safety of on-site personnel. 4. Develop and implement the Site Safety Plan. 5. Ensure safety issues are documented and addressed. 6. Correct unsafe situations and ensure that Company and governmental regulations are enforced. SPECIFIC DUTIES ENSURE all hazards have been properly addressed and that adequate mitigation measures are in place. ASSIST with safety aspects of initial assessment planning. COORDINATE with WWCI, Source Control Unit Leader, and Operations Section Chief to ensure all hazards have been properly addressed and that adequate mitigation measures are in place at all times. PROVIDE assistance in support of response and intervention efforts. 1. Establish exclusion or work zones. 2. Provide hazard assessment and implement mitigation measures. Issue Date Revision No. r Revision Date Prepared By Approved By Page 31 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon011 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.4 — Well Control Safety Specialist ENSURE that all necessary PPE has been provided and appropriate medical facilities are on site during the intervention. DEVELOP, issue, and implement Site Safety Plan. 1. Conduct initial assessment. 2. Oversee continuing intervention operations. 3. Maintain Site Safety Plan and modify as required. ATTEND daily operations and planning meetings on site. INITIATE and maintain accurate documentation of all conversations and actions. Issue Date Revision No. � Revision Date Prepared By Approved By Page 32 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon011 Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.5 — Operations Personnel Primary: Reports to: OPERATIONS PERSONNEL On -Site Operations Personnel Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Perform well intervention activities as directed by Source Control Unit Leader. 2. Provide expertise and project development as incident requires. 3. Specify equipment and resources as required. 4. Assist in coordination of assessment, planning, resource specifications, and implementation of intervention measures. SPECIFIC DUTIES RECEIVE and discuss initial information/incident status with Source Control Unit Leader. PROVIDE assistance in support of response and intervention efforts. PERFORM hazard assessment and mitigation measures. ASSIST in other duties as required or directed. Issue Date Revision No. � Revision Date Prepared By Approved By Page 33 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon CTI Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.6 — Support Contractors Primary: Reports to: SUPPORT CONTRACTORS As Designated Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Direct the individual company's activities under the direction of the Source Control Unit Leader. 2. Specify equipment and resources as required. 3. Coordinate assessment, planning, resource specifications, and implementation of intervention measures. SPECIFIC DUTIES RECEIVE and discuss initial information and incident status with Source Control Unit Leader. PROVIDE advice to Source Control Unit Leader upon initial contact regarding the following: Initial equipment requirements Initial personnel requirements ARRANGE personnel mobilization and advise Source Control Unit Leader of itinerary and ETAs. COORDINATE with Well Control Safety Specialist, Source Control Unit Leader, and Well Control Team Leader to ensure all hazards have been properly addressed before any intervention measures are implemented. PROVIDE assistance in support of response and intervention efforts. Provide hazard assessment and mitigation measures. INITIATE and maintain a log of all conversations and actions. Issue Date Revision No. r Revision Date Prepared By Approved By Page 34 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon CTI Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.7 — Well Control Team Leader Primary: Reports to: WELL CONTROL TEAM LEADER WWCI Team Leader Source Control Unit Leader GENERAL DUTIES AND RESPONSIBILITIES 1. Direct activities of the Well Control Specialist Team and support contractors involved in intervention operations. 2. Direct the activities of the Well Control Engineer (on site). 3. Coordinate assessment, planning, resource specifications, and implementation of intervention measures. SPECIFIC DUTIES TRAVEL to location and report to the On -Site Command Center upon notification of a well control emergency. OBTAIN accurate reports from Source Control Unit Leader, field personnel, and Deputy Incident Commander. ENSURE Source Control Unit Leader has directed on-site personnel in establishing the following: Fire watch and event log FIFI and asset protection Site Safety Plan, including exclusion or work zones On -Site Command Center APPROVE planning and implementation of on-site assessment with Operations and Planning Section Chiefs and Source Control Unit Leader. ACT as leader of all on-site well control operations. Issue Date Revision No. r Revision Date Prepared By Approved By Page 35 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. Marathon CTI Corporation_ Document No.: Well Control Emergency Management Plan Section: 6.0 — On -Site Response Team Roles and Responsibilities Title: 6.7 — Well Control Team Leader DEVELOP initial On -Site Assessment Report in conjunction with the Operations Section Chief and Well Control Engineer. DEVELOP the Capping Plan in conjunction with the Operations and Planning Section Chiefs and Well Control Engineer. MONITOR the Relief Well Team progress. ARRANGE WWCI personnel mobilization and advise Incident Commander of itinerary and ETAs. ESTABLISH Single Point of Contact (SPOC) for Incident Commander during WWCI mobilization. ESTABLISH SPOC for Logistics Section Chief for coordination of equipment mobilization to well site. COORDINATE with the Well Control Safety Specialist, Source Control Unit Leader, and Well Control Engineer to ensure all hazards have been properly addressed before initial assessment or intervention measures are implemented. COORDINATE with Well Control Safety Specialist to ensure all necessary PPE has been provided. ATTEND daily operations and planning meetings on site. INITIATE and maintain accurate documentation of all conversations and actions. ENSURE that accurate field operations documentation is prepared and reported daily. PROVIDE cost estimates/commitments for intervention operations. Issue Date Revision No. r Revision Date Prepared By Approved By Page 36 6/9/2011 R. B. Davis Bryan Beautz Wild Well Control, Inc. "MI Document No.: Well Control Emergency Management Plan Marathon 011 Section: 7.0 — Equipment List for Large -Scale Events Corporation. Title: 7.0 — Equipment List for Large -Scale Events EQUIPMENT LIST FOR LARGE-SCALE EVENTS The following equipment (one each) might be deployed for a large-scale event. Equipment Description Supplier Estimated Dimensions L x W x H Estimated Weight (Ib/kg) Fire Pump: HL -250, 4,000 gpm WWCI 186" x 82" x 91" 17,000/7,711.2 Fire Pump: HL -250, 4,000 gpm WWCI 186" x 82" x 91" 17,000/7,711.2 Fire Pump: 6,000 gpm WWCI 180" x 103" x 91" 16,000/7,257.47 Fire Pump: 6,000 gpm WWCI 180" x 103" x 91" 16,000/7,257.47 20' Response Container WWCI 20' x 8' x 7'6" 20,400/9,253.44 Fuel Tank: 500 gal (Empty) WWCI 8' x 4'8" x 6'5" 2,900/1,315.44 Marine Manifold (New Style) WWCI 12'5" x 7'4" x 5'2" 6,000/2,721.6 Marine Manifold (New Style) WWCI 12'5" x 7'4" x 5'2" 6,000/2,721.6 I Conventional Athey Wagon WWCI 25'6" x 9'8" x 4'6" 19,750/8,958.6 3" Inboard Boom Section WWCI 35'1" x 5'4" x 3'4" 3,640/1,651.1 7' Receiver Box Boom w/Cutter Attachment WWCI 8' x 5' x 3'4" 2,200/997.92 17' Receiver Box Boom WWCI 16'9" x 5'4" x 3'4" 3,825/1,735.02 Rake/Yoke Skid WWCI 10'6" x 7'6" x 5' 6,000/2,721.6 Stinger Basket WWCI 7'7" x 4'6" x 3'9" 2,600/1,179.36 A -Frame Toolbox WWCI 8'6" x 4'6" x 5'10" 6,000/2,721.6 Flip -Up Monitor Sheds WWCI 7'1" x 9'6" x 2'6" 1,500/680.4 Flip -Up Monitor Sheds WWCI 7'1" x 9'6" x 2'6" 1,500/680.4 Air Compressor WWCI 10' x 5'6" x 6'3" 5,000/2,268 Hook Boom WWCI 331" x 66" x 46" 4,500/2,041.16 BTI Abrasive Cutter Equipment Abrasive Cutter BTI 95" x 52" x 71" 6,000/2,721.6 Hose Basket for Abrasive Cutter BTI 99" x 40" x 26" 4,500/2,041.16 Hose Reel BTI 95" x 52" x 61" 4,500/2,041.16 Issue Date Revision No. r Revision Date 6/9/2011 Wild Well Control, Inc. Prepared By Approved By R. B. Davis Bryan Beautz Page 37 1!j/ Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F001— Initial Incident Data INITIAL INCIDENT DATA The recipient of the notification should use this form to record initial reports of emergencies and incidents. Area Location Person Making Notification Date/Time of Notification Type of Emergency/Incident ❑ Spill/Release ❑ Property Damage ❑ Fire/Explosion ❑ Personal Injury/Illness/Fatality ❑ Media Coverage/Public Impact ❑ Government Agency Fine Incident Classification ❑ Level 1 ❑ Level 2 ❑ Level 3 Date/Time of Incident Description of Incident Status/Action Taken Casualties/Fatalities Yes ❑ No ❑ Number of Casualties Number of Fatalities Evacuation Yes ❑ No ❑ All Personnel Evacuated Yes ❑ No ❑ Destinations of Evacuees Assistance Required Agencies Notified Yes ❑ No n Name of Agencies Management Notified (as Appropriate) Major/Serious Incidents Drilling Engineer ❑ District Manager ❑ Operations ❑ Gas Control Logistics Other ❑ ❑ ❑ Person Taking Report Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 38 Wild Well Control, Inc. I1%l9 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F002 — Blowout Response Action/Notification Log BLOWOUT RESPONSE ACTION/NOTIFICATION LOG RESPONSE OPERATIONS Job Title Date/Time Initial Notification Received Initial Notification Received From Date/Time Person Contacted Action Comments Issue Date Revision No. Revision Date Prepared By Approved By Page 39 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F003 — Well Control Data Sheet WELL CONTROL DATA SHEET To Wild Well Control, Inc. From: Phone: +1.281.784.4700 Date: Fax: +1.281.784.4750 Time: EVENT DESCRIPTION ESTIMATED FLOW Gas: (MMscfd) Liquids: (Bpd) Abrasive: ❑ None ❑ Moderate ❑ High Issue Date Revision No. Revision Date Prepared By Approved By Page 40 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. 1!j/ Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F003 — Well Control Data Sheet WELL CONTROL DATA SHEET (WELL CONTROL CONTRACTOR) Current Status r CONTACTS Emergency Response Team Contact Name: Name: Title: Title: Phone: Phone: Fax: Fax: On -Site Contact E-mail: E-mail: Has any equipment or services been ordered out to the well site? Yes ❑ No ❑ Vendor Equipment/Material ETA ilk Comments Additional equipment on separate sheet? Yes ❑ No ❑ Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 41 Wild Well Control, Inc. MarathonOil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F003 — Well Control Data Sheet ADDITIONAL COMMENTS Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 42 Wild Well Control, Inc. I1%l9 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F004 — Drilling and Production Incident Data Checklist DRILLING AND PRODUCTION INCIDENT DATA CHECKLIST Well/Block Name Date Responsibility Name Contact Primary Alternate Recent Situation Data Data Location Comments Well schematics showing best-known situation from ❑ events leading up to the blowout Drilling data and formation evaluation logging reports ❑ (mud, MWD, LWD, and wireline) Blowout flow path ❑ Wellhead configuration ❑ Relevant pressures ❑ Circulation losses since last casing setting point ❑ Status of last cement pumped ❑ Condition of casing at incident ❑ Last casing seat LOT (PIT) test, results ❑ Drilling Situation Comments BOP Stack ❑ BHA ❑ Influx Point and Source ❑ Fluids in Well at Time of Incident ❑ Last Casing Seat LOT (PIT) Test ❑ Production Blowout Situation Comments Production Tree ❑ Casing and Tubing ❑ Location of Packers, Valves, Perforations, ❑ and Obstructions Type of Completion ❑ Damage to Downhole Accessories ❑ Squeeze Jobs Required ❑ Issue Date Revision No. Revision Date Prepared By Approved By Page 43 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I1%l9 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F004 — Drilling and Production Incident Data Checklist Reservoir and Reservoir Fluid Properties Permeability ❑ Productivity Index ❑ Static Reservoir Pressure ❑ Reservoir Temperature ❑ GOR ❑ Reservoir Extension ❑ Molecular Composition of Reservoir Fluids ❑ Minimum Flowing BHP ❑ Other Notes Issue Date Revision No. Revision Date Prepared By Approved By Page 44 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F005 — Technical Data Archive Checklist TECHNICAL DATA ARCHIVE CHECKLIST Well/Block Name Date Relevant rig or structure drawings Responsibility Name Contact Primary ❑ Rig directional drilling structure maps Alternate Survey type Complete wellbore surveys for all wells within a 1 -mile distance Office Archived Data Locatio Relevant rig or structure drawings ❑ Date of survey Well location and directional drilling coordinate system with reference systems ❑ ❑ Rig directional drilling structure maps ❑ Survey type Complete wellbore surveys for all wells within a 1 -mile distance ❑ ❑ Surveyor's name ❑ Grid convergence ❑ Magnetic declination ❑ Wellbore Surveys for Relevant Wells with Details Surface maps showing rig (blowout site) and debris, pipelines, structures, and other surface hazards for a nominal 1 -mile radius Well name/number ❑ Date of survey ❑ Survey interval ❑ Surface tie-in coordinates ❑ Survey type ❑ Survey company ❑ Surveyor's name ❑ Grid convergence ❑ Magnetic declination ❑ Running gear and configuration ❑ Magnetic spacing ❑ BHA ❑ Borehole temperature ❑ Tool face used ❑ QA/QC data ❑ Recent Situation Data Surface maps showing rig (blowout site) and debris, pipelines, structures, and other surface hazards for a nominal 1 -mile radius ❑ Surface map (plan view) of the rig showing average prevailing winds ❑ Surface map showing latest seismic coverage to include any subsurface hazards (such as shallow gas, palaeochannels, or faults) ❑ Well schematics showing best-known situation from events leading up to the blowout ❑ Issue Date Revision No. Revision Date 6/9/2011 Prepared By R.B. Davis Approved By Page Bryan Beautz 45 Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F005 — Technical Data Archive Checklist Drilling ` _ BOP Stack ❑ Wellhead Configuration ❑ Casing Program ❑ BHA ❑ Open -Hole Section ❑ Influx Point and Source ❑ Blowout Flow Path ❑ Relevant Pressures ❑ Fluids in Well at Incident Time ❑ Production ` _ Production Tree ❑ Wellhead Configuration ❑ Casing ❑ Relevant Pressures ❑ Blowout Flow Path ❑ Tubing ❑ Location of Packers, Valves, ❑ Perforations, and Obstructions Damage to Downhole ❑ Accessories Type of Completion ❑ Geological stratigraphic cross section to include pore pressures, fracture gradients, overburden, and temperature ❑ profile; mark all possible drilling hazards Drilling records from the blowout and offset wells, including detailed record of drilling and production operations ❑ immediately prior to the blowout Drawdown production tests or DST if available ❑ Drilling data and formation evaluation logging reports (mud, MWD, LWD, and wireline) ❑ Status of last cement pumped ❑ Condition of the casing at the time of the incident ❑ Performance of last casing seat LOT (PIT) and use of squeeze jobs ❑ Circulation losses encountered since the last casing setting point ❑ Reservoir and Reservoir Fluid Properties Productivity Index ❑ Static Reservoir Pressure ❑ Reservoir Temperature ❑ GOR ❑ Reservoir Extension ❑ Molecular Composition of Fluids ❑ Molecular Composition of Reservoir Fluids ❑ Permeability ❑ Minimum Flowing BHP ❑ Issue Date Revision No. Revision Date 6/9/2011 Prepared By R.B. Davis Approved By Page Bryan Beautz 46 Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F006 — Personnel Debriefing Checklist PERSONNEL DEBRIEFING CHECKLIST Well/Block Name Date Briefing Question Comments 4 Was there an indication that any BOPs or VALVES ❑ Yes failed to actuate when energized? ❑ No Any indication of a WASHOUT in the pipe string? Yes ❑ No Any unusual PRESSURE FLUCTUATIONS noticed? ❑ Yes ❑ No Any OTHER OCCURRENCES that seem out of the ❑ Yes ordinary prior to the incident? Describe. ❑ No Were there any SAFETY VALVES or INSIDE BOPs in the pipe string? (If yes, what is the status of these Yes valves?) ❑ No Are there any NIPPLES/FLOATS/PLUGS in the ❑ Yes string? (If yes, describe status.) ❑ No What was the last recorded SIDPP? What was the last recorded SICP? What was the MUD WEIGHT (in/out) at the time of the incident? What was the last recorded PIT GAIN? What EQUIPMENT is CONNECTED to the BOP stack/wellhead (pump lines, wireline lubricator, and coiled tubing injector)? What is the status of all RAMS and VALVES on the BOP stack/wellhead (open, closed, damaged, locked)? Issue Date Revision No. Revision Date 6/9/2011 Prepared By R.B. Davis Approved By Bryan Beautz Page 47 Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: FOO6 — Personnel Debriefing Checklist Well/Block Name Date Describe the WELL CONFIGURATION and OPERATION at the time of the incident (drilling, fishing, running casing, cementing, and workover/completion operations). REVIEW STEP-BY-STEP what each person was doing two hours prior to, during, and after the incident. Any additional data Issue Date Revision No. Revision Date Prepared By Approved By Page 48 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix A — Data Acquisition Forms Title: F007 — Site Survey Checklist SITE SURVEY CHECKLIST Well/Block Name Date Responsibility Name Contact Primary Alternate GENERAL SITUATION 1. Determine which wells are out of control and whether they are on fire. 2. Determine whether there is easy access to the wellheads. 3. Determine amount of debris that must be removed. 4. Determine potential for erosion. 5. Determine predominant wind speed and direction. 6. Provide heat radiation estimates (or measurements). 7. Determine other obvious or potential hazards. EQUIPMENT STATUS 1. Determine general rig damage. 2. Determine condition of wellhead/conductor pipe (vertical, structurally competent). 3. Determine whether there is any significant damage to surface equipment. 4. Determine whether surface equipment is capable of being shut in. 5. Predict additional structural damage or secondary involvement due to fire. SPILL STATUS 1. Determine blowout fluid composition (percentage salt water, oil, gas, condensate, sand). 2. Determine size of the oil column, gas/condensate cloud, or fire. 3. Determine blowout fluid exit point and description of flow (vertical, obstructed, through valve, through drill pipe). 4. Determine whether poisonous gases are present at dangerous levels. 5. Determine stability of flow (remaining constant, increasing, decreasing, changing composition). 6. Provide pollution/spill summary. Issue Date Revision No. Revision Date Prepared By Approved By Page 49 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. Marathon 011 Corporation. Document No.: Section: Title: Well Control Emergency Management Plan Appendix B — National Incident Management System Abbreviations Appendix B — National Incident Management System Abbreviations APPENDIX B - NATIONAL INCIDENT MANAGEMENT SYSTEM ABBREVIATIONS Abbreviation Definition CIKR Critical Infrastructure and Key Resources CPG Comprehensive Preparedness Guide DHS Department of Homeland Security DOC Department Operations Center SMAC Emergency Management Assistance Compact EMS Emergency Medical Services EMT Emergency Medical Technician EOC Emergency Operations Center HSPD-5 Homeland Security Presidential Drive 5, "Management of Domestic Incidents" HSPD-7 Homeland Security Presidential Drive 7, "Critical Infrastructure Identification, Prioritization, and Protection" HSPD-8 Homeland Security Presidential Directive 8, "National Preparedness" IAP Incident Action Plan IC Incident Commander ICP Incident Command Post ICS Incident Command System IMT Incident Management Team IPS Integrated Planning System JIC Joint Information Center JIS Joint Information System MAC Multiagency Coordination MACS Multiagency Coordination System NFPA National Fire Protection Association NGO Nongovernmental Organization NIC National Integration Center NIMS National Incident Management System NIPP National Infrastructure Protection Plan NRF National Response Framework NSPD National Security Presidential Directive SDO Standards Development Organization TCL Target Capabilities List UC Unified Command Issue Date Revision No. Revision Date Prepared By Approved By Page 50 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix C — OiI and Gas Abbreviations Title: Appendix C — OiI and Gas Abbreviations APPENDIX C — OIL AND GAS ABBREVIATIONS Abbreviation Definition AFE Authorization for Expenditure bbl Barrel (42 US Gallons) BHA Bottom -Hole Assembly BHP Bottom -Hole Pressure BOP Blowout Preventer bpm Barrels per minute BPV Back -Pressure Valve BSR Blind Shear Ram C&K Choke and Kill CFM Cubic Feet per Minute CMR Crisis Management Room CMT Crisis Management Team CP Command Post csg Casing DC Drill Collars DP Drill Pipe ECD Equivalent Circulating Density EMS Electromagnetic Survey EMW Equivalent Mud Weight ERC Emergency Response Center ERO Emergency Response Organization ESD Emergency Shutdown ETA Estimated Time of Arrival FIFI Firefighting FIT Formation Integrity Test FRC Fire -Resistant Clothing ft Foot, feet gpm Gallons per minute GOR Gas/Oil Ratio GR Grade HP Horsepower HR Human Resources HWDP Heavyweight Drill Pipe ID Inside Diameter IADC International Association of Drilling Contractors IAP Intervention Action Plan Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 51 Wild Well Control, Inc. /Mil Marathon 011 Corporation. ICO ICS IRS kh KOP LCM LEL LOT LWD Mscf/d mD-ft MD MUX MWD MWe O.D. OBM ORT OSCP OSD PA P&A PIT POOH PPE Ppg ppm psi PWD RU SBM SCFD SICP SIDPP Sim0ps SPDC tbg TD TVD Document No.: Well Control Emergency Management Plan Section: Appendix C — OiI and Gas Abbreviations Title: Appendix C — OiI and Gas Abbreviations Incident Command Organization Incident Command System Incident Response Structure Formation flow capacity (also mD-ft, where mD = millidarcy) Kickoff Point Lost -Circulation Material Lower Explosive Limit Leakoff Test Logging While Drilling Thousand Cubic Feet Per Day See kh Measured Depth Multiplex Measurements While Drilling Megawatt electrical Outside Diameter Oil -Based Mud On -Site Response Team Oil Spill Contingency Plan Oil Spill Detection Public Affairs Plug and Abandon Pressure Integrity Test Pulling Out of Hole Personal Protective Equipment Pounds per gallon Parts per million Pounds per square inch Pressure While Drilling Rig Up Synthetic -Based Mud Standard Cubic Feet per Day Shut -In Casing Pressure Shut -In Drill Pipe Pressure Simultaneous Operations Single Point of Contact Tubing Total Depth True Vertical Depth Issue Date Revision No. Revision Date Prepared By Approved By Page 52 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix C — OiI and Gas Abbreviations Title: Appendix C — OiI and Gas Abbreviations UGBO Underground Blowout UHF Ultrahigh Frequency USI Ultrasonic Imaging VHF Very -High Frequency VIV Vortex -Induced Vibration WCE Well Control Engineer WCERO Well Control Emergency Response Organization WCERP Well Control Emergency Response Plan WCERT Well Control Emergency Response Team WOO Wait on Orders WP Working Pressure wt Weight WWCI Wild Well Control, Inc. Issue Date Revision No. Revision Date Prepared By Approved By Page 53 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations APPENDIX D - H2S OPERATIONS Hydrogen sulfide (also known as H2S, sour gas, poison gas) is a toxic, corrosive, explosive, and colorless gas found in many oil and gas reservoirs throughout the world. H2S is easily perceptible at concentrations well below 1 part per million (ppm) in air. However, when the concentration of H2S increases above 100 ppm, H2S paralyzes the olfactory nerve and the smell is imperceptible. This means that the gas can be present at lethal concentrations with no perceivable odor. Prolonged exposure to lower concentrations can also result in similar olfactory fatigue. The unusual olfactory -fatigue property associated with H2S makes it extremely dangerous to rely only on the sense of smell to warn of H2S presence. After a period of exposure, the smell of H2S might no longer be detectable; the higher the concentration, the shorter the period. TOXICITY OF H2S AND COMMON EFFECTS OF EXPOSURE Prolonged exposures to H2S can be hazardous, even at low levels. The legal limit for working in H2S atmospheres in the US is less than 10 ppm time -weighted average (TWA). This limit applies to an 8 -hour workday. The table below outlines the effects of exposure to different concentrations of H2S for various periods of time. This information should be used as a guideline, as the effects of exposure on individuals vary. Table D.1— Common Effects of H2S Exposure Level of Effect H2S Concentration (ppm in Air) Exposure Time (Minutes) Common Symptoms/Features Odor Threshold * 0.01 1 Characteristic smell of rotten eggs (subjective) Irritation 10 360 Redness of eyes; nose and throat irritation Odor threshold varies with the individual from as low as 0.0005 ppm to as high as 0.15 ppm. Issue Date Revision No. Revision Date Prepared By Approved By Page 54 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. ■�r4�) Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations Level of Effect H2S Concentration (ppm in Air) Exposure Time (Minutes) Common Symptoms/Features Dizziness Headache Moderate 10-50 ppm Nausea/vomiting Difficulty breathing Vision 50 60 Acute conjunctivitis (gas eye) Sense of 150 2-15 Loss of sense of smell Smell (subjective) 150 60 Respiratory distress Serious Injury 500 30 Signs of nervous system injury, convulsions (in nearly fatal 700 15 cases) 500 60 ** Immediate unconsciousness Fatal 700 30 Respiratory distress 900 15 At the fatal level, H2S is rapidly absorbed into the bloodstream, overloading the body's natural capacity to process the absorbed mass. Consequently, H2S affects the respiratory nerve center, which causes breathing to stop. At serious -injury levels (such as 500 ppm for 30 minutes), the exposed person will have serious respiratory distress and is at risk of dying if he does not receive immediate artificial respiration and emergency medical attention. Concentrations in excess of 10 ppm should be considered a health hazard. Exposure without proper gear should be avoided. In order to comply with the exposure threshold limit value (TLV) of 10 ppm in an 8 -hour workday, living quarters for the emergency response team should be upwind and of sufficient distance from the blowout such that the average ground level concentrations do not exceed 1 ppm. (1 ppm = 1 cm3/m3 = 1.4 mg H2S per cubic meter of air at standard temperature and pressure.) 15 ppm is the short-term exposure limit (STEL) as published by the American Conference of Government Industrial Hygienists (ACGIH) in 1984. The STEL is the maximum ** A person exposed to 900 ppm H2S for 15 minutes, 700 ppm for 30 minutes, or 500 ppm for 60 minutes will die. Issue Date Revision No. Revision Date Prepared By Approved By Page 55 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations concentration to which a worker might be exposed for a period of up to 15 minutes without harmful effects. No more than four excursions above the TLV should be permitted in any one day. At least 60 minutes between exposure periods and the daily TWA must not exceed the TLV. WELL CONTROL Well control procedures are basically the same in the presence of H2S, but the added risk of personnel exposure has an impact on the decision-making process for handling a given well control situation. Extra consideration should be given to items such as remote kill lines, remote adjustable choke control panels and remote BOP controls. Any influx into the wellbore (kick) should be assumed to contain H2S. The size of the influx, amount of underbalance, formation character, weather conditions, and other factors should be considered when deciding to circulate out or pump away the influx. If the decision is made to circulate out the kick, clear the rig floor and shaker/choke/gas buster area of all unnecessary personnel, and take the following precautions: Rope off the rig substructure, BOP, choke line, choke manifold, and mud return areas, and identify as a restricted area. No one may enter these areas without breathing apparatus, H2S monitor, and specific superintendent's approval. Continuously monitor the H2S concentration in the mud returns. The Drilling Foreman will alert affected downwind facilities as identified in the workover program. The Drilling Foreman will implement any additional precautions he deems prudent. When circulating, all personnel involved in the well control operation will mask up at least 30 minutes prior to bottoms up. The flow from the choke should be diverted through the gas buster, and the gas should be flared. The mud stream will return to the active system, where any remaining gas can be removed by the degasser and the use of an H2S scavenger. If the decision is made to pump away the influx, a procedure should be furnished by the engineer based on actual conditions at the time. This will generally involve pumping down the tubing or work string at a slow rate while bullheading on the annulus with the same mud weight as in the hole, or with kill -weight mud if weight -up can be accomplished quickly. When drill pipe and casing pressure are equal, it can be assumed that the influx is pumped away (an additional volume of mud should be pumped for Issue Date Revision No. Revision Date Prepared By Approved By Page 56 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations safety). Kill -weight mud can then be circulated in the well to hold the appropriate back pressure on the choke. Stripping operations in the presence of H2S are particularly hazardous due to increased stress cracking at low temperatures and high stress levels. If an influx occurs while out of the hole or off bottom, pumping away the influx should be considered prior to initiating stripping operations. Heavy trip -gas concentrations should be diverted through the gas buster and flared, if possible. H2S TRAINING REQUIREMENTS The level of orientation or training required will vary, depending upon the role each individual is expected to take in the event of an H2S release. The following should be considered as minimum training requirements. Table D.2 — Minimum H2S Training Requirements Personnel Minimum H2S Training Requirements Occasional visitors — never (or rarely) on the rig floor Able to identify H2S alarm Able to identify wind direction Know to evacuate to the upwind Safe Briefing Area immediately upon hearing the alarm Visitors who might work on the rig Able to don and use breathing apparatus Able to identify H2S alarm Able to identify wind direction Know to evacuate to the upwind Safe Briefing Area immediately upon hearing the alarm Rig crew Able to don and use breathing apparatus Able to identify H2S alarm Able to identify wind direction Know how to perform the tasks assigned to them, according to the rig's H2S drill Issue Date Revision No. Revision Date Prepared By Approved By Page 57 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations In addition to these specific training requirements, the following general requirements should be followed: The H2S Safety Representative should immediately begin training crews, ensuring that everyone on the rig site has received an H2S orientation. Records of H2S safety training and orientation are to be recorded in the H2S safety -training file. H2S drills should be held as often as deemed necessary by the Superintendent and the H2S Safety Representative, until satisfactory performance is obtained. Thereafter, safety drills should continue to be conducted once per week per crew. These weekly drills will be documented in the IADC morning report book. The ORT Leader will designate two Safe Briefing Areas such that at least one will always be upwind of the wellbore under prevailing wind conditions. The primary area will be near the Contractors' offices (generally upwind). This upwind location will be a gathering point for all drills. The ORT Leader will ensure that a sign is posted notifying all visitors to report to the office to verify that they receive or already have completed H2S orientation. The Superintendent can delegate these duties, but he remains responsible for their implementation. SAFETY IN AN H2S-EXPOSED AREA It is important for personnel in an H2S-exposed area to have appropriate safety equipment. Additionally, there are recommended actions that can be taken during evacuation and rescue to protect exposed personnel from further danger. Safety Equipment Safety equipment should be available in the Safe Briefing Area during times when H2S is present in the atmosphere at the rig. The primary Safe Briefing Area will be near the Contractors' offices. H2S safety equipment should include the following items, at a minimum: Alarm sensor Alarm controller Visual and audible alarms Breathing apparatus Issue Date Revision No. Revision Date Prepared By Approved By Page 58 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations If the H2S concentration is or might become greater than 10 ppm, a self-contained breathing apparatus must be worn. Wind socks Breathing -air compressor Cascade -type breathing system When working in an H2S environment for a prolonged period of time, a cascade air - breathing apparatus must be used. Manual -type H2S concentration sensors Chalkboard or whiteboard and markers When not in use, this equipment can be stored in the adjacent offices, H2S safety trailer, or other location as deemed by the Superintendent, as long as it is readily available. Evacuation and Rescue During evacuation, the following actions can help to protect personnel from further harm: 1. Hold your breath. 2. Put on an escape SCL. 3. Evacuate to safe evacuation/meeting area (upwind). 4. Do not panic. Rescuing a person overcome by H2S exposure can put the rescuer in danger. In order to prevent further harm, the rescuer must adhere strictly to the following procedure: 1. Put on self-contained breathing apparatus (30 minutes). 2. Have second man as backup with self-contained breathing apparatus (30 minutes) available. 3. Bring casualty back to Safe Briefing Area. 4. Immediately apply mouth-to-mouth artificial respiration, followed as soon as possible by resuscitation. Issue Date Revision No. Revision Date Prepared By Approved By Page 59 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations 5. Summon expert medical assistance as soon as possible. 6. Do not panic. BOP EQUIPMENT ALERT: H2S can have an adverse effect on well control equipment. With assistance from the Tool Pusher or Senior Contractor Representative, the Drilling Foreman will inspect and ensure that BOP and surface equipment are of metallurgy suitable for H2S service, meeting the standards set forth in NACE Standard MR -01-75. This inspection and verification should be completed well in advance of nipple -up so that any changes can be made if necessary. The Drilling Foreman and well site mud engineer should also confirm that an H25 scavenger (zinc oxide or an equivalent scavenger) is available, with sufficient quantity on location to treat the entire mud system with 2 Ib/bbl, or as required. OPERATING CONDITIONS (ALARM LEVELS) The Drilling Foreman, with assistance from the H2S Safety Representative, should ensure the following on operations where the presence of H25 is possible: All safety equipment for H2S operations is in place as required prior to starting operations. Sensors and warning devices are rigged up and working properly prior to starting operations. Supplied -air (cascade) manifold gauges are checked for proper pressure and air lines are checked for proper operation every tour (at every crew change). This is documented in the IADC book. All personnel are trained and fully briefed on H2S procedures and prepared for handling H2S emergencies. No one should work alone. All personnel must work in pairs (the "buddy system"). The Drilling Foreman is responsible for taking every practical precaution to maintain a safe working environment while remedial actions are being taken to reduce the amount of H2S present at the surface. When working on a well where H2S is possible, the rig will conduct operations based on the following classifications of H25 risk (where "[H25]" Issue Date Revision No. Revision Date Prepared By Approved By Page 60 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations using square brackets refers to H2S concentration, usually measured in ppm [parts per million]): Table D.3 — H2S Alert Levels Alert Level H2S Concentration [H2S] Comments Level 0 0 ppm Normal operations Level 1 0-10 ppm Normal operations, with increased alertness, preparing for next level. Restricted access to affected areas. Level 2 10-100 ppm (but not on drill floor) Restricted access and breathing apparatus required in affected areas, where [H2S] > 10 ppm. Nonessential personnel removed from rig. Immediate action taken to reduce mud H2S levels. First alarm at 10 ppm, high alarm at 20 ppm Level 3 10-100 ppm (on the drill floor) Approaching an emergency situation First alarm at 10 ppm, high alarm at 20 ppm H2S Emergency > 100 ppm Actions taken to reduce H2S concentrations have failed and an emergency situation has been reached. (This is not necessarily an uncontrolled release, but would include uncontrolled releases.) LEVEL 0: [H2S] = 0, NORMAL OPERATIONS IN POTENTIAL H2S ZONES This is the base level, in effect at all times on wells where H2S is possible. The following precautions should be maintained, even when no H2S has been detected: All H2S detection equipment will be function tested daily and documented in the IADC book. H2S detection equipment will be calibrated weekly and documented in the rig PM file. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 61 Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations All breathing apparatus, detectors, alarms, and other safety equipment will be in place and ready for immediate use. Two Safe Briefing Areas have been marked out and identified, and the entrance sign has been posted. H2S drills will continue at a minimum of once per week per crew and will be documented in the IADC daily report form. Orientation and training on breathing apparatus will continue so that new arrivals and visitors are covered. (See Table D.2.) LEVEL 1: [H2S] = 0-10 PPM, ACCEPTABLE AMOUNT OF H2S PRESENT Level 1 begins whenever H2S is detected anywhere on the rig. Typically, this will be at the shale shaker, when safe concentrations (less than 10 ppm) of H2S are being released to the atmosphere. Although this is a safe H2S concentration, everyone must be alert to the fact that the H2S concentration could increase at any time. Upon reaching Level 1 conditions, the Drilling Foreman will ensure the following actions are taken: Verify all of the previous H2S level precautions are already in place. The area around the shale shaker and the rig cellar will be declared restricted areas. No one may approach these areas without the following: — Ready access to breathing apparatus — Continuous awareness of current H2S concentration by means of a personal H2S monitor giving continuous readouts — Continuous observation by a standby man who also has immediate access to breathing apparatus (the "buddy system") Appropriately rated (explosion -proof) bug blowers will be positioned to provide adequate ventilation to H2S contaminated areas and the rig floor. The Tool Pusher or designated H2S Safety Representative will conduct an initial H2S safety meeting with each crew. H2S safety will be discussed at a brief toolbox safety meeting at every shift change. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 62 Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations The H2S concentration in the mud is checked a minimum of every 24 hours, or more frequently at the Drilling Foreman's discretion. The Garret Gas Train Kit will be used for this determination. Identify possible courses of action to take should the H2S concentration increase to higher levels (such as stopping circulation or treating mud with H2S scavenger). Take appropriate actions to maintain H2S levels below 10 ppm. The objective is to minimize the number of times the H2S alarms sound. If the 10 ppm H2S alarm becomes excessive, it could contribute to complacency and lose its desired effect as a warning. LEVEL 2: [H2S] = 10-100 PPM (ANYWHERE BUT ON THE RIG FLOOR) Company policy requires breathing apparatus to be worn when working in an atmospheric H2S concentration higher than 10 ppm. Therefore, every practical precaution will be taken to either reduce atmospheric H2S levels to less than 10 ppm, or to declare "off limits" those areas with an atmospheric H2S concentration higher than 10 ppm. Upon reaching Level 2 conditions, the Drilling Foreman will ensure the following actions are taken: Verify all of the previous H2S level precautions are already in place. The rig crew will respond to the low level ([H25] >10 ppm) alarm with their H2S drill (as previously trained). The Drilling Foreman, assisted by the senior contractor representative, will identify the source of the H2S, and respond accordingly. For example, if the H2S release is confined to the shale shaker area only, that is not as critical a situation as [H2S] > 10 on the drill floor. Handheld H2S monitors will be used to measure atmospheric H2S concentrations continuously. The Drilling Foreman will implement appropriate procedures to reduce atmospheric H2S levels in the affected areas (such as treating mud with H2S scavenger, increasing overbalance, controlling ROP, or increasing ventilation to area). Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 63 Wild Well Control, Inc. Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations The H2S concentration in the mud will be checked every 4 hours, or as directed by the Drilling Foreman. The Garret Gas Train Kit will be used for this determination. Breathing apparatus must be worn when entering an area with atmospheric H2S concentration higher than 10 ppm. No one may remain in an area with [I -12S] > 10 ppm unless their presence is absolutely necessary to regain a safe working environment. A strict buddy system will be enforced throughout the rig and immediately downwind of the rig. The rig substructure, shale shaker area, and any other areas with [H2S] > 10 ppm will be roped off and identified as a restricted area. No one may enter these areas without specific Drilling Foreman approval. LEVEL 3: [H2S] = 10-100 PPM (ON THE DRILL FLOOR) Since the rig floor is a critical work area and cannot be easily evacuated, H2S concentrations higher than 10 ppm are far more critical here than in more remote areas of the rig. Upon reaching Level 3 conditions, the Drilling Foreman will ensure the following actions are taken: Verify all of the previous H2S level precautions are already in place. Upon initial low alarm ([H2S] > 10 ppm), everyone on the rig floor will either evacuate or mask up, per the established H2S drill. No one may remain on the rig floor unless his or her presence is absolutely necessary to regain a safe working environment. An H2S monitor will be placed on the rig floor to provide continuous atmospheric H2S concentrations. The Drilling Foreman will use his discretion whether to circulate through the choke or through the shakers. The Drilling Foreman will immediately implement appropriate procedures to reduce H2S concentration in the mud (such as stopping circulation, treating mud with H2S scavenger, increasing overbalance, or increasing ventilation). Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 64 Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D – H2S Operations Title: Appendix D – H2S Operations Two men will be placed at each entrance to the location to turn back nonessential personnel and to direct essential personnel to the appropriate Safe Briefing Area. These teams will be equipped with breathing apparatus and H2S monitors. The Drilling Foreman will discuss extended -term procedures to reduce H2S levels with his superintendent or immediate supervisor. H2S EMERGENCY: [H2S] > 100 PPM An H2S Emergency is defined as having lost the capability to control the amount of H2S being released at the well site. Under this condition, the Drilling Foreman must identify the problem and take immediate corrective action to provide an adequate level of safety for the men working on the rig. Upon reaching an H2S Emergency condition, the Drilling Foreman will ensure the following actions are taken: Immediately implement a strict buddy system, in which no one is to ever do anything alone. Every task must be done in pairs. The Drilling Foreman will notify the Superintendent or his immediate supervisor of the emergency. The Superintendent will decide whether or not to activate further emergency -response measures. Communicate to the Superintendent what outside resources the rig needs or might need in the immediate future (such as gas monitors, gas -monitoring teams, increased breathing -apparatus refill capacity, mobile radios, or walkie-talkies). The Superintendent will contact the outside resources needed to assist the rig. Establish a CP, typically in the rig -site office, equipped with the following: — Telephone and radio — Continuous contact with the workover superintendent — Flare gun and one box of flare gun shells — Fluorescent orange vest to identify the On -Scene Commander — Walkie-talkies to communicate with the Safe Briefing Area and work parties throughout the rig — Continuous manning by either a foreman or a highly reliable, experienced, and competent individual, plus at least two pairs of runners Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 65 Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D – H2S Operations Title: Appendix D – H2S Operations Man the primary Safe Briefing Area, equipped as specified. Establish and mark off a "Hot Zone" where H2S concentration is greater than 10 ppm. This is done by assigning pairs of individuals who are masked up and equipped with a continuous H2S monitor to measure H2S concentrations throughout the location. Maintain at least one two-man team to continuously check that the "Hot Zone" is adequately identified. (Winds can vary and change conditions rapidly.) Assign an individual to gather all vehicles and park them in a safe upwind location, parked facing their escape route, with the motor off and with the keys in the ignition. Alert the rig camp of the emergency, and to stand by for further instructions. Under emergency conditions, it might be difficult for one man to directly supervise more than four people. Organize small work teams of at least two, but usually not more than five, men. Assign one man as leader of every work team. — Each work team will have an individual assigned to check the air supply of all team members and to monitor H2S levels using a continuous monitor. This should be his primary responsibility: he should not be assigned other duties that could interfere with this vital safety function. — All work is assigned to individual teams at the Safe Briefing Area. — The Safe Briefing Area Commander keeps a written log of all assigned tasks. — Each work team is assigned only one task. — An estimated time of completion is identified for each assigned task. — Each work team reports back to the Safe Briefing Area immediately upon completion of their assigned task, allowing the Safe Briefing Area Commander to be fully up-to-date on the progress being made. — If a work team has not completed their task by their estimated time of completion, they will report back to the Safe Briefing Area (or send a pair of runners to report in). Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 66 Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations SPECIAL OPERATIONS Well Testing A well test might be included in the workover operations. The following conditions should apply any time a well test is done in a potential H2S zone: Special well test procedures that outline the contingency planning for an H2S emergency should be written prior to the testing operation. These procedures should be thoroughly discussed with all personnel involved in the well test operation. Special provisions required by any local governmental authority should also be incorporated into the test procedure. Prior to initiation of the test, special safety meetings must be conducted by the H2S Safety Representative for all personnel who will participate. This will require at least two meetings to include both crews. Special emphasis should be placed on use of personal safety equipment, evacuation to the Safe Briefing Area, rescue operations, and first-aid procedures. The test should be conducted with the minimum number of personnel on the rig floor and in the vicinity of the lines and test equipment to safely conduct the test. Other personnel should be assigned duties in an upwind area away from the cellar, rig floor, lines, and test equipment. Downhole test tools and surface equipment should be suitable for H2S service and supplied by a reputable testing contractor. All items from the test head (or tree) to the choke manifold and well test equipment should be furnished by the well test company. During the test, the use of H2S portable detection equipment will be intensified. All produced gases must be burned through a flare system equipped with a continuous pilot and an automatic igniter. At least one backup ignition device must be provided. Produced fluids that are stored must also be vented to the flare pit. If well is within 5 km of a contact point, portable H2S monitoring must be done downwind of the flare pit in case the flare cannot be kept burning continuously. Two people, both masked up, should conduct this monitoring. There should be two flare pits when the gas is to be flared. The primary pit is for flaring, and the secondary pit is for emergency well control operations only, such as when the gas buster cannot handle pressure or volume, or for diverting an uncontrolled flow. The testing of all wells should be initiated only during daylight hours. Issue Date Revision No. 1 Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 67 Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix D — H2S Operations Title: Appendix D — H2S Operations Lost Circulation Lost circulation becomes a serious problem when it occurs with a formation containing open H2S, especially if that formation has a minimal overbalance. As with well control, the presence of H2S does not change how the situation is handled, rather it impacts the decision-making process on which options to take. A more conservative approach is warranted, with more attention given to preventative maintenance. If the hole will not stand full, it is very important to keep the hole filled with mud, water, or diesel and record the exact volume pumped so that an accurate hydrostatic head can be calculated if the well becomes static. LCM materials should be kept on hand so that the situation can be dealt with in a timely manner. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 68 Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition WIP APPENDIX E - VOLUNTARY WELL IGNITION This appendix discusses considerations for the development and execution of a Well Ignition Plan (WIP). The API RP 68, Recommended Practice for Oil and Gas Well Servicing and Workover Operations Involving Hydrogen Sulfide, indicates that a WIP should be written for wells containing dangerous H2S levels. Development of a formal WIP for all well types should be considered based on the risk level of the well, its location, and the environment. For the purposes of this document, the use of "well" is generic and refers to a well, pipe, pipeline, equipment, and any other component that could leak and require the consideration of possible voluntary ignition. This appendix contains information about the following topics: WIP Well Ignition Roles and Responsibilities Preliminary Actions in Anticipation of Possible Ignition Well Ignition Criteria/Decision Map Well Ignition Procedure Well Ignition Field Checklist The WIP can be written as a standalone document or included in the WCEMP. In the absence of a formal plan, organizations should at least consider that there might be circumstances requiring the ignition of a blowout and the need to take appropriate actions. When considering voluntary ignition during well planning and operations, examine the following topics and effects: Risk factors contained in the well ignition plan or WCERP Ignition of nontoxic blowouts Ignition of H2S wells Ignition methods Effects of radiant heat and other postignition factors Issue Date Revision No. Revision Date Prepared By Approved By Page 69 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition After consideration of the factors in the individual case, it might be found that it is safest and in the best interest to set the well on fire. An example of a case where implementation of voluntary ignition is likely beneficial is when a large concentration of H2S is released to atmosphere close to residential areas or highly traveled roads. The typical WIP should include the following elements: Preliminary actions in response to the emergency and in preparation for possible well ignition Clear and timely consideration of the issues that support a decision to ignite the well Clear identification of the persons or positions authorized to carry out ignition Descriptions of the actions to be taken prior to ignition, such as establishing the perimeter of the dispersing vapor cloud, setting up an appropriate exclusion zone, and verifying evacuation Description of availability and location of ignition equipment Actual ignition procedure and cautions Consideration of the effects and actions to be taken following the ignition WELL IGNITION ROLES AND RESPONSIBILITIES When considering the decision of igniting a well, the roles and responsibilities for taking that action must be clearly defined and understood. Since time is often a critical factor in responding to the protection of persons, property, and the environment, the final responsibility for deciding to ignite a well rests on the most senior Company person on site at the event. That person is thought to have the closest perspective to the situation, data, and impacts. If time permits, this person should take every opportunity to consult with Well Control Engineers, the ORT, and Marathon ICS, as well as other personnel and resources internal or external to the Company. A generic roles -and -responsibilities relationship is illustrated in Figure E.1. Issue Date Revision No. Revision Date Prepared By Approved By Page 70 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. f. Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition External/Regulatory Agencies WCERT Deputy Incident Commander On -Site Company Representative WWCI Engineering Errtergency Well Coit of Undenvey r f Receive Notification of Event Evaluate Hazards to Persons, P roperty, and E nvironm ant i �. Commate and Performrform Liaison RolletoWCERr Consult vuth Well Control Experts Q r‘ rl Nobly Agencies, es, ass appropriate Make Decisionto---' Ig-rlte Well r Perrorrn !^•fell Ignition Protetture i CommunicateStau Status and Progress h 1 Continue Implementation of I° WCERP Response PI- PIM ' ` Figure E.1— Well Ignition Roles and Responsibilities Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 Wild Well Control, Inc. R.B. Davis Bryan Beautz 71 Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition PRELIMINARY ACTIONS IN ANTICIPATION OF POSSIBLE IGNITION The preliminary actions to be taken in the event of a well control incident are typically addressed in detail in the Company's Emergency Response Plan, WCEMP, the Site Safety Plan (SSP), or other documents. More specific and detailed information regarding H2S Operations can be found in industry resources as well as API RP 68. The Company representative on location, with assistance from the Site Safety Specialist, should verify the following where the presence of H2S is possible or probable: All safety equipment for H2S operations is in place as required prior to starting operations. Sensors and warning devices are rigged up and properly working prior to starting operations. Supplied -air (cascade) manifold gauges are checked for proper pressure and air lines are checked for proper operation every tour (at every crew change). This is documented in the IADC book. All personnel are trained and fully briefed on H2S procedures and prepared for handling H2S emergencies. These are general guidelines for the monitoring of operating conditions, and preliminary actions to be taken in the event of a well control incident that might require ignition. The Company representative on location is responsible to take every practical precaution to maintain a safe working environment while remedial actions are being taken to reduce the amount of H2S present at the surface. ADDITIONAL ACTIONS TO BE TAKEN IN AN H2S EMERGENCY: [H2S] > 100 PPM An H2S Emergency is defined as having lost the capability to control the amount of H2S being released at the well site. Under this condition, the Company representative on location must identify the problem and take immediate corrective action to provide an adequate level of safety for the men working on the rig. Issue Date Revision No. Revision Date Prepared By Approved By Page 72 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Upon reaching an H2S Emergency condition, the Company representative on location will ensure the following actions are taken: Immediately implement a strict buddy system, in which no one is to ever do anything alone. Every task must be done in pairs. When a blowout is detected or has occurred, all ignition sources should be isolated, if possible. The Company representative on location will notify the superintendent or his immediate supervisor of the emergency. The superintendent will decide whether or not to activate further emergency -response measures. Evacuate the area, as appropriate, due to concentration of toxic or flammable materials as well as when the well control procedures are not progressing as expected. Isolate and deny entry into the area, including all adjacent communities and roadways. Communicate to the superintendent what outside resources the rig needs or might need in the immediate future (such as gas monitors, gas -monitoring teams, increased breathing -apparatus refill capacity, mobile radios, or walkie-talkies). The superintendent will contact the outside resources needed to assist the rig. Establish a CP, typically in the Company rig -site office, equipped with the following: — Telephone and radio — Flare gun and one box of flare gun shells — Fluorescent orange vest to identify the Company representative on location — Walkie-talkies to communicate with the Safe Briefing Area and work parties throughout the rig — Continuous manning by either a Company representative on location, or a highly reliable, experienced, and competent individual, plus at least two pairs of runners Man the primary Safe Briefing Area, equipped as specified. Issue Date Revision No. Revision Date Prepared By Approved By Page 73 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Establish and mark off a "Hot Zone" where H2S concentration is greater than 10 ppm. This is done by assigning pairs of individuals, masked up and equipped with a continuous H2S monitor, to measure H2S concentrations throughout the location. Maintain at least one two-man team to continuously check that the "Hot Zone" is adequately identified. (Winds can vary and change conditions rapidly.) Evacuation zones are always located upwind and determined to be a minimum of 1 mile or 0 percent LEL, whichever is greater. Assign an individual to gather all vehicles and park them in a safe upwind location, parked facing their escape route, with the motor off, and with the keys in the ignition. Alert the rig camp of the emergency and to stand by for further instructions. Under emergency conditions, it might be difficult for one man to directly supervise more than four people. Organize small work teams of at least two, but usually not more than five, men. Assign one man as leader of every work team. — Each work team will have an individual assigned to check the air supply of all team members and to monitor H2S levels using a continuous monitor. This should be his primary responsibility. He should not be assigned other duties that could interfere with this vital safety function. — All work is assigned to individual teams at the Safe Briefing Area. — The Safe Briefing Area commander keeps a written log of all assigned tasks. — Each work team is assigned only one task. — An estimated time of completion is identified for each assigned task. — Each work team reports back to the Safe Briefing Area immediately upon completion of their assigned task, allowing the Commander to be fully up-to- date on the progress being made. — If a work team has not completed their task by their estimated time of completion, they must report back to the Safe Briefing Area (or send a pair of runners to report). Issue Date Revision No. Revision Date Prepared By Approved By Page 74 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition WELL IGNITION CRITERIA The recommended practices of API RP -86 indicate that the decision to ignite the well should be made only as a last resort, and only then when the following is clear: Human life and property are endangered. There is no hope of controlling the well under the prevailing conditions at the well site. ERCB Directive 071, Emergency Preparedness and Response Requirements for the Petroleum Industry, adds that timely ignition (within 15 minutes) is required when any one of the following elements is present: Evacuations have not taken place, even if notified. H2S levels over 10 ppm detected in unevacuated areas. H2S concentrations in excess of 1 ppm (1 -hour average) detected in urban density developments. Monitoring not taking place on wells with known high H2S concentrations. The decision to ignite or not ignite the well requires a quick and thorough assessment of the conditions at the well site and the immediate vicinity. Delays could create additional threat scenarios for site personnel and communities within the immediate area. IN ALL CONDITIONS, notify the local emergency -response organizations that a well control problem exists and that the decision to ignite the well is being considered. The methodology for determining voluntary well ignition involves the following: 1. Understand conditions prior to any decision to voluntarily ignite a blowing gas/oil well. 2. Follow identified protocols and authorities for determining ignition. 3. Identify alternatives to voluntary ignition, if practical. 4. Identify methods to ignite and sustain the ignition. 5. Develop concepts for minimizing collateral damage. Issue Date Revision No. Revision Date Prepared By Approved By Page 75 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition VOLUNTARY WELL IGNITION GENERIC DECISION MAP It is an accepted practice that a decision map is beneficial toward expediting a sound decision to ignite a blowing well. However, a decision map alone is not adequate and must be supplemented by the knowledge and expertise of an experienced FIFI and well control expert, if at all possible. A generic decision map is shown in Figure E.2. Issue Date Revision No. Revision Date Prepared By Approved By Page 76 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. Marathon oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition 1 Communicate with Deputy Incident Commander and others per WCERP Implement H2S Procedures START Well Control Event/ ncontrolled Releas .Yes Are Human Life or Property ndangered Yes Decision Map Voluntary Well Ignition Monitor and Con inue WCERP Response No Consider Voluntary Well Ignition ■ Yes Yes Implement Alternative Approaches No Wind/Water Conditions Favorable? Evaluate Site/ Exclusion Zone Evaluate Environmental Conditions Will Environment Impact Be Reduced? Other Alternatives More Effectiv 9 No 0 Figure E.2 — Decision Map Continue Response in Accordance with WCERP, WIP, and ERP Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 77 Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition CONDITIONS AFFECTING WELL IGNITION The decision to ignite a blowing gas/oil well must have all factors considered before a decision for voluntary ignition of the well can be made. Because most drilling sites are in remote areas and accessibility for heavy well control equipment can be an issue, the almost certain destruction of the drilling rig upon well ignition will prolong the well control event. The WIP should establish actions to be taken if a product release occurs while personnel are on site and should indicate the qualified Company representatives at the site who have the authority to ignite the release. These emergency response procedures should be reviewed as part of the prejob safety meeting. The conditions affecting well ignition are extensive. A more extensive analysis of some of the most important factors that might impact a decision to ignite a well is addressed in the tables at the end of this document. The following list identifies some of the elements for consideration, as each well event must be treated as unique. Does the well contain H2S? If H2S is present, in what concentrations? Are there any residential areas with hospitals, schools, or highly traveled roads close by? Igniting the well can cause serious damage to surrounding equipment, rendering it useless. It must be assumed that well ignition will remove the ability for operators to control the well. Collateral damage from the explosion might make the wellhead inaccessible. Equipment exposed to the ignition sequence might cause an equal or greater hazard. Always assess secondary explosion possibilities. Flammable liquid characteristics of the product released from the well might not be within the flammable range necessary for ignition. After ignition, maintaining the fire at the source might not be possible. Other products such as sulfur dioxide or water entrained in the fuel mixture might cause incomplete or lack of combustion conditions. What will be the efficiency of the burn? Will meaningful amounts of gas/oil be consumed in an effective effort to reduce the impacts of the well control event? Products of complete and incomplete combustion might create a secondary hazard within the range of the plume cloud. Are large amounts of gas/oil being produced? Issue Date Revision No. Revision Date Prepared By Approved By Page 78 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Are there any low-lying areas where gas/oil can accumulate? What is the general terrain in the affected area? What is the wind direction and speed? Is the area "footprint" increasing due to wind or wave action? Are there any lakes, oceans, rivers, or streams that can be affected by a spill? Are there any structures, production facilities, wells, or pipelines that can be affected? Is any wildlife affected by the gas/oil released? In general, voluntary ignition of the well should NOT be done when any of the following is true: Well flow composition will not sustain ignition. There is a high probability of a rapid, successful intervention by a Well Control Specialist The nature of the blowout indicates a low rate of flow. A high tendency for the well to bridge exists. Potential for incident escalation is low. Concentration of H2S is low. Pollution is easily contained and minimized. Isolation of failed equipment is possible. VOLUNTARY IGNITION DRAWBACKS The combustion efficiency of an ignited blowing gas/oil well cannot be forecast. Efficiencies might be as low as 50%-60%, depending on how obstructive the drilling rig is to the supply of oxygen needed to sustain the burn. This lower efficiency, coupled with a longer time to regain control or cap the well after ignition, might result in as much or more of an oil spill. Issue Date Revision No. Revision Date Prepared By Approved By Page 79 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition The nature and characteristics of the well control event are a major factor in making the determination to ignite the well, in addition to the presence of H2S. It is important to note that not all wells should be ignited, including some H2S wells. Some examples of wells that might be better controlled without ignition include the following: Equipment, flange, or other leak types that might be controlled by pumping junk shots or other methods Blowouts of the drill pipe, where the flow exit point is of benefit to effective gas dispersion Low -rate blowouts that might be controlled by momentum kills Some subsurface blowouts and ruptures ALTERNATIVES TO REQUIRED IGNITION Grade (topographical contouring with connecting drainage ditches) the surface of the well site to channel and direct the flow of oil discharged and water down to sumps to prevent a large fraction of the oil from contaminating a larger area. Equip the sumps with suction pumps to move the collected oil to flare booms or burn pits. Expand the footprint of the well site to provide a larger sump for collection of the oil that rains back down on the location. Use a water cannon to knock oil out of the blowing plume. Employ additional well control equipment (added redundancy) to significantly reduce the probability of an uncontrolled flow, perhaps in the form of an extra blind - shearing ram placed on the wellhead below the normal BOP stack, and operated by its own independent control system. Use a more conservative well design, to include increased casing burst strength values. Divert the well flow to a pit a distance away from the rig and ignite the pit, not the well. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 80 Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition If, after consideration of the alternative approaches, the highest interests are best addressed by voluntary ignition of the well, proceed to ignite the well as safely and quickly as possible. OPTIONS FOR MINIMIZATION OF COLLATERAL DAMAGE Installation of blast shields Installation of thermal protection (reflective metal) Installation of deluge systems Development of a drainage system to channel oil away from the vicinity of the source flow, all adjacent wellheads, and production facilities Minimization of the time required to reach a decision to ignite such that the accumulation of gas/oil in and around adjacent wells and production facilities is minimized POSTIGNITION EFFECTS Postignition effects from the ignition and subsequent fire should be considered as part of the WIP development process and during the execution of the plan. Among the most common effects are as follows: Secondary explosions that can occur at any time but usually shortly after the well's ignition Heat radiation that can harm persons near the fire Debris field caused by fire and explosion Need for air-quality monitoring Additional isolation procedures necessitated by changes in the dynamics of the well fire, environmental or other conditions These effects should be anticipated and mitigated wherever possible. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 81 Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition SECONDARY EXPLOSIONS Secondary explosions are almost assured during a rig fire. Numerous items on rigs can be subjected to sufficient heat that causes them to explode. Accumulator bottles, oxygen -acetylene cutting equipment, diesel tanks, perforating charges, and other common oilfield explosives, production separators and other production equipment, can all be dangerous when a well is on fire. Thus, it is important to allow the situation to stabilize before making an assessment after ignition. Gas accumulation inside rig structures is very dangerous. If this gas is not ignited, radiant heat and fire impinging on the structure can cause the gas inside to explode or ignite. HEAT RADIATION Fires produce radiant heat (thermal radiation) that can result in burns to exposed personnel. A thermal radiation level of concern is the threshold level above which a hazard might exist. The thermal radiation effects that individuals might experience depend primarily upon the length of time that individual is exposed to a specific thermal radiation level. Longer exposure durations, even at a lower thermal radiation level, can produce serious physiological effects. Figure E.3 lists some of the effects of thermal radiation exposure on bare skin at specific levels and durations. ALOHA's default thermal radiation values are based on a review of widely accepted sources (American Institute of Chemical Engineers 1994, Federal Emergency Management Agency et al. 1988). Three threshold values (measured in kilowatts per square meter and denoted as kW/m2) have been calculated using ALOHA: 10 kW/m2 (potentially lethal within 60 sec) 5 kW/m2 (second-degree burns within 60 sec) 2 kW/m2 (pain within 60 sec) In a stable, uniform, and symmetrical fire, the heat flux could be expected to extend uniformly in a circular pattern away from the source. However, thermal radiation from the fire can be greatly affected by the several factors. Direction of the fire and resulting heat flux will be impacted from the debris and remains of the rig and site structures, specific failure points on the wellhead, piping, or other equipment. Weather is also a significant factor influencing the radiant heat density as it is evident that strong winds will tend to skew the heat flux downwind. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 82 Wild Well Control, Inc. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Radiation Intensity (kW/m2) Time for Severe Pain (Seconds) Time for Second -Degree Burns (Seconds) 1 115 663 2 45 187 3 27 92 4 18 57 5 13 40 6 11 30 8 7 20 10 5 14 12 4 11 Figure E.3 — Thermal Radiation Burn Criteria Source: US EPA and NOAA (2007). DEBRIS FIELD CREATED BY FIRE/EXPLOSION Most rig fires create significant debris, removal of which can be a lengthy process, increasing the well control time in almost every event. The quantity of debris to remove is directly related to the operational environment. Onshore production fires usually have less debris to remove than offshore drilling rig fires. Residual chemicals used around a well or rig can be very flammable and hazardous. In addition, radioactive materials, such as those found in logging equipment, can also be a special hazard if subjected to fire. Workers at the well must take necessary precautions when dealing with all kinds of these potentially hazardous materials and debris. AIR QUALITY MONITORING The WIP should also outline procedures for acquiring and deploying additional monitoring and air quality equipment, if required. After ignition, much of the H2S should be converted to sulfur dioxide. While typically less dangerous that H2S, sulfur dioxide at levels that exceed 10 ppm should require all persons to be evacuated to a safe location. ADDITIONAL ISOLATION PROCEDURES The Company might have to deal with the problem of isolating a major highway or railway if the hazard has the potential to impact the traveling public or railway operations. The Company's Emergency Response Plan should identify the highways and Issue Date Revision No. Revision Date Prepared By Approved By Page 83 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition railways that could be affected and set out the procedures for communicating with the regional and local transportation authorities, regulatory agencies, and appropriate rail companies to isolate the area. WELL IGNITION PROCEDURE Since every blowout is different, the absolute procedure for igniting a well cannot be written for every possible circumstance. When the decision to ignite the well has been made, the swell must be ignited quickly but with the utmost care and safety. A generic procedure for igniting the well is shown below in Figure E.4. A detailed checklist of voluntary ignition procedures for field use is shown at the end of this appendix. ART Announce Intention for Voluntary Ignition Evacuate All Personnel Secure/ Prepare Location Isolate Leakage to Single Point, if possible No Confirm Acceptable Environmental onditions Yes Determine Preferred Source of Ignition Evacuate Exclusion Zone No r Yes Figure E.4 — Well Ignition Procedure Ignite Well Allow Well to Stabilize Monitor Environmental Impacts Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 84 Wild Well Control, Inc. r►*►.. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Certain procedures should be completed for most situations, in order to safely ignite the flow. When the order to ignite a well is given, these guidelines should be followed: Evacuate all personnel. Rescue injured personnel. If possible, limit the blowout's exit point to a single source through methods such as closing BOP stack valves, tree and wellhead valves, and chokes. Evaluate wind and weather conditions to ascertain whether the situation might endanger remaining personnel or the person responsible for igniting the well. Determine whether ignition by way of a flare gun or other tool is possible from the facility: Strong prevailing winds away from the firing point, H2S-free atmosphere, available cover from a flashback, and clear escape access. Establish the flare gun's range and whether well access within this range is safe and possible, given the presence of H2S and potential heat radiation. Clear all personnel and local residents within a 1 -mile radius, except for personnel required at the firing base. Evacuation zones should always be located upwind and determined to be a minimum of 1 mile or at a 0 -percent LEL, whichever is greater. The radius might have to be expanded, depending on the well's flow rate and the H2S concentration and dispersal patterns. A potential range for this distance should be determined whenever H2S contingency and well ignition plans are written, however, the actual conditions will dictate the proper distance. Potential overpressure from a gas cloud explosion can be calculated using several different methods. The WIP can include calculations for different vapor clouds, so that decisions can be made that could influence the ignition procedure and the distance required to safely light the well. To ignite the well, approach from the upwind side while monitoring H2S levels. While remaining within a safe area and with the range of the ignition device, a single person should fire the tool and ignite the flow. Escape from the area should be made immediately, due to possible secondary explosions and falling debris. Once ignition takes place, the well should not be approached until it stabilizes. Later conditions should permit access with reasonable safety while under the strict supervision of Well Control Specialists. Issue Date Revision No. Revision Date I Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 85 Wild Well Control, Inc. /Ito Marathon 011 Corporation. REFERENCES Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition API RP68, Recommended Practice for Oil and Gas Well Servicing and Workover Operations Involving Hydrogen Sulfide. ERCB Directive 071, Emergency Preparedness and Response Requirements for the Petroleum Industry. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 86 Wild Well Control, Inc. 1!j/ Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Site: WELL IGNITION FIELD CHECK SHEET Date: Company Man: Step Activities Completed by: (Name/Title) Announce Intention for Voluntary Ignition Alert all personnel that the well will be ignited. Advise local authorities and others per WCERP. 6/9/2011 Evacuate All Personnel Evacuate any injured or disabled personnel. Evacuate all nonessential personnel. Begin evacuation of nearby residences/others. Evacuation zones are located upwind and determined to be a minimum of 1 mile or at 0% vapor LEL, whichever is greater. 87 Secure/Prepare Location As possible and if safety of personnel can be assured, secure and prepare site to facilitate control of the well. — Remove any radioactive logging equipment, specialty, or other hazardous materials from the site, if possible. — Prepare/enhance dikes, berms, or channels that might be used to direct liquid or material flows. — Anticipate drainage of FIFI consumables. — Remove materials that might result in secondary explosions. — Anticipate and prepare for a controlled destruction of rig and equipment that will facilitate future well control (provide fire protection/cooling on two legs of rig so that rig failure will result in rig falling away from future approach to well). Isolate Leakage Isolate leakage to one source of discharge, if possible. Consider the preferred direction of discharge if multiple options exist. Confirm Acceptable Environmental Conditions Are Present Confirm that acceptable environmental conditions are present to perform a safe ignition. — Low to moderate wind speed — Other factors as appropriate Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 87 Wild Well Control, Inc. 1!j/ Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Step Activities Completed by: (Name/Title) Determine Preferred Source of Ignition Determine the preferred source of ignition. — Flare gun — FIreFIyTM Remote/Auto System — Other ignition methods, as available Ensure the range of the equipment is sufficient using the safest direction of approach. Deploy a strategy to ensure ignition will be sustained, if flammability of stream is not consistent. Page 6/9/2011 Evacuate Exclusion Zone Evacuate everyone from the impacted area except for the person or persons igniting the well. Plan for the maximum overpressure that could be experienced due to a gas cloud explosion. Are all persons safe and accounted for? Bryan Beautz 88 Ignite Well Approach the well from an upwind direction. Ensure that only one person, appropriately qualified, operates the ignition equipment. — Name: Ignite the well using the selected ignition method. — Time: Other Comments: Evacuate immediately to safe range. Inform Company Man of successful evacuation. Allow Well to Stabilize Allow the well fire to stabilize. Prepare for the potential of any secondary explosions. Ensure ignition is sustained. Anticipate, monitor, and mitigate postignition effects, as possible. Consult Well Control Specialist for ongoing direction. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 88 Wild Well Control, Inc. 1!j/ Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix E — Voluntary Well Ignition Title: Appendix E — Voluntary Well Ignition Step Activities Completed by: (Name/Title) Monitor Environmental Impacts Monitor environmental impacts, as appropriate. — H2S or SO2 — Air — Pollution/Water — Others Take appropriate action such as the following: — Modification of exclusion zone shape or size in reaction to sensors and hazard levels to ensure the safety of all persons Page 6/9/2011 Continue Well Control Emergency Management Plan Continue to operate in accordance with the Well Control Emergency Response Plan. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 89 Wild Well Control, Inc. Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List APPENDIX F - INTERVENTION EQUIPMENT LIST This section outlines some of the equipment that might be needed for a variety of well control intervention projects. Most of the specialized intervention equipment and materials will come from sources along the United States Gulf Coast. This type of equipment is usually built to be easily transported by airfreight and can be deployed relatively quickly to any location worldwide. SPECIALIZED FIREFIGHTING EQUIPMENT A minimum of two 4,000 gpm, 500 HP pumps is usually required. The necessary hardware to use either earth pits or frac tanks for suction supply will be required. For this particular application, at least one transfer pump might be required to replenish the water reservoir. Typically, four 750 to 1,000 gpm adjustable water monitors are used. A variety of other sizes are available for particular applications. Figure F.1 — 4,000 gpm Firefighting Pump Rated at 4,000 gpm, the FIFI pumps are equipped with an 8V92TA Detroit Diesel engine coupled to a L8R20 Worthington pump. These pumps are all skid -mounted for easy mobilization. Figure F.1 above illustrates a FIFI pump with a capacity of 4,000 gpm. Issue Date Revision No. Revision Date 6/9/2011 Prepared By R.B. Davis Approved By Bryan Beautz Page 90 Wild Well Control, Inc. Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Pump and Fuel Tank Specifications Item Description Weight Dimensions 1. 4,000 gpm Fire Pump 10,060 Ib Dry 11,260 Ib Wet L: 13' x W: 5' x H: 6' 9" 2. 500 gal Fuel Tank 2.900 Ib Dry 6,640 Ib Wet L: 8' x W: 4' 9" x H: 6' Hydro -Chem Monitor Stand (2,000 gpm) A "Hydro -Chem" monitor is used to support well control operations where flammable liquids are present. This specialized piece of equipment is also used on ship fires and in petrochemical facilities. Figure F.2 — 2,000 gpm Hydro -Chem Monitors GENERAL EQUIPMENT Construction Equipment There are a number of items that can be considered standard construction -type equipment. This type of equipment is often used in oilfield and well control operations. Issue Date Revision No. Revision Date Prepared By Approved By Page 91 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Fabrication Personnel and Equipment Skilled welders will be needed for various fabrication projects. Each should be supplied with necessary equipment such as welding machines, cutting torches, grinders, chipping hammers, and wire brushes. An adequate supply of safety equipment ordinarily used during fabrication projects such as goggles and face shields will be required (typical requirement: 6-8, possibly more). Roustabouts A roustabout crew will be needed for various tasks such as fabrication and rig up of pumps and lines. A crew consisting of one supervisor and five roustabouts should be contracted. Material A considerable amount of fabrication material might be needed for various tasks. The material list will include items needed to build heat shields, fire monitor enclosures, and capping accessories, and other items: 500 sheets of 2' x 8' galvanized corrugated tin (10 gauge) 50 joints of 23/8" tubing 24 pieces (500 ft2) of expanded metal grating 750 ft of2"x2"x%" angle iron 500 ft of 3" x 3" x %" angle iron 4 sheets of 4' x 8' x %" steel plate 250 ft of %2" cold rolled bar Air Compressor Two 185 cfm, 125 psi air compressors, each with a minimum of 150 ft of 2" 300 psi WP hose and spare end connections. These will be required to supply air for starting pumps and operating pneumatic tools that might be needed for the project. Air compressors are generally available through local specialty rental companies or might be available on the primary support vessel. Issue Date Revision No. Revision Date Prepared By Approved By Page 92 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Generators Self-contained diesel -powered generators might be required in order to power certain electrical equipment (typical requirement: 1-2). Light Towers Self-contained diesel -powered light towers should be ordered to facilitate fabrication projects that might extend into the night. Light plants and towers are generally available from specialty rental or construction companies. The primary support vessel might have adequate lighting. Pneumatic Tools Impact wrenches, drills, grinders, and pneumatic hacksaws along with hoses, sockets, bits, and various other accessory pieces are included in this type of equipment. These are available from most oilfield supply or construction outlets. Pneumatic Winches Large pneumatic winches, or "air tuggers," might be needed for capping or debris removal. They are usually available through specialty rental companies. SPECIAL WELL CONTROL EQUIPMENT Coiled Tubing Units There might be a need for a coiled tubing unit during the intervention. The size of the coiled tubing varies from 1" to as much as 3%". In addition to the size of the tubing itself, the pressure rating of the equipment must also be considered. Most coiled tubing units are rated to 10,000 psi working pressure. However, there are a limited number of 15,000 psi working -pressure units in use in various locations. Snubbing Equipment Snubbing units are often used in well control operations. The units are sized according to the lift rating of the hydraulic snubbing jack. The particular size of the unit needed depends on the particular job. The basic sizes of snubbing units are 150K, 240K, 340K, 460K, and 600K. The snubbing capacity is generally one half of the lifting capacity of the jack. The ancillary equipment required for snubbing includes a minimum of stripping ram BOPs with an equalizing loop and bleed off. Various pump lines and manifolds are Issue Date Revision No. Revision Date Prepared By Approved By Page 93 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List also required for snubbing operations. The snubbing jacks, power packs, and other items are available through several specialty snubbing vendors. Figure F.3 — Snubbing Equipment Hydraulic Tongs These tongs usually are different from standard casing tongs in that they have backup built into them. The tongs might be required to make or break drill pipe or drill collars and thus will need to have high torque capabilities. These tongs are available through specialty tong vendors or casing crew companies. Hydraulic Tools This equipment includes tools such as torque wrenches, nut splitters, and portable power jacks. These are available from pressure -testing companies and specialty rental companies. Hot -Tapping and Valve Drilling Equipment There might be a requirement for hot -tap and valve drilling equipment. This equipment is used to drill into a pressurized pipe or vessel. Valve drilling equipment is used to drill through the gate on a damaged gate valve. Hot -tap and valve drilling equipment is available through WWCI and other oilfield service companies. The following picture shows the hot -tap tool in use on a well control job. Issue Date Revision No. Revision Date Prepared By Approved By Page 94 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\,.)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Figure F.4 — Hot Tap Tool Mud Mixing Equipment There might be a requirement for a full complement of mud -mixing equipment to prepare kill fluids. This includes mud tanks, mixing hoppers, bulk materials storage equipment, and materials -handling equipment. Abrasive Jet Cutters High-pressure cutters that use abrasive material such as frac sand, slag, or crushed garnet might be needed for debris or wellhead removal. These cutters can be used in explosive atmospheres. The cutters are available from WWCI, BJ Services, and Halliburton. Issue Date Revision No. Revision Date Prepared By Approved By Page 95 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. I(\)1 Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F - Intervention Equipment List Title: Appendix F - Intervention Equipment List Figure F.5 - Abrasive Jet Cutter Proximity Ranging Equipment In a relief well situation, magnetic ranging tools might be needed to locate the blowout well. The company that provides this type of service is located in the US state of New York. This equipment is easily transported by airfreight. Breathing Equipment If toxic gas is present or heavy accumulations of hydrocarbon gases are in the area, breathing equipment and trained personnel should be on site at all times. A cascade breathing system should be installed on the primary support vessel adequate to provide air for all personnel. An ample supply of portable air packs, both 30 -minute and 5 - minute "escape packs," should be available consistent with the number of personnel onboard. Spare masks, regulators, and bottles should be available on site. A breathable - air compressor should be placed on the primary support vessel to recharge the bottles and cascade system. A gas -monitoring system might be needed. This should include visual and audible alarms, a 6 -channel monitoring system and a battery backup. Several portable gas detectors will also be needed. Issue Date Revision No. Revision Date Prepared By Approved By Page 96 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. Marathon Oil Corporation. Lathe Cutters Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Portable, lathe -type die cutters might be required for circumferential cuts on casing strings. The cutters can be either pneumatic or hydraulic depending on the application. These cutters come in a variety of sizes and are available through WWCI and other oilfield service companies. Figure F.6 — Lathe Cutter in Use on 5" Drill Pipe Freeze Equipment There are two types of freezes done in well control applications. The older type is a dry - ice freeze. The equipment and materials required to perform this type are dry ice (CO2), methanol, a bucket, and a liner. The bucket is usually fabricated for the specific item that is to be frozen. Dry ice and methanol are available through various commercial outlets. The newer and more efficient method is to use a prefabricated jacket for the pipe size and liquid nitrogen to freeze. The kit generally includes coils and blankets or special jackets that fit around the pipe that is to be frozen. Issue Date Revision No. Revision Date 6/9/2011 Prepared By R.B. Davis Approved By Bryan Beautz Page 97 Wild Well Control, Inc. Marathon Oil Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix F — Intervention Equipment List Title: Appendix F — Intervention Equipment List Figure F.7 — Freeze Operation OTHER SPECIALIZED EQUIPMENT The list of specialty surface and downhole equipment that is used in well control intervention is very long. In addition to the equipment listed above, landing nipples and plugs, back -pressure valves, shot drums, windows for coiled tubing or snubbing units, casing and tubing clamps, slip rams, punch rams, cutter rams, antirotation rams, stripper rams, cables, snatch blocks, and a host of other assorted items might be needed for the intervention. This gear is available through WWCI, BTI, and various other specialty oilfield companies. Issue Date Revision No. Revision Date Prepared By Approved By Page 98 6/9/2011 R.B. Davis Bryan Beautz Wild Well Control, Inc. Get a list of the chemicals of concern for the incident. � J J Obtain site map, develop and plot sampling locations for Level II Team J Determine the number of people required to accomplish air monitoring. ) 1 Document on Level II Team IH Form & Site Safety Plan and indicate the PPE required. } Are people & equipment available within area to accomplish monitoring? � J Fax/Email Level II IH Form & Plotted site plan to response site. } Contact the appropriate Personnel & mobilize to site. Document on Level II IH Form. Develop action plan to interpret monitoring results and document on Level II IH Form. � J Marathon oil Corporation. Document No.: Section: Title: Well Control Emergency Management Plan Appendix G — Air Monitoring Requirements Appendix G — Air Monitoring Requirements APPENDIX G - AIR MONITORING REQUIREMENTS Obtain MSDS and review components of chemical(s). Has modeling been done by Env. to determine air emission plumes? Yes No —10 Obtain site map, and use modeling as a guide to plot sampling locations on map for Level II Team. Determine potential health effects of chemical(s). Do significant health effects exist? Yes No Identify what type(s) of equipment needed for monitoring & document on Level II IH Form. Document on Level II Team IH Form & Site Safety Plan and indicate no PPE required. Yes No Contact additional resources through Refining (if close to site), GP for rental equipment, or contact CERT through 866-MOCCERT to determine availability & mobilize to site. Document on Level II IH Form F Figure G.1— Air Monitoring Decision Flowchart Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 99 Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix G — Air Monitoring Requirements Title: Appendix G — Air Monitoring Requirements IH AIR MONITORING INFORMATION FORM FOR LEVEL II TEAM Products of Concern Product Components of Concern Probable Exposure Health Effects of Product PPE Required Number of People Required to Monitor (Including Names and Organization) Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 100 Wild Well Control, Inc. /Ito Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix G — Air Monitoring Requirements Title: Appendix G — Air Monitoring Requirements Equipment Needed to Monitor (Including Where Equipment Is Coming from) Monitoring Locations See site plan with marked monitoring locations. Monitoring Results Action Plan Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 101 Wild Well Control, Inc. Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix G — Air Monitoring Requirements Title: Appendix G — Air Monitoring Requirements LEVEL 11 RESPONSE AIR MONITORING LOG Sampler Name: Date: Facility Name: Approved By Page 6/9/2011 Monitoring for: Equipment Used: Bryan Beautz ❑ Direct Reading ❑ Detector Tubes ❑ Other For Direct Reading Equipment: For Detector Tubes: For Other: Manufacturer and Model: Manufacturer: Describe Monitoring Equipment: Serial Number: Tube Type: Calibration Date: Tube Range: MONITORING RESULTS Location Time (Include "a.m." or "p.m.") Reading (Include Units) Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 102 Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix H — Local Responder Information Title: Appendix H — Local Responder Information APPENDIX H - LOCAL RESPONDER INFORMATION FIRE/FIRST RESPONDER Fire and first -responder responsibilities include the following: Perform a site assessment. Perform air monitoring. Remove accessible casualties to a safer zone. Decontaminate, as necessary. Triage, treat, and transport casualties. Establish site access and accountability. Assure that a well control company has been notified. Prevent expansion of any fire. Perform initial interventions to prevent runoff of contaminants. Assist with evacuation, as necessary. Preserve evidence, when possible. EMERGENCY MEDICAL SERVICES Assure site safety. Establish that air monitoring is in place and area is safe before entry, where appropriate. Remove accessible casualties to a safer zone. Decontaminate, as necessary. Triage, treat, and transport casualties. Establish a dedicated unit for the safety of incident responders. Assist with evacuation, as necessary. Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 103 Wild Well Control, Inc. /Mil Marathon 011 Corporation. Document No.: Well Control Emergency Management Plan Section: Appendix H — Local Responder Information Title: Appendix H — Local Responder Information LAW ENFORCEMENT Control access to the site. Consider the cause of the incident. — Accident within the normal scope of work processes — Accident outside the normal scope of work processes — Intentional act of sabotage Work with responders to preserve evidence, when possible. Execute traffic plan. Assist with evacuations, as necessary. EMERGENCY MANAGEMENT Activate Emergency Management plan as necessary based on size and scope of incident. Assure that a Well Control Company has been notified. Support the activities of the Incident Commander, as needed. Consider the health effects of gas cloud or products of combustion downwind from incident. — Old and young populations — Populations with preexisting conditions likely to be exacerbated — Populations with limited mobility (hospitals, nursing homes, senior living centers, jails) — Special -needs populations — Limited access to transportation Issue Date Revision No. Revision Date Prepared By Approved By Page 6/9/2011 R.B. Davis Bryan Beautz 104 Wild Well Control, Inc. 1 Marathon Oil Piceance Operations Emergency Response Plan Appendix H: Inland Spills Response Tactics Guide Appendix H: Inland Spills Response Tactics Guide See Guide Below - January 2013 © The Response Group Page 1 Inland Spill Response Tactics Guide A - ; , , , a I Emergency Response 'Pre -Planning 8 Support 13939 Telge Road • Cypress, TX 77429 • Tel: (281) 880-5000 • =7 Section 1.0 Table of Contents 1.0 Table of Contents 1.1 Prevention Section Name 1.1.1 Earthen Dams, Berms, and Barriers 1.1.2 Culvert Damming or Sealing 1.1.3 Underflow Dam and T -Siphon 1.1.4 Water Gate/ Mega Dam 1.1.5 Boom Anchoring: On Land and Water 1.1.6 Diversion Booming 1.1.7 Exclusion Booming 1.1.8 Protection Booming 1.1.9 Containment Booming - Nearshore 1.1.10 Containment Booming - Offshore 1.1.11 Cold Weather Prevention 1.2 Recovery and Removal Section Name 1.2.1 Natural Recovery 1.2.2 Physical Herding 1.2.3 Manual Removal 1.2.4 Mechanical Removal — On Land 1.2.5 Mechanical Removal — On Water 1.2.6 Debris Removal 1.2.7 Sorbent Deployment 1.2.8 In -Situ Burning: On Water and Land 1.2.9 Cold Weather Recovery: Manual 1.2.10 Cold Weather Recovery: Mechanical 1.3 Cleaning Section Name 1.3.1 Pressure Flushing 1.3.2 Flooding 1.3.3 Steam Cleaning 1.3.4 Sediment Reworking 1.3.5 Vegetation Removal 1.3.6 Sand Blasting 1.3.7 Decontamination 1.3.8 On Water Decontamination Section Appendix Name A Small Boat Safety B Materials of Opportunity for Spill Response C Types of Skimmers for Inland Waterways Inland Spill Response Tactics Guide ©The Response Group Section 1.1 Table of Contents 1.1 Prevention Section Name 1.1.1 Earthen Dams, Berms, and Barriers 1.1.2 Culvert Damming or Sealing 1.1.3 Underflow Dam and T -Siphon 1.1.4 Water Gate/ Mega Dam 1.1.5 Boom Anchoring: On Land and Water 1.1.6 Diversion Booming 1.1.7 Exclusion Booming 1.1.8 Protection Booming 1.1.9 Containment Booming - Nearshore 1.1.10 Containment Booming - Offshore 1.1.11 Cold Weather Prevention Inland Spill Response Tactics Guide ©The Response Group 1.1.1) Prevention: Culvert Damming or Sealing MOM Earthen Dams, Berms, and Barriers Purpose: A physical barrier is placed across a waterway to prevent moving oil from passing. It can only be implemented where there is little to no current flow and the width of the waterway warrants the deployment. Examples of location for deployment include (but are not limited to) streams and dry valleys, and mouths of small creeks along lake shorelines. Application: - In no -current situations, a backhoe or front-end loader may be used to place dirt or other material into the waterway. - In low to moderate current conditions, gravel or sand bags may be used to limit and prevent erosion of the barrier. - If the waterway is shallow and narrow enough, a wooden board can be used as the barrier, filling around the edges with dirt. Steps: a.) Depending on current speed, develop the barrier with dirt, gravel, sand bags or wooden board. b.) If applicable, line the barrier with plastic sheeting. c.) Line the shoreline in the collection area with sorbents. d.) Recover spilled material. e.) Maintain integrity of construction, monitor situation. Materials: Equipment Manpower Construction Materials Hand Tools PPE Sorbents Recovery -Front-end Loader -Backhoe -Supervisor -Equipment Operator -Responder -Dirt -Plastic sheeting -Gravel -Sand Bags -Wooden Board -Straw Bales -Shovel -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box Environmental Considerations: - The barrier needs to be placed away from sensitive areas, (ideally) such as spawning sites. - Downstream water requirements should be monitored to prevent dewatering of sensitive areas. - Dewatering or poor water quality downstream may affect aquatic organisms. - This method may disrupt or contaminate sediments along or in the waterway. 1.1: Prevention ©The Response Group 1.1.2) Prevention: Culvert Damming or Sealing Sheet Metal or Plywood with Sandbags and Visqueen Culvert Damming or Sealing Culvert Plug Adjustable Purpose: To create a dam or underflow as a quick response in a narrow waterway where culverts are present and immediate access to materials are limited. Application: - Effective in low -speed waterways where the creek or channel is relatively narrow (< 20'). - In high-flow situations, an underflow dam is recommended. - Effective as initial response or as primary defense against spills, depending on the durability of the construction. Steps: a.) Depending on current speed, develop the barrier with dirt, gravel, sand bags or wooden board, or plug. b.) If applicable, line the barrier with plastic sheeting. c.) Line the shoreline in the collection area with sorbents. d.) Recover spilled material. e.) Maintain integrity of construction, monitor situation. Materials: Equipment Manpower Construction Materials Hand Tools PPE Sorbents Recovery -Front-end Loader -Backhoe -Supervisor -Equipment Operator -Responder -Dirt -Plastic sheeting -Gravel -Sand Bags -Wooden Board -Shovel -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box Environmental Considerations: - The barrier needs to be placed away from sensitive areas, (ideally) such as spawning sites. - Downstream water requirements should be monitored to prevent dewatering of sensitive areas. - Dewatering or poor water quality downstream may affect aquatic organisms. 1.1: Prevention ©The Response Group 1.1.3) Prevention: Underflow Dam and T -Siphon Underflow Dam and T -Siphon T -Siphon Purpose: An underflow dam or T -siphon is a barrier that should be constructed where the current flow will not allow for complete blockage of the waterway. The underflow dam/ t -siphon is designed to let water flow through the dam while the spilled material is trapped on the surface. Examples of location for deployment include (but are not limited to) streams and dry valleys, and mouths of small creeks along lake shorelines. Application: - An underflow dam/t-siphon can be made of dirt, gravel, sand bags, or a wooden board. In an underflow dam, a series of inclined pipes run through the dam to allow water flow from one side to the other. The "low" side of the inclined pipes is on the upstream side of the underflow dam while the "high" side of the pipes is on the downstream side of the dam. o Water will travel through the dam while the spilled material will stay floating on the upstream side of the dam. In a T -siphon, the water travels through the pipe, trapping the material at the top of the pipe while water continues to flow through. Steps: a.) Depending on current speed, develop the barrier with dirt, gravel, sand bags or wooden board. b.) Half -way through the construction of the barrier, incline a series of pipes to allow water to flow freely through the dam. c.) Line the dam with plastic sheeting to prevent seepage. d.) Line the shoreline in the collection area with sorbents. e.) Recover spilled material. f.) Maintain integrity of construction, monitor situation. Materials: Equipment Manpower Construction Materials Hand Tools PPE Sorbents Recovery -Front-end Loader -Backhoe -Supervisor -Equipment Operator -Responder -Dirt -Plastic Sheeting -Gravel -Sand Bags -Wooden Board -Pipes -Shovel -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box Environmental Considerations: - The barrier needs to be placed away from sensitive areas (ideally), such as spawning sites. - This method may disrupt or contaminate sediments along or in the waterway. 1.1: Prevention ©The Response Group 1.1.4) Prevention: Water Gate/ Mega Dam Water Gate/ Mega Dam Purpose: A Water Gate/ Mega Dam is a canvas barrier that can be quickly deployed to stop all flow through a waterway. In addition to acting as a full -stop barrier, it also has doors that can be opened below the water level to act as an underflow dam. Its ideal use is across narrow, slow moving waterways. Application: - The water gate is deployed across the waterway to stop all flow downstream. - Spilled material can be removed from the upstream side of the gate in the collection area. Steps: a.) Deploy water gate. b.) Insert sand bags for ballast as necessary. c.) Line the shoreline in the collection area with sorbents. d.) Recover spilled material. e.) Maintain integrity of the gate, and monitor the situation. Materials: Manpower Construction Materials PPE Sorbents Recovery -Supervisor -Responder -Water Gate -Sand Bags -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box Environmental Considerations: - The barrier needs to be placed away from sensitive areas, (ideally) such as spawning sites. - Downstream water requirements should be monitored to prevent dewatering of sensitive areas. - Dewatering or poor water quality downstream may affect aquatic organisms. - This method may disrupt or contaminate sediments along or in the waterway. Category WL Model Specs for Floods and Water Control for Emergency Services WL -0630 WL -1450 WL -2050 WL -2650 WL -3950 WL -5050 WL -6050 Water Retention Height 6 in. 14 in. 20 in. 26.5 in. 39 in. 50 in. 60 in. Width of Gate 22 in. 56 in. 75 in. 96 in. 159 in. 207 in. 240 in. Length of Gate 30 ft. 50 ft. 50 ft. 50 ft. 50 ft. 50 ft. 50 ft. *Additional information can be found at www.water-gate.com 1.1: Prevention ©The Response Group 1.1.5) Prevention: Boom Anchoring: On Land and Water Boom Anchoring: On Land and Water Anchoring boom on water - Boon Deployn ent,Angles Relative to Current Velocity 4.0 3.5 m 3.0 2.5 o 2.0 E1 e' 1.5 • 1.0 0.5 0 0 10 20 30 40 50 80 70'' 8& 90 Room Deployment Angle Purpose: To anchor, or hold boom in place for nearshore or offshore boom deployment. Booming Strategy Application: - There are two basic types of anchoring: o On land (Anchor stakes, rope) o On water (Anchor, Chain, Rope, Buoy) - As shown in table above, boom deployment is determined by the current speed. - Boom must be angled at a steeper angle, relative to the current once the current speed is > 0.7 knots. Steps: Materials: Anchoring Boom on Land a.) If on land, place anchor stakes at an angle away from the water for strength (as shown in the photo above). More stakes will yield more holding strength b.) If on water, anchor boom at an angle relative to the current, making sure the anchors are held by watching the buoy. Ensure that the buoy is not moving once anchored. c.) Reposition as necessary Boom Equipment Manpower Hand Tools PPE -Boom, Bridle, Rope, Buoys, Anchor -Anchor Chain and/ or stakes -Workboat -Supervisor -Vessel Operator -Responder -Shovel -Stake Hammer -Gloves -Hard Hat Environmental Considerations: - Placement and maintenance of the anchoring points should not cause excessive physical disruption to the environment. - Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.6) Prevention: Boom Anchoring: On Land and Water Diversion Booming Purpose: To deflect spilled material around a sensitive site and downstream to a less sensitive site. Application: - Typically used in a one-way current i.e. river or stream vs. a two-way current i.e. tidal entrance. - May be used in waterways where the water flow is relatively fast i.e. > 1 knot. - Boom is deployed as a single strand or cascading arrangement (pictured above) to deflect spilled material around a sensitive site. - Spilled material may be removed further downstream at a pre -determined recovery site, not at the site of the diversion. Steps: Materials: a.) Identify sensitive area to protect. b.) Deploy Boom with the current upstream of the sensitive area, extending to the end, or beyond the sensitive area. c.) Maintain integrity of the boom, and monitor the situation. Boom Equipment Manpower Hand Tools PPE -Boom -Supervisor -Stake Driver -Tyvek Suit -Rope -Boat Operator -Boots -Boom Bridle -Responder/ Boat Crew -Gloves -Buoys -Respirator -Anchor -Life Jacket -Anchor Chain -Hard Hat -Anchor Stakes -Workboat Environmental Considerations: - Placement and maintenance of the anchoring points should not cause excessive physical disruption to the environment. - Boom must be maintained so that is does not trap oil improperly and cause additional damage to the sensitive area being protected. - Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.7) Prevention: Exclusion Booming Exclusion Booming Purpose: To prevent spilled material from entering a sensitive area i.e. delta, channel, bayou, river fork, bay, etc. Application: Placed across the entrance to a sensitive area. Deployed where the currents are <0.75 knots. Spilled material may be recovered or deflected by the exclusion boom. Steps: a.) Identify sensitive areas to exclude spilled material from entering. b.) Place boom across entrance at an angle dependent upon current speed. c.) Deflect spilled material if necessary. d.) Recover spilled material if necessary. e.) If applicable, line the shoreline in the collection area with sorbents. f.) Maintain integrity of the boom, and monitor the situation. Materials: Boom Equipment Manpower Hand Tools PPE Sorbents (If Applicable) Recovery (If Applicable) -Boom -Supervisor -Stake Driver -Tyvek Suit -Roll -Vacuum Truck -Rope -Boat Operator -Boots -Pad -Skimmer -Boom Bridle -Responder/ Boat Crew -Gloves -Pillows -Pumps -Buoys -Respirator -Socks -Fast Tank -Anchor -Life Jacket -Boom -Frac Tank -Anchor Chain -Hard Hat -Roll Off Box -Anchor Stakes -Workboat Environmental Considerations: Placement and maintenance of the anchoring points should not cause excessive physical disruption to the environment. Boom must be maintained so that is does not trap oil improperly and cause additional damage to the sensitive area being protected. Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.8) Prevention: Protection Booming Purpose: To prevent a sensitive site from being impacted by spilled material, whether below the surface, or exposed. Protection Booming Application: - Placed around a sensitivity, typically in currents <.75 knots, but may be deployed in faster moving waters, dependent upon booming angle relative to the current speed. - Spilled material will not be removed, only prevented from impacting the sensitivity. Steps: a.) Identify sensitive areas to prevent spilled material from impacting. b.) Place boom around sensitivity at an angle dependent upon current speed. c.) If necessary, line the shoreline or boom with sorbents as a second line of defense. d.) Maintain integrity of the boom, and monitor the situation. Materials: Boom Equipment Manpower Hand Tools PPE Sorbents (2°d Line of Defense) -Boom -Supervisor -Stake Driver -Tyvek Suit -Roll -Rope -Boat Operator -Boots -Pad -Boom Bridle -Responder/ Boat Crew -Gloves -Pillows -Buoys -Respirator -Socks -Anchor -Life Jacket -Boom -Anchor Chain -Hard Hat -Anchor Stakes -Workboat Environmental Considerations: - Placement and maintenance of the anchoring points should not cause excessive physical disruption to the environment. - Boom must be maintained so that is does not trap oil improperly and cause additional damage to the sensitive area being protected. - Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.9) Prevention: Containment Booming - Nearshore Purpose: To contain and prevent spilled material from advancing further downstream until it can be removed, either manually or mechanically. Containment Booming - Nearshore Application: - May be deployed where currents exceed 1 knot, dependent upon booming angle. - Contain the spilled material until it can be removed. - May be deployed in all types of waterways, i.e. rivers, streams, lakes, ponds, etc. Steps: a.) Identify a recovery site with good access for responders, by vehicle or boat. b.) Place boom at angle relative to the current speed to prevent entrainment or splash over. c.) If applicable, line the shoreline in the collection area with sorbents. d.) Recover spilled material either manually or mechanically. e.) Maintain integrity of the boom, and monitor the situation. Materials: Boom Equipment Manpower Hand Tools PPE Sorbents (If Applicable) Recovery -Boom -Supervisor -Stake Driver -Tyvek Suit -Roll -Vacuum Truck -Rope -Boat Operator -Boots -Pad -Skimmer -Boom Bridle -Responder/ Boat Crew -Gloves -Pillows -Pumps -Buoys -Respirator -Socks -Fast Tank -Anchor -Life Jacket -Boom -Frac Tank -Anchor Chain -Hard Hat -Roll Off Box -Anchor Stakes -Workboat Environmental Considerations: - Placement and maintenance of the anchoring points should not cause excessive physical disruption to the environment. - Boom must be maintained so that is does not trap oil improperly and cause additional damage to the sensitive area being protected. - Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.10) Prevention: Containment Booming - Offshore Containment Booming - Offshore Purpose: To contain spilled material until it can be removed mechanically. Application: - Deployed on the open water to contain free-flowing spilled material, driven by currents - Contain the spilled material until it can be removed. - Ends may be tethered between 2 response vessels or anchored. Steps: Materials: or wind. a.) Locate the spilled material, or identify a zone where spilled material may track towards (depending on a trajectory). b.) If anchored, deploy boom at an angle relative to the current/ water flow. c.) If towed by vessel, drive around spilled material, trapping it in the boom. d.) Recover spilled material mechanically. e.) Offload recovered material in liquid storage. f.) Maintain integrity of the boom, and monitor the situation. Boom Equipment Manpower PPE Sorbents (If Applicable) Recovery -Boom -Supervisor -Tyvek Suit -Pad -Skimmer -Rope -Boat Operator -Boots -Pillows -Pumps -Boom Bridle -Responder/ Boat Crew -Gloves -Socks -Fast Tank -Buoys -Respirator -Boom -Storage Barge -Anchor -Life Jacket -Anchor Chain -Hard Hat -Workboat Environmental Considerations: - Boom must be maintained so spilled material does not entrain or splash over the boom and cause additional damage to sensitive areas. - Traffic to/ from site should not disturb wildlife. 1.1: Prevention ©The Response Group 1.1.11) Prevention: Cold Weather Prevention Purpose: To contain spilled material until it can be removed manually or mechanically in cold weather (ice, snow) conditions. Cold Weather Prevention Application: - Can be used in cold weather scenarios. - Most effective cold weather applications include, but are o Earthen dams o Culvert damming/ sealing o Filter barriers Steps: Materials: not limited to the following: a.) Determine width and speed of waterway. b.) Determine implementation one of three prevention techniques identified above. 1.) If the water is deep, an underflow dam may be used. 2.) If shallow/ slow moving, a filter barrier or earthen dam may be created. c.) If applicable, line the barrier with plastic sheeting. d.) Line the shoreline in the collection area with sorbents. e.) Recover spilled material. f.) Maintain integrity of construction, monitor situation Equipment Manpower Construction Materials Hand Tools PPE Sorbents Recovery -Front-end Loader -Backhoe -Supervisor -Equipment Operator -Responder -Dirt -Plastic sheeting -Gravel -Sand Bags -Wooden Board -Straw Bales -Shovel -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Cold weather -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box Environmental Considerations: - Access to the site may disturb local wildlife. - Dewatering or poor water quality downstream may affect aquatic organisms. - This method may disrupt or contaminate sediments along or in the waterway. 1.1: Prevention ©The Response Group Section 1.2: Recovery and Removal Section 1.2 Table of Contents 1.2 Recovery and Removal Section Name 1.2.1 Natural Recovery 1.2.2 Physical Herding 1.2.3 Manual Removal 1.2.4 Mechanical Removal — On Land 1.2.5 Mechanical Removal — On Water 1.2.6 Debris Removal 1.2.7 Sorbent Deployment 1.2.8 In -Situ Burning: On Water and Land 1.2.9 Cold Weather Recovery: Manual 1.2.10 Cold Weather Recovery: Mechanical Inland Spill Response Tactics Guide ©The Response Group 1.2.1) Recovery and Removal: Natural Recovery Purpose: This method is used where there is no attempt to remove stranded oil in order to minimize impact to the environment. This is because there is no proven effective method for cleanup, or the area is too unsafe for responders to enter. Natural Recovery Application: - No action is taken, although monitoring of the incident continues. - This may be applicable for all types of habitats. - Typically used on remote or inaccessible habitats, when natural removal rates are very fast. o Steep cliffs with high energy waves/ currents o River canyons o Waterfalls o Evaporation of gasoline Steps: a.) Monitor situation Materials: Equipment Manpower PPE Recovery -Vessel -4X4 Vehicle (Dependent upon location) -Equipment Operator -Observer -Life Jacket -N/A Environmental Considerations: - This method may be inappropriate where high numbers of mobile animals or endangered species use the waterway. o Birds, Terrestrial animals - As there is little human -interaction, the effects should be from oiling only. 1.2: Recovery and Removal ©The Response Group 1.2.2) Recovery and Removal: Physical Herding Purpose: To free oil trapped •n debris or vegetation on the water; to direct the movement of floating oil towards containment and recovery devices; or to push oil away from sensitive areas. Physical Herding Application: - Can be implemented in two ways to generate a current to dislodge trapped oil and herd the released oil to containment and recovery area. o Water/ air streams o Propeller wash - Best used in low energy environments as the wash/ surface current will be the driving factor towards recover of the spilled material. o Lakes and ponds o Bayous o Slow-moving rivers or streams - If not already, emulsified oil will form when the recently released oil is washed out. Steps: a.) Locate free-floating or stranded spilled material. b.) Use one of the two methods described above to mobilize the spilled material towards the recovery devices. c.) Contain and recover spilled material. Materials: Equipment Manpower PPE Sorbents Recovery Storage -Vessel Jon Boat Air Boat - 4X4 Vehicle -Wash Pump -Suction and Spray Hose -Supervisor -Boat Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Vacuum Truck -Skimmer -Pumps -Fast Tank -Frac Tank -Roll Off Box -Storage Barge Environmental Considerations: - This activity may generate high levels of suspended sediments and mix them with the spilled material, resulting in deposition of contaminated sediments in benthic habitats. - Traffic to/ from site should not disturb wildlife. 1.2: Recovery and Removal ©The Response Group 1.2.3) Recovery and Removal: Manual Removal Manual Removal Purpose: To remove spilled material on the water or land with hand tools and manual labor to supplement mechanical removal or where mechanical removal is insufficient. Application: - Several different tools available for manual removal (but are not limited to) include following: o Rakes o Shovels o Buckets o Nets o Rags Can be used where light to moderate impact has occurred on the shorelines, or heavy spilled material is floating and has formed semi-solid to solid masses that can be picked up manually. Steps: a.) Locate spilled material. b.) If on land (dependent upon environmental considerations) use shovels, buckets, etc to remove spilled material. c.) Use sorbents to supplement removal when applicable. d.) If on water, use buckets, nets, etc. to recover spilled material. e.) Material may be stored in roll -offs once retrieved until waste services retrieve it. Materials: Equipment Manpower Hand Tools PPE Sorbents Storage -Vessel - 4X4 Vehicle -Wash Pump -Suction and Spray Hose -Supervisor -Boat Operator -Responder -Rakes -Shovels -Buckets -Nets -Rags - Trash Bags -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Trash Bags -Buckets -Dumpster -Conex Box -Roll Off Box -Drum Environmental Considerations: - Foot traffic over sensitive areas needs to be restricted or prevented. There may be periods when access should be avoided such as bird nesting. 1.2: Recovery and Removal ©The Response Group 1.2.4) Recovery and Removal: Mechanical Removal - On Land Mechanical Removal - On Land Purpose: To remove spilled material with mechanical equipment to supplement manual removal, or where manual removal is insufficient. Application: - Impacted sediments are collected and removed using (but not limited to) the following: o Backhoe o Front -End Loader o Bobcat o Bulldozer - The material is pushed into piles and transported offsite to treatment/ disposal. - Sand and saw dust may be applied to collect spilled material on the surface to enhance recovery efforts. - Use carefully where excessive sediment removal may erode the beach. - Need special permission to use in private areas or those with known cultural resources. Steps: a.) Locate spilled material. b.) Utilize heavy equipment to compile the material into a manageable area. c.) If needed, mix spilled material with sand or sawdust. d.) Use sorbents to supplement removal when applicable. e.) Offload recovered material/ debris into storage vehicles or roll off boxes to be transported for waste disposal. Materials: Equipment Manpower PPE Sorbents Storage - 4X4 Vehicle -Backhoe -Trackhoe -Front-End Loader -Bobcat -Bulldozer -Supervisor -Equipment Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Dumpster -Conex Box -Roll Off Box -Drum Environmental Considerations: - Heavy equipment is environmentally intrusive, along with the support personnel required. - Sediment removal and erosion and subsequent runoff into adjacent bodies of water. 1.2: Recovery and Removal ©The Response Group 1.2.5) Recovery and Removal: Mechanical Removal - On Water Purpose: To remove spilled material with mechanical equipment to supplement manual removal, or where manual removal is insufficient. Mechanical Removal - On Water Application: - Equipment is operated from the shore or on the water to recover significant amounts of spilled material. - May be used on any type of waterway, either near or away from the shoreline. - There are many different types of recovery methods and materials applicable to on water mechanical recovery. Steps: a.) Locate spilled material. b.) Contain material, typically done with boom. c.) If needed, mix spilled material with sand or sawdust. d.) Use sorbents to supplement removal when applicable. e.) Offload recovered material/ debris into storage vehicles or roll off boxes to be transported for waste disposal. Materials: Equipment Manpower PPE Sorbents (If Applicable) Storage -Boom - Vessel -Skimmer -Vac Truck -Pumps -Supervisor -Boat Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Life Jacket -Roll -Pad -Pillows -Socks -Boom -Fast Tank -Frac Tank -Storage Barge -Drum Environmental Considerations: - Limit boat traffic in shallow water environments i.e. marsh grass, submerged vegetation. - Monitor marine life in the area to ensure their safety during recovery operations. 1.2: Recovery and Removal ©The Response Group 1.2.6) Recovery and Removal: Debris Removal Purpose: To remove impacted debris or debris in the path of potential impact and expedite the cleanup process. Debris Removal Application: - Two types of debris removal exist: o Manual o Mechanical - Debris removal should be conducted when driftwood and debris is or may soon be contaminated and provide a potential source of release to the environment. - Unless removed, impacted debris may be a source of contamination for organisms in the area. Steps: a.) Locate impacted debris or pre -identify areas that need to be removed of debris. b.) Recover debris manually or mechanically, based on the situation or site access. c.) Offload recovered material/ debris into storage vehicles or roll off boxes to be transported for waste disposal. d.) Line the shoreline with sorbents to soak up any residual material if necessary. Materials: Equipment Manpower Hand Tools PPE Sorbents Storage -Vessel -Supervisor -Rakes -Tyvek Suit -Roll -Dumpster - 4X4 Vehicle -Equipment Operator -Shovels -Boots -Pad -Conex Box -Backhoe -Boat Operator -Buckets -Gloves -Pillows -Roll Off Box -Trackhoe -Responder - Trash Bags -Respirator -Socks -Drum -Front-End Loader -Hard Hat -Boom -Bobcat -Life Jacket -Bulldozer Environmental Considerations: - Foot traffic over sensitive areas needs to be restricted or prevented. There may be periods when access should be avoided such as bird nesting. - There may be physical disruption of the associated substrate, especially when equipment must be deployed to recover a large quantity of debris. 1.2: Recovery and Removal ©The Response Group 1.2.7) Recovery and Removal: Sorbent Deployment Sorbent Deployment Purpose: To remove spilled material by absorption onto oleophilic materials placed in on the water, along the shoreline, or on land. Application: Sorbents can be placed in any environment. Sorbent material is placed on the contaminated area, soaking up the spilled material. Sorbents must be removed and replaced at a constant rate, as it loses efficacy once it has absorbed the spilled material. Sorbents are often used as a secondary treatment method after gross, initial removal has taken place and in sensitive areas where access/ equipment is restricted. Steps: a.) Locate the area for sorbent application b.) Place sorbents on the impacted area c.) Once sorbents have lost efficacy, remove, replace and store spent sorbents in solid storage for proper waste disposal. Materials: Equipment Manpower PPE Sorbents Storage -Vessel -Boat Operator -Tyvek Suit -Roll -Dumpster -4X4 Vehicle -Responder -Boots -Pad -Conex Box (Dependent upon location) -Gloves -Pillows -Roll Off Box -Respirator -Socks -Drum -Hard Hat -Boom -Life Jacket -Snare boom/ pom poms Environmental Considerations: - Access for deploying and retrieving sorbents should not affect soft or sensitive habitats or wildlife. - Sorbent use should be monitored to prevent overuse and generating large volumes of waste. - When the sorbents are no longer effective, spilled material may remain in critical habitats. 1.2: Recovery and Removal ©The Response Group 1.2.8) Recovery and Removal: In -Situ Burning: On Water and Land In -Situ Burning: On Water and Land Purpose: To remove spilled material from the environment by burning. Application: - MUST have regulatory approval. - Oil floating on the water surface is collected into slicks >2 mm thick and then ignited. - Methods if ignition: o Handheld torch o Heli -torch - The oil can be contained in fire resistant booms, or natural barriers. - On shore, oil is burned usually when it is on a combustible substrate i.e. vegetation, debris. - Oil can be burned off non-flammable substrate using a burn promoter. - On sedimentary substrates, it may be necessary to dig trenches for oil to accumulate in pools thick enough effectively burn. - Heavy and emulsified oils are harder to ignite and sustain an efficient burn, but are burnable. Steps: Materials: a.) Get approval from agencies prior to ignition. b.) Locate the area to be burned. c.) If offshore, corral with fire boom. If on land, dig a trench to promote pooling. d.) Choose a safe method to ignite the requested area. e.) Maintain a safe distance from the fire and then recover equipment once the fire has burned out. Equipment Boom Equipment Manpower PPE -Vessel -Helicopter -Torch -Fire Boom -Rope -Bridle -Anchor -Buoy -Supervisor -Boat Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Life Jacket Environmental Considerations: - Large volumes of smoke are generated, and its effect on nesting birds and populated areas should be evaluated. 1.2: Recovery and Removal ©The Response Group 1.2.9) Recovery and Removal: Cold Weather Recovery: Manual Cold Weather Recovery: Manual Purpose: To remove spilled material on the water or land with hand tools and manual labor to supplement mechanical removal or where mechanical removal is insufficient. Application: Several different tools available for manual removal (but are not limited to) include the following: o Rakes o Pick Axe o Shovels o Buckets o Hand -Powered Auger - Most effective when used in combination with mechanical recovery as the surface/ substrate may be too frozen for manual recovery alone. Steps: Materials: a.) If applicable, locate spilled material by prodding below the surface with a stick or pole to determine the boundaries of the impacted area. b.) If spilled material is on the surface, snow can be used as a sorbent, to be scooped up and placed into a storage bin/ pit and recovered by skimmers. c.) If spilled material is under the surface i.e. ice, use an auger or shovel to punch a hole or dig a trench to identify location of spilled material. d.) The spilled material will naturally move to the opening, but may need to be herded under the ice via wash pump, flushing. e.) Once spilled material is on the surface, recover with vacuum trucks and skimmers and store for disposal unit Equipment Manpower Hand Tools PPE Sorbents Storage - 4X4 Vehicle -Supervisor -Rakes -Tyvek Suit -Roll -Trash Bags - Auger -Responders -Shovels -Boots -Pad -Buckets -Buckets -Gloves -Pillows -Dumpster - Trash Bags -Respirator -Socks -Conex Box -Life Jacket -Boom -Roll Off Box -Hard Hat -Drum -Cold Weather Environmental Considerations: Review the area to make sure species are not in proximity to the work being conducted. - Limit foot traffic by creating a walking path with wooden boards if necessary. 1.2: Recovery and Removal ©The Response Group 1.2.10) Recovery and Removal: Cold Weather Recovery: Mechanical Cold Weather Recovery: Mechanical Purpose: To remove spilled material with mechanical equipment to supplement manual removal, or where manual removal is insufficient. Application: - Several different tools available for manual removal (but are not limited to) include the following: o Backhoe o Front -End Loader o Bobcat o Bulldozer o Auger Determine the thickness of the ice and the feasibility of driving heavy equipment on the ice. Once ice is determined to be thick enough, drill a series of holes to: 1.) Identify the location of the spilled material. 2.) Allow the spilled material to float to the surface. Once the spilled material has been located, flush, or herd the material to the hole with wash pumps, and recover with skimmers and vacuum trucks. Steps: a.) Drill holes to identify the location of the spilled material; a gridded system works well to locate boundaries of the impacted area. b.) Once the area has been identified, dig a trench to allow more spilled material to come to the surface. Do not place heavy equipment where the strength of the ice has been compromised due to drilling holes. c.) Once on the surface, recover spilled material with vacuum trucks and skimmers Materials: Equipment Manpower PPE Sorbents Storage - 4X4 Vehicle -Supervisor -Tyvek Suit -Roll -Dumpster -Backhoe -Equipment Operator -Boots -Pad -Conex Box -Trackhoe -Responder -Gloves -Pillows -Roll Off Box -Front-End Loader -Respirator -Socks -Drum -Bobcat -Hard Hat -Boom -Bulldozer -Auger Environmental Considerations: - Review the area to make sure species are not in proximity to the work being conducted. 1.2: Recovery and Removal ©The Response Group Section 1.3 Table of Contents 1.3 Cleaning Section Name 1.3.1 Pressure Flushing 1.3.2 Flooding 1.3.3 Steam Cleaning 1.3.4 Sediment Reworking 1.3.5 Vegetation Removal 1.3.6 Sand Blasting 1.3.7 Decontamination 1.3.8 On Water Decontamination Inland Spill Response Tactics Guide ©The Response Group 1.3.1) Cleaning: Pressure Flushing Pressure Flushing Purpose: To remove spilled material that has adhered to the substrate or manmade structures, pooled on the surface, or trapped in vegetation. Application: Variety of use in all habitats assuming the proper pressure is used. o High pressure is applicable on hard surfaces i.e. manmade structures, rip rap, etc. o Low pressure is necessary for softer substrates i.e. marsh/ wetlands Method should lift oil from the substrate and mobilize it to the water's edge for pickup. May be combined with a flooding system to prevent re -adhesion to the substrate. Efficient cleaning method when sorbents and vacuum/ skimmers are available for recovery. Steps: a.) Locate spilled material that has been stranded. b.) Determine best flushing method (high pressure vs. low pressure). c.) Spray water onto surface. d.) Recover spilled material with available method: vacuum truck, skimmer, sorbents. Materials: Equipment Manpower PPE Sorbents Recovery - Vessel -Vehicle (Dependent upon location) -Wash Pump -Hose with spray nozzle -Supervisor -Equipment Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Snare/ Pom Poms -Vacuum Truck -Skimmer -Boom Environmental Considerations: - Not appropriate where nearshore sediments contain rich biological communities. - May need to restrict use to prevent the drainage from traveling to adjacent areas. - Flushing from vessels would reduce the amount of foot traffic on substrate. - May drive the spilled material deeper into the substrate if administered improperly. - Hot water can kill organisms in direct contact. 1.3: Cleaning ©The Response Group 1.3.2) Cleaning: Flooding Flooding Purpose: To wash or transport spilled material that has been stranded on land to the water's edge for collection. Application: A perforated header pipe or hose is placed above the impacted area, relative to the drainage slope. Ambient water is pumped through the header pipe at low pressures and flows down slope. On porous sediments, water flows through the substrate, pushing the loose oil, or floating it. Flow is maintained to remove the majority of free oil. Oil is trapped by booms and is recovered by skimmers or other suitable equipment. Steps: a.) Locate spilled material that has been stranded. b.) Flush material to water's edge. c.) Trap material with booms. d.) Recover with vacuum trucks, skimmers, or sorbents. Materials: Equipment Manpower PPE Sorbents Recovery - Vessel -Vehicle (Dependent upon location) -Wash Pump -Hose or perforate pipe -Supervisor -Equipment Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Snare/ Pom Poms -Vacuum Truck -Skimmer -Boom Environmental Considerations: - Not appropriate where nearshore sediments contain rich biological communities. - Habitat may be physically disturbed by foot traffic during operations and contaminated by sediments washed down the slope. - Oiled sediment may be transported to shallow nearshore areas, therefore contaminating the environment and burying the associated benthic organisms. 1.3: Cleaning ©The Response Group 1.3.3) Cleaning: Steam Cleaning Steam Cleaning Purpose: To remove residual oil from rigid surfaces where flushing and pressure washing is less effective. Application: - Steam or very hot water (170°F to 212°F) is manually sprayed with hand wands at high pressure. - Water runoff volumes are much lower when compared to flushing methods. - Most applicable on manmade structures. o Seawalls o Rip Rap Applied when heavy oil residue remaining on a surface needs to be cleaned for aesthetic reasons. - May be combined with a flooding system to prevent re -adhesion to the substrate. Steps: a.) Locate spilled material that has been stranded. b.) Rinse spilled material to water's edge. c.) Trap material with booms. d.) Recover with vacuum trucks, skimmers, or sorbents. Materials: Equipment Manpower PPE Sorbents Recovery - Vessel -Vehicle (Dependent upon location) -Wash Pump -Steam cleaner -Generator -Supervisor -Equipment Operator -Responder -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Snare/ Pom Poms -Vacuum Truck -Skimmer -Boom Environmental Considerations: - Not to be used in areas of soft substrate, vegetation, or high biological abundance directly on or below the structure. - Complete destruction of all organisms directly in the spray zone. 1.3: Cleaning ©The Response Group 1.3.4) Cleaning: Sediment Reworking Sediment Reworking Purpose: To rework/ mix up impacted sediments to break up the deposits, increase its surface area, and mix deep subsurface oil layers, which will expose the material to natural removal processes and enhance the rate of oil degradation. Application: - The impacted sediments are either manually or mechanically mixed. o Manual tools include (but not limited to): Shovels, rakes, etc. o Mechanical equipment includes (but not limited to): backhoe, trackhoe, etc. - Along lake shores, impacted sediments may also be pushed lower on the shore to enhance natural cleanup from reworking by wave activity. The process may be aided with high-volume flushing in coarse substrates i.e. gravel, rocks. - Applicable where erosion is a factor, this method leaves the sediment in place, or where a crust has formed, unable to be pressure washed or flushed. - Appropriate for sites where oil is stranded on land or above the normal water level. Steps: a.) Locate contaminated area. b.) Mix up sediments either manually or mechanically to an acceptable depth. c.) If applicable, recover spilled material with sorbents to extent possible. Materials: Equipment Manpower Hand Tools PPE Sorbents -Backhoe -Trackhoe -Bulldozer -Front-end Loader -Supervisor -Equipment Operator -Responder -Shovels -Rakes -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks Environmental Considerations: - Avoid using on shores near water intakes, fish spawning areas, or near bird -nesting sites. - Spilled material may potentially be released and enter adjacent bodies of water. - Potential to expose organisms below the original layer of impacted sediments. 1.3: Cleaning ©The Response Group 1.3.5) Cleaning: Vegetation Removal Vegetation Removal Purpose: To cut and remove oiled vegetation to prevent oiling of wildlife or chronic oil releases. Application: - Typically removed via weed -eater above the water line. - Cut vegetation is raked up. - Floating and submerged vegetation is either removed manually or mechanically. - Applicable in areas composed of emergent, herbaceous vegetation and floating aquatic vegetation. o Wetland o Bog o Overgrown shorelines of lakes, rivers, etc - Used when the risk of oiled vegetation contaminating wildlife is greater than the value of the vegetation, and there is no less destructive method that removes or reduces the risk to acceptable levels. o Wildlife Management Area Steps: a.) Locate contaminated vegetation. b.) Cut and remove contaminated vegetation. c.) Store in solid waste containers for disposal. Materials: Equipment Manpower Hand Tools PPE Sorbents Storage -Backhoe -Trackhoe -Bulldozer -Front-end Loader -Supervisor -Equipment Operator -Responder -Shovels -Rakes -Weed Eater -Tyvek Suit -Boots -Gloves -Respirator -Life Jacket -Hard Hat -Roll -Pad -Pillows -Socks -Boom -Dumpster -Conex Box -Roll Off Box -Drum Environmental Considerations: - Operations must be strictly monitored to minimize root destruction and deeper mixing of oil. - Access in bird -nesting areas should be avoided during nesting seasons. - Vegetation removal will destroy habitat for many animals. - Along exposed shorelines, the vegetation may not re -grow, eroding and destroying the habitat. - Trampled areas will recover slowly. 1.3: Cleaning ©The Response Group 1.3.6) Cleaning: Sand Blasting Purpose: To remove heavy residual oil from solid substrates. Sand Blasting Application: - Sandblasting equipment is necessary. - In some cases, may include recovery of oiled sand. - Applicable on manmade structures such as seawalls and rip rap, not recommended on wood. Steps: a.) Locate contaminated area. b.) Blast/ break up spilled material. c.) Recover sand/ oil mix manually or mechanically. d.) If applicable, recover spilled material with sorbents to extent possible. e.) Place recovered material into solid storage for future waste disposal. Materials: Equipment Manpower Hand Tools PPE Sorbents -Backhoe -Supervisor -Shovels -Tyvek Suit -Roll -Trackhoe -Equipment Operator -Rakes -Boots -Pad -Bulldozer -Responder -Gloves -Pillows -Front-end Loader -Respirator -Socks -Sand Blaster -Life Jacket -Hard Hat -Mask Environmental Considerations: - Not to be used in areas of soft substrate, vegetation, or high biological abundance directly below or adjacent to the structures. - Complete destruction of all organisms in the blast zone. - When used sand is not recovered, oiled sediments may be introduced to the adjacent habitat. 1.3: Cleaning ©The Response Group 1.3.7) Cleaning: Decontamination Decontamination Purpose: To safely decontaminate equipment and personnel that have been in the field. Application: The decon area should be located on a flat surface and at a safe distance from the response site, taking into consideration wind directions and air monitoring readings. Decon facilities should be located in the contamination reduction zone. The level and type of decontamination required is dependent upon the following: o Chemical, physical toxicological properties of the waste o Amount, location, and containment of contaminants o Potential for exposure on worker duties o Potential for waste to permeate, degrade, penetrate PPE 3 types of decontamination o Physical — water rinse, scrubbing/ scraping, dislodging o Chemical — dissolving, solidification, sterilization — must be chemically compatible with equipment being cleaned o Physical & Chemical — chemical solution/ water rinse scrub down Steps: a.) Establish an area suitable for decontamation. b.) Deploy impermeable canvas to contain the material removed from personnel/ equipment. c.) Determine whether physical or chemical decon be used, deploy the chosen method. d.) Test for effectiveness of decontamination. a. Visual (check for discoloration, stains, corrosion, etc) b. Wipe Sampling (swab is analyzed) c. Cleaning solution analysis (contaminants remaining in cleaning solution) d. Presence of permeated chemicals (garments sent to a lab) e.) Conduct air monitoring. f.) Monitor site integrity. 1.3: Cleaning ©The Response Group 1.3.7) Cleaning: Decontamination Materials: Equipment Manpower Hand Tools PPE Sorbents Storage -Pressure washer -Vacuum truck -Air monitoring equip. -Supervisor -Equipment Operator -Decon specialist -Shovels -Rakes -Buckets -Brushes -Tyvek Suit -Boots -Gloves -Respirator -Hard Hat -Mask -Boom -Roll -Pad -Pillows -Socks - Dumpster -Conex Box -Roll Off Box -Drum -Frac Tank -Fast Tank Environmental Considerations: - Ground/ area must be cleared prior to site set up. - Potential for contaminant runoff if impermeable barriers are improperly installed. Heavy equipment and foot traffic in and around the area. • Site Work Zone Contaminated Reduction Corridor Prevailing Wind Direction Access Control Points Support Zone Hotline Contamination Control Line 1.3: Cleaning ©The Response Group 1.3.7) Cleaning: Decontamination Level A Protection: Maximum Layout EXCLUSION ZONE Outer Glove Tape Boot Cover & Removal Removal Glove Wash Boot Cover Boot Cover & Removal Glove Rinse Suit/Safety Boot Wash Tank Change 9 �- $ Suit/Safety Boot Rinse and Redress - Boot Covera Outer Gloves 1 U Suit/Safety Removal ■ 11 Fully Encapsulating Suit and Hard Hat Removal CONTAMINATION REDUCTION 12 SCBA Backpack Removal ZONE ,y 13 Inner Glove Wash 14 Inner Glove Rinse 15 Face Piece Removal i 16 Inner Glove Removal 17 Inner Clothing Removal Field Wash 18 '1.9 Redress Segregated Equipment Drop HOTLINE CONTAMINATION CONTROL LINE SUPPORT ZONE 1.3: Cleaning ©The Response Group 4 Level B Protection: Maximum Layout EXCLUSION ZONE Outer Glove Tape Boot Cover & Removal Removal Glove Wash 40-4-40-4-111.4-04-404-0 Boot Cover Boot Cover & Removal Glove Rinse 7 SultiSafety Boot Wash ■ Tank Change g Ei 8 SuitISCBAIBootlGlove Rinse and Redress - Boot Cover/ Outer Gloves 1y0 Safety Boot Removal 11 SCBA Backpack Removal CONTAMINATION REDACTION 12 Splash Suit Removal ZONE 13 Inner Glove Wash 14 Inner Glove Rinse T 15 Face Prece Removal 7 16 Inner Glove Removal 17 Inner Clothing Removal Field Wash Segregated Equipment Drop HOTLINE CONTAMINATION CONTROL LINE Hill Redress SUPPORT ZONE 1.3: Cleaning ©The Response Group 1.3.7) Cleaning: Decontamination Level C Protection: Maximum Layout EXCLUSION ZONE Outer Glove Tape Boot Cover & Removal Removal Glove Wash Boot Cover Boot Cover & Removal Glove Rinse 7 Suit1Safety Boot Wash ■ Canister or 9 8 SuitlSafety Boot Rinse Mask Change and Redress - Boot Cover/ ■ Outer Gloves 10 Safety Boot Removal ■ 11 Splash Suit Removal CONTAMINATION ■ REDUCTION 12 Inner Glove Wash ZONE 13 Inner Glove Rinse 14 Face Piece Removal ■ 15 inner Glove Removal ■ 16 Inner Clothdng Removal Field Wash 17 18 Redress Segregated Equipment Drop HOTLINE CONTAMINATION CONTROL LINE SUPPORT ZONE 1.3: Cleaning ©The Response Group Appendix Appendix Table of Contents Section Appendix Name A Small Boat Safety B Materials of Opportunity for Spill Response C Types of Skimmers for Inland Waterways Inland Spill Response Tactics Guide ©The Response Group Appendix A) Small Boat Safety Small Boat Safety The following guidelines should be followed when personnel are boarding a vessel: 1. Maintain three points of contact at all times for proper balance. 2. Become familiar with the layout of the boat. 3. Know where emergency equipment (e.g., fire extinguishers, life jackets, life rings, and life rafts) is stored. 4. Know how to use emergency equipment. 5. Have and wear a U.S. Coast Guard approved personal flotation device. 6. Wear proper clothing. While onboard a vessel, personnel should: 1. Follow the instructions of the Vessel Captain about their actions on the vessel. 2. Follow the instructions of the supervisor about the performance of their duties in the response effort. 3. Watch out for slippery deck surfaces, especially if they are covered or stained with oil. 4. Use sorbent pads to clean up oil and/or to improve traction along walkways. 5. Use safety lines when working on the deck. 6. Watch out for erratic boat motions in rough water. 7. Avoid taking medicines for seasickness if they make you drowsy. 8. Know their location and surrounding circumstances, and avoid being distracted by the task at hand. 9. Be aware of ropes and lines on deck. 10. Wear gloves when working with ropes or cables to avoid burns and cuts. 11. Wear a life jacket at all times. 12. Keep safety railings and/or chains in place until it is necessary to remove them to work; replace the railings and/or chains as soon as possible. Personnel should know what to do should they fall overboard into cold water. Their bodies will lose heat many times faster in the water than in the air, especially from the head, neck, armpits, and groin. While they are in the water they should: 1. Orientate themselves to floating hazards around them. 2. Move away from hazards if they are in danger; otherwise stay put until they are rescued. 3. Look for a flotation aid thrown from a vessel. 4. Avoid unnecessary movement of their arms and legs. 5. Float as still as possible, with legs together, elbows close to sides, and arms folded across the front of the life jacket. 6. Try to keep head and neck out of the water. 7. Stay calm. 8. Try to raise an alarm; if the life jacket has a light or whistle, use it. 9. Attempt to swim back to the vessel only if it is close at hand. Appendix A ©The Response Group Appendix A) Small Boat Safety If personnel observe someone falling overboard, they should: 1. Keep their eyes on the victim. 2. Point to the victim while raising the alarm; notify others by calling "man overboard." 3. Throw a flotation aid to the victim - not at the victim, but near enough so that he/she can easily swim to the device. If the victim is rational but shivering when he/she is pulled onboard, he/she should put on dry clothes or a blanket, and rest in a warm environment. If the victim is semiconscious or unconscious, personnel should: 1. Check for breathing and heart beat; administer artificial respiration or CPR, if necessary. 2. Move the victim to a warm environment. 3. Remove the victim's clothes, but never massage the skin. 4. Wrap the victim in a blanket to prevent further heat loss. 5. Never attempt aggressive warming. 6. Attempt gentle rewarming by placing a bottle filled with warm water next to the victim's head, neck, armpits, or groin. Appendix A ©The Response Group Appendix B) Materials of Opportunity for Spill Response Materials of Opportunity for Spill Response B.1) Pre -Cut Wood: Type Use Plywood Construction of underflow dams, berms, and barriers, walkway to site across muddy terrain Particle Board Construction of underflow dams, berms, and barriers, walkway to site across muddy terrain 2X6 and Smaller Dam and barrier support, boom anchoring 2X6 and Larger Dam and barrier support, underflow dams, berms, and barriers, walkway to site across muddy terrain B.2) Metals: Type Type Use Fence Post (T -Post) Anchoring boom Pipe (< 4" dia.) Anchoring boom, small scale underflow dam Pipe (> 4" dia.) Small scale to large scale underflow dam Chainlink Fence Filter barrier when used in combination with hay, or sorbents B.3) Plastics or Similar: Type PVC Pipe, All Sizes Sheeting Use Underflow dam piping Layer of impermeabilty for an underflow dam, berm, or barrier B.4) On -Site Earthen Materials Type Use Grass Sorbent Twigs and Logs Base -layer for construction of a dam, berm, barrier, temporary walkway to site across muddy terrain Rocks Underflow dam and small scale boom anchor, dependent upon size of rock Trees (still in -ground) Boom anchoring Dirt Dam, berm and barrier construction, Appendix B ©The Response Group Appendix C) Typical Skimmers C.1) Disc Skimmer: Purpose: To recover oil that has been collected by boom or trapped in a geographic area such as a harbor or cove. Description: A disc skimmer is made up of oleophilic discs that spin downward into the spilled material. The discs have scrapers that will then scrape off what has been recovered into a sump in the center of the device and then removed by an attached hose. It is effective at separating oil from water. Use: Ideal use includes shallow or calm waters, but may be used in offshore situations if the environmental conditions warrant its use. The sump screen may jam with debris, resulting in manual removal and cleaning of the device. Specifications: Recovery rates are dependent upon size of the unit and number of discs. Smaller units have an EDRC of —300 bbls of oily water liquid while larger units may have around 1500 bbls of oily water liquid. The model shown above, the Vikoma 12K skimmer has an EDRC just above 500 bbls. 2-3 operators needed. Ancillary Equipment: Pump, Powerpack, Liquid Storage Container C.2) Drum Skimmer: Purpose: To recover oil that has been collected by boom or trapped in a geographic area such as a harbor or cove. Description: A disc skimmer is made up of one or more oleophilic drums that spin downward into the spilled material. The drums have scrapers that will then scrape off the recovered material into a sump or collection bin and then removed by an attached hose. Use: Ideal use includes shallow or calm waters, and is not effective in high energy conditions, i.e. offshore. The collection resulting in manual removal and cleaning of the device. Specifications: Recovery rates are dependent upon size of the unit and number of drums. Smaller units have an EDRC of —200 bbls of oily water liquid while larger units may have around 500 bbls of oily water liquid. 2-3 operators needed. bin or sump screen may jam with debris, Ancillary Equipment: Pump, Powerpack, Liquid Storage Container Appendix C ©The Response Group Appendix C) Typical Skimmers for Inland Waterways Response AM! C.3) Weir Skimmer: Purpose: To recover oil that has been collected by boom or trapped in a geographic area such as a harbor or cove. Description: A weir skimmer is composed of floats, a weir lip (over which the oil flows), a central float, and a sump, connected to a hose for suction. Use: This type of weir may be used in a variety of settings from shallow, calm water to more open, high- energy water (offshore). As with all skimming types, it is more effective in calmer conditions. Specifications: Recovery rates are dependent upon size of the unit and the pumping rate. Smaller units have an EDRC of 1500 bbls of oily water liquid while larger units may have around 6000 bbls of oily water liquid. 1-3 operators needed. Ancillary Equipment: Pump, Powerpack, Liquid Storage Container C.4) Manta -Ray Skimmer: Purpose: To recover oil that has been collected by boom or trapped in a geographic area such as a harbor or cove. Description: A manta ray is a single system skimmer with no major components. It floats at the water surface and is connected to a pump or vac truck for suction. The oil is skimmed through the manta ray and placed into a storage container (fast tank, vac truck, etc.) Use: Typically used in nearshore or calm -water environments. Specifications: Recovery rates are dependent upon the pumping rate of the attached unit (Pump or Vac Truck). It has %z" or 1" suction openings. The %z" opening gets — 80 gpm capacity and 1" opening gets — 150 gpm. 2"-4" couplings for hoses. Ancillary Equipment: Pump, Vacuum Truck, Liquid Storage Container Appendix C ©The Response Group Weed Management Plan Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 ►�1','MN MarathonOil Weed Management Plan November 22, 2013 Introduction Marathon Oil ("Marathon") has developed this Weed Management Plan to address noxious and undesirable, non-native weed species that may occur on land owned, leased, or managed by Marathon in Garfield County, Colorado. This plan will serve as a guide to direct integrated weed management efforts in controlling weed species that have been recognized by Federal, state, and local authorities as invasive and/or detrimental to ecosystem health in the areas in which Marathon operates. Priority will be given to those species that have the highest potential to disrupt ecological functions, impair native plant communities, and degrade wildlife habitat. Background Effective weed management relies on utilizing various proven methods to control and treat weed infestations. Marathon will employ an integrated approach to controlling targeted weed species through preventative, cultural, mechanical, biological, and chemical methods, where appropriate. The aforementioned methods are described as follows: • Preventative: Prevention is the first and perhaps most -important step in weed management, and includes, but is not limited to, quickly reseeding disturbed areas with weed -free seed, using only certified weed -free straw and straw bales for mulch and organic stormwater control BMPs, using equipment free of weed seeds during reclamation work, and eliminating weed infestations on lands surrounding reclaimed or disturbed areas; • Cultural: Including, but not limited to, establishing and maintaining an adequate population of desirable vegetation to compete with weeds, mulching to inhibit weed seed germination and growth, and using weed barriers; • Mechanical: Including, but not limited to, hand pulling, hoeing, mowing, and tillage; • Biological: Utilizing natural enemies, such as insects or other biological organisms, to control specific weed species; and • Chemical: Using herbicides to control weed species with consideration given to herbicide selection, timing of application, target weeds, desirable extant and/or planted vegetation, number of treatments per year, and the number of years a particular species will need to be treated for desired control. Piceance - 1 Implementation In order to prioritize actions and better allocate human and capital resources, Marathon will focus first on weed prevention, second on early detection of invading weeds, and third on managing already established weed species. Priority will be given to those species identified by Garfield County as noxious, followed by state -listed noxious weeds. Additionally, Marathon may take action against undesirable, non-native species not considered noxious that prove to be detrimental to reclamation success and/or occur near facility production equipment. The primary treatment method that Marathon will employ will be chemical. Herbicides will be carefully selected and applied by state -certified and licensed applicators in accordance with label directions and specifications. Application of selected herbicides will be administered in such a way as to limit or preclude negative environmental impacts, including, but not limited to, not applying herbicides when wind speeds exceed ten (10) miles per hour, using physiologically selective or selectively applied herbicides, not applying soil sterilants or pre -emergent herbicides if heavy rainfall is expected within 24 -hours of application, and only using aquatic -labeled herbicides near surface water and wetlands. In all cases, herbicide label instructions will be strictly adhered to. Observational monitoring for weed species will be conducted monthly during the growing season by qualified individuals as part of Marathon's ongoing stormwater inspections, and a more -comprehensive weed survey will be conducted annually. Weed infestations will be identified, noted, and mapped, where appropriate. Identified infestations will be chemically -treated with appropriate herbicides twice annually --once in the spring, and once in the fall --with additional applications throughout the growing season if such is deemed necessary. Treatment success will be evaluated during subsequent monitoring activities. Conclusion This Weed Management Plan seeks to provide guidance for the effective and efficient control of noxious and undesirable, non-native weed species that may occur on Marathon -operated land in Garfield County, Colorado. Marathon will utilize an integrated approach to control weeds that includes preventative, cultural, mechanical, biological, and chemical methods, where appropriate, that are prioritized and targeted in their deployment. Routine monitoring for weeds will be conducted to identify infestations, as well as to evaluate the success of past treatments. Priorities for weed management can change and adaptive strategies will provide the best overall results. Marathon will reevaluate this plan annually to ensure that best practices are being utilized and make adjustments to their weed management program as necessary. Piceance - 2 Pipeline Information Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 OLSSON ASSOCIATES MARATHON 32C PRODUCED WATER POND PIPELINES PERMITS Marathon has secured permits for pipelines that serve the 32C facility. This includes the following permits: • Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. • Amended Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. • Second Amended Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. • Third Amended Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. • Fourth Amended Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. • Fifth Amended Administrative Permit for Marathon Oil Company, Marathon Fresh & Produced Water Pipeline System. Any other pipeline associated with this facility is not greater than 12 inches in diameter and over 2 miles in length or 2 cumulative miles if separated by municipal or public lands; or greater than 5 miles in length or 5 cumulative miles separated by municipal or public lands and is thus exempt from Article 9 of the Garfield County Land Use and Development Code. 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Marathon Oil Company 743 Horizon Ct., Ste. 220 Grand Junction, CO 81506 Telephone: 970.244.5735 Fax: 970.245.6287 November 19, 2013 Garfield County Commissioners 108 8th Street, Suite 401 Glenwood Springs, CO 81601 RE: Garfield County Limited Impact Review Application 596-32C Produced Water Pond Marathon Oil Company To Whom it May Concern: M HAJJ arathon Oil Marathon Oil Company (Marathon) will comply with all the provisions and terms of the following private agreements pertaining to Marathon's operation in Garfield County, Colorado. Pipeline Easement Agreement dated 10/23/06, between Marathon and Chevron Shale Oil Co. Surface Damage Agreement dated 4/23/07 between Marathon and Chevron Shale Oil Co. Surface Damage Agreement dated 7/2/07 between Marathon and Chevron Shale Oil Co. Surface Damage Agreement dated 9/24/07 between Marathon and Chevron Shale Oil Co. Surface & Road Use Agreement dated 4/30/08 between Marathon and Oxy USA WTP LP Easement & Right -of -Way Agreement dated 11/8/07 between Marathon and Puckett Land Co. Easement & Right -of -Way Agreement dated 2/1/08 between Marathon and Puckett Land Co. Copies of these documents are available upon request. Sincerely, MARATHON OIL COMPANY - 742 1144 Eric R. Ward Operations Manager MCAT-Piceance Operations vls/ERW CI fIEVRON USA INC I 11 1213529100008 ...c....../„..../7 -----r\---- 1 - 1 I 1 I 1 5 S 7 r / 5S96W I I: —�— _ __ !-- BF Y PETROLEUM D I f MARATHONIL 1 2135321000 9' I i I I 0 I -_____ BERRY PETRO EUMIAND ry MARATHO • I 216901100027 -� i -_-� 5S95 r. HEVRO USA INC .CIEVRON'USA INC 21691 200412 217118200008 OXY USA INC 216921400026! PUCKETT ND COMPANY 101300001 • Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 1 inch equals 1 mile 2 3 Miles ATTACHMENT 1 - PIPELINE ROW MAP FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE: 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN Abikanliaihr CORDILLERAN f I 5S97W CHEVRON USA INC 12135291(0008 5S96"r,. I r �B R2Y PETROLEUM MARATHON OIL. 213532104019 .47 CHE IRON USA INC ..213533400010 ' BERRY PETROIJEUM AND MARATHO 21690110 _L_ 1~ I • I L. i f `6 S 0-61/V:' - —&S HEVRON USA INC I 21691g200012 HEVRON USA INC. 217118200008 OXY USA I. C 92140 '. 6 Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 1 inch equals 0.75 mile 2 Miles ATTACHMENT 2 - PIPELINE ROW MAP DETAIL OF NORTHERN SEGMENT OF ROW FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE: 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN arr CORDILLERAN i HEVRON US* INC 21691 22000'I12 a i c 6 S 97 W .9F - / PUCKETTL41D COMPANY /101300001 Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 inch equals 0.5 mile 1 2 Miles ATTACHMENT 3 - PIPELINE ROW MAP DETAIL OF SOUTHERN SEGMENT OF ROW FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN arr CORDILLERAN OCT -4 -20th 12:06 FROM1: GRRCO, ACCT 9703845011 IfiP VINIAt iii# l AW %W 1 III Rao.ptionl . 756012 12/eeJ2209 04:03:01 PM Jean OlberiaO f of 3 Roc Poe:S4 3 bac Foo- .O0 GRRFIEL9 COUNTY CO TO : 42637456 P:9 ADMINISTRATIVE PERMIT fcrr Marathon Oil Company. Marathon Fresh & Produced Water Pipeline System In accordance with and pursuant to Section 9.07 ofthe Garfield County Zoning Resolution of 1978, as amended, and Resolution No, 2005 _. 53 oflu) Board of County Commissioners of Garfield County, State of Colorado, the Director of the Building and Planning Deponent herby authorizes, by Adminigtrative Permit, the following tivity: The construction of 13.72 miles of both 8 -inch diameter steel pi CEC1 -4-2011 1P:06 FROM: GF RCO, ACCT 9703545011 �Ifl PP./OM NISI INIt li iII Rscsptiomb : 76081Z 111081200$ 81 C5 01PM Joan Alberto*2 of 4 Rat: Foa 03.2 Doc Pact 0 00 GARFIELD GCL' TY CO Exhibit A T O :92637456 P:9 1. Any equipment used In construction or operation of a pipeline must comply with the Colorado Cil and Gas Conservation Commission Rales and Regulations, Section 802, Noise Abatement. Additionally, all power sources used In pipeline operations shall have electric motors or muffled internal combustion engines. 2. Pipeline operations shall be located in a manner to minimize their visual impact and disturbance of the land surface. Facilities shall be painted in a uniform, non -contrasting, non reflective color, to blend with the adjacent landscape. Right- f --way shall be located in existing disturbed areas unless safety or visual concerns or other adverse surface impacts dandy dictate otherwise. 3. Allaccess and oversize or overweight vehicle permits shell be obtained from the County Road & Bridge Department Marto beginning operation. Any new roads or Intensified driveway accesses created es a result of the pipeline construction, intended to be permanent for maintenance and repair operations shell be placed behind a locked gate °rather barriers preventing use by recreational vehicles. Any gates orbarners need to be consistent with the surface owner's preferences. 4. All vehicles working within Garfield County Right of Ways will be licensed and registered in the State of Colorado. All vehicles hauling equipment and materials for the pipeline construction will abide by Garfield County Road & Bridge Departments oversizeioverweight regulations. All vehicles requiring an oversize/overweight permit will send a letter showing proof that they can operate under a known bond holder on filo with Garfield County Road & Bridge Department before a permit will be issued. 5. The Applicant shall provide the County with a digital alignment of the pipeline once constructed In a format readable to the County Geographic Information System (GIS) analyst. 6. In no case shall en operator engage in activities which impact Federal or State threatened and endangered species. 7. Air contaminant emissions shall be In compliance with the applicable permit and control provisions of the Colorado Air Quality Control Program, Title 25, Resolution 7, C.R.S. QCT -4-2010 12:07 FROI'I:GARCO, DCCT 9733E145011 1111110c15:50411411 IiiMI1.111WIlii niidl i 1111! Receptionfll 759512 12111112439 44 06;G1 pts Jilin Rlbirioo 3 or 3 Reo Fda 30.00 OGG Fee,C3.O+3 GARFrEL4 COOTY L� T9: 92637156 P:10 All operations shall comply with all applicable Federal and State Public Health and Envirrnn ent, Noise, and Air and Water Quality Control standards, 9. Any proposed waste disposal or heatment facilities shall comply with all requirements of the County individual Sewage Disposal System Regulations. 10. Should an abandoned pipeline be removed, it will be subject to the original re -vegetation and weed management requirements in the original application. 11. There will bo no entrances to any County roads for the protect and the only impact to the County road system will be during the construction of the pipeline project. 12. Tho Applicant shall initiate weed management activities prior to fhe start of construction and shall treat all inventoried noxious weeds in the project area prior to construction activities and shall forward a copy of the appifcafron records to: Garfield County Vegetation Management, P© Box 426, Rifle CO 81850. 13. During construction, before leaving the site, all off read major construction equipment (graders, dozers, etc) working in areas of mapped noxious weeds should be power washed to remove seeds, soil, and vegetative matter. 14. The applicant shall provide the Vegetation Management Department with the original tags from each seed bag. 15. The security of $415,000 shall be held by Garfield County until vegetation has been successfully reestablished according to the Reclamation Standards in the Garfield County Wood Management Plan. Itis the responsibility of the applicant to contact the County, upon successful rte -vegetation establishment, to request an inspection for security release consideration. 16. Installation of the portions of the pipeline system and general construction activity in the areas where sensitive species octivitles are identified (Sage Grouse treks and active raptor nests) shall be performed outside of those limes and seasons that are soascns for breeding and nesting, in specific, the months of February fhrcugh June. Those identified areas include: Sections 19, 29, 32 and 33 of T5S, R98W and Section 13 of T6S, R97W 17. Any changes to the distribution or connection of this pipeline system or its contents shed moire a now Administrative Permit, DCT -1-2010 12:07 FROM:GARCOIACCT 9703EqS011 T0:92637456 P:11 i!1 Raospt4on4: 762013 0$)23(2aD9 10129:07 1f hinn PlharLon gr 4 RIO F0.00 Dc ForsO.41:1 GARFIELD COUNTY CO AMENDED ADMINISTRATIVE PERMIT for Marathon Oil Company. Marathon Fresh & Produced Water Pipeline System in accordance with and pursuant to Section 9.07 of the Garfield County Zoning Resolution of 1978, as amended, and Resolution No. 2005 - 53 of the Board of County Commissioners of Garfield County, State of Colorado, the Director of the Building and Planning Department hereby authorizes, by Administrative Permit, the following activity: The construction of 13.72 miles of both 8 -inch diameter steel pipe for fresh water and 4 -inch diameter Flexpipe for produced water in a system which distributes and collects, respectively, those fluids to andfrom related drilling operations in the area northwest of Parachute. The pipeline system is interred in a 100 right-of-way. The Amended Administrative Permit (Amending Reception 4759812) is issued subject to the conditions set forth in Exhibit A (attached hereto), and shall be valid only during compliance with such conditions and other applicable provisions of the Garfleld County Zoning Resolution, Subdivision Regulations, Building Code, and other regulations of the Board of County Commissioners of Garfield County, Colorado. BUILDING AND PLANNING DEPARTMENT, GARFTELD COUNTY, COLORADO Fred A. Jarman, Date Building & Planning Department, Director Oc;M\-'0."9t4 DCT -1-2010 12:08 FROM:CARCc.flCCT 9703845011 T©:92637456 P:12 11 loZik ",loll; i!fmigi4f'l li0,4iiii 1111 ReGrptionti: 762013 (�1178I3isOB lO:a4:131 a 1 .loan RIG,rsco 2 or 3 Rea Fa4:$6,C4 Dae Fea:Q.6p CRRFIELO COUNTY CO Exhibit A 1. Any equipment used In construction or operation of a pipeline must comply with the Colorado Oil and Gas Conservation Commission Rules and Regulations, Section 802, Noise Abatement. Additionally, all power sources used in pipeline operations shall have electric motors orrrwffled internal combustion engines. 2. Pipeline operations shell be located In a manner to minimize their visual impact and disturbance of the land surface. Facilities .shall be painted in El uniform, mora -contrasting, non -reflective color, to blend with the adjacent landscape. Right-of-way shell be located In existing disturbed arees unless safety or visual concoms or other adverse surface impacts clearly dictate otherwise. 3. All access and oversize oroverwelght vehicle permits shall be obtained from the County Road & Bridge Department prior to beginning operation. Any new roads or intensified driveway accesses created as a result of the pipeline construction, intended to be permanent for maintenance and repair operations shall be placed behind a locked gate or other barriers preventing use by recreational vehicles. Any gates orbeniers need to be consistent with the surface owner's preferences. 4. All vehicles working within Gerfield County Right of Ways will be licensed and registered In the State of Colorado. All vehicles hauling equipment and materials for the pipeline construction will abide by Garfield County Road & Bridge Departments oversize%overwe&ght regulations. Ail vehicles requlnng an oversize/overweight permit will send a letter showing proof that they can operate under a known bond holder on file with Garfield County Road & Bridge Department before a permit will he Issued. 5. The Applicant shall provide the County with a digital alignment of the pipeline once constructed In a format readable to the County Geographic Information Sysfarn (GIS) analyst. 6. In no case shall an operetor engage In activities which Impact Federal or State threatened and endangered species. 7. Air contaminant emissions shall be in compliance with the applicable permit and control provisions of the Colorado Air Quality Control Program, Title 25, Resolution 7, C.R.S. OCT -4-2010 12:0e FRON:CARCO] ACCT 9703845011 TC:92637456 P:13 Receptjankl: 782013 31of34ailQG Fea!106CO DaoJean Fee:6.Q() GARFIELD COUNTY CO 8. Ail operations shell comply with elf applicable Federal and State Public Heelth and Environment, Noise, end Air and Water Quality Control standards. 9. Any proposed waste disposal or treatment facilities shall comply with all requirements of the County Individual Sewage Disposal System Regulations. W. Should an abandoned pipeline be removed, it will be subject to the original re -vegetation and weed management regelrements !n the original application, 11. There will be no entrances to any County roads for the project and the only impact to the County road system will be during the construction of Ms pipeline project. 12. The Applicant shell Initiate weed management activities prior to the start of construction and shall treat all inventoried noxious weeds in the project area prior to construction activities end shall forward a copy of the application records to. Garfield County Vegetation Management, PO Box 426, Rife CO 81650. 13, During construction, before leaving the site, ell off road major construction equipment (graders, dozers, etc) working in areas of mapped noxious weeds should be power washed to remove seeds, soil, and vegetative matter 14. The applicant shall provide the Vegetation Management Department with the or'g!'nel tags from each seed beg. 15, The security of $415,000 shall be held by Garfield County until vegetation has been successfully reestablished according to the Reclamation Standards in the Garfield County Weed Management Plan. it is the responsibility of the applicant to contact the County, upon successful re -vegetation establishment, to request an inspection for security release consideration. 16. installation of the portions of the pipeline system end general construction activity in the areas whore sensitive species activities are identified (Sage Grouse leks end active raptor oasts) shall be performed outside of those times and seasons that are seasons for breeding and nesting, in specific, the months of February through ,June. Those identified ernes include: Sections 19, 29, 32 and 33 of T5S, R96 W and Section 13 of T6S, R97W. OCT -4-2010 12:09 FROM:GARCOJ-CCT 9170�3945011I III r���ill r,IR1h� liS�rl�Y�l�I`511IY�h`I'� I'hf ON 111! Rrcaptionq: 702018 0101/2009 0:29,07 All Joan alberl!oa 4 o1 4 Rio Fra:$0.2fl Doo Foo:O.00 GARFIELD COUNTY CO Tx:92637455 P:14 17. Any changes to (he distribution or connection of this pipeline system or its contents shall require a new Administrative Permit. 18. An amendment to the mute for the pipeline in Section 29, T5S, 1R96Wof the P.M. has been permitted by the Planning Director, depicted below. The restrictions for installation and construction in #16 (above) shall be adhered to for this amended mute. f1CT-1-2010 12:09 FRf7M:GRRCO, RCCT 9703E45011 III 11I1i Reteptionli: 763630 02/20120139 03:46,06 P11 len Alberloe r i of 6 R*o +f;SO.00 Oe5 Foe 4.00 GARFIELD CDURTV CO TO 92G37455 P: IS SECOND /WENDED ADMINIST . TIVD' PERMIT for Marathon Oil Company. Marathon Fresh & Produced Water Pipeline System In accordance with and punt to Article IX of the Garfield County Unified Land Use Resolution of 2008 and Resolution No. 2005 - 53 of the Board of County Commissioners of Garfield County, Stnte of Colorado, the Director of t e Building and Planning Department hereby authorizes, by Administrative Permit, the following activity: The construction of 13.72 miles of both 8 -inch diameter steel pipe for fresh water and 4 -inch diameter F'lexpipe for produced water in a system which distributes and collects, respectively, those Holds to andfromrelated drilling operations in the area northwest of Parachute. The pipeline system is interred in a 100' right-of-way. The Second Amended Administrative Permit (Amending Reception #759512 and #7620113) is issued subject to the cattdUions set forth in Exhibit A (attached hereto), and shall be valid only during compliance with such conditions and other applicable provisions of the Garfctd County Zoning Resolution, Subdivision Regulations, Building Code, and other regulations of the Board of County Commissioners of Garfield County, Colorado. BUILDING AND PLANNLNG DEPARTMENT, GARFIELD COUNTY, COLORADO F .�.i ] P Building & Pl�arining De, ent, Director 1 OCT -4-2010 12:10 FFOM:GARCO,ACCT 9703845011 NM Are p b7 201.00B 63 44:06 3Pn Sean A1birloo 2 of 6 Rap Fa•:i0.00 pec Faa.0 60 ©ARFIELD CoIJ1:7V Cd Exhibit A Ta :92637456 1. Any equipment used in construction or operation of a pipeline must comply with the Colorado Oil and Gas Conservation Commission Roles and Regulations, Section 802, Noise Abatement, Additionally, all power sources used in pipeline operations shall have electric motors or muffled Internet combustion engines. 2. Pipeline operations shell be located in a manner to minimize their visual impact and disturbance of the land surface. Facilities shell be painted in a uniform, non -contrasting, non -reflective color, to blend with the adjacent landscape. Right-of-way shall be located in existing disturbed areas unless safety or visual concerns orother adverse surface impacts clearly dictate otherwise. 3. A11 access and oversize or overweight vehicle permits shall be obtained from the County Road & Bridge Department prior to beginning operation. Any new roads or intensified driveway accesses created as a result of the pipeline construction, intended to be permanent for maintenance and repair operations shall be placed behind a locked gate or other barriers preventing use by recreational vehicles. Any gates or barriers need lobe consistent with the surface owner's preferences. 4. All vehicles working within Garfield County Right of Ways will be licensed and registered in the State of Colorado. All vehicles hauling equipment and materials for the pipeline construction will abide by Garfield County Road & Bridge Departments oversize/overweight regulations. All vehicles requiring an oversize/overweight permit will send a letter showing proof that they can operate under known bond holder on file with Gerlleld County Road & Bridge Department before a permit will be issued, 5. The Applicant shall provide the County with a digital alignment of the pipeline once constructed in a format readable to the County Geographic Information System (GIS) analyst. 6. In no case shall an operator engage in activities which impact Federal cr State threatened and endangered species. 7. Air contaminant emissions shall be in compliance with the applicable permit and control pmvislons of the Colorado Air Quality Control Program, 'T10 25, Resolution 7, C.R.S. P:16 QCT -4-20113 12:1[3 FROM:GARCO,RCCT 9703045011 1! k'i mama Il i rilivernalini#1/01,1 I ill Receptlena: 7113530 O7'201202 0324086 P Jsan R1Rarloo 3 of 9 P. Ps■:S0.00 Doc F./:0.27 GARFIELD COU!+TY CO QO: 9267?456 P: 17 8. Ali operations shall comply with all applicable Federal and Stele Public Health and Environment, Noise, and Air and Water Quality Control standards. 9. Any proposed waste disposal or treatment facilities shall comply with all requirements of the County Individual Sewage Disposal System Regulations. 10. Should an abandoned pipeline be removed, it will be subject to the original re -vegetation end weed management requirements in the original application. 11 There will be no entrances to any County roads for the project and the only impact to the County road system will be during the construction of the pipeline project. 12. The Applicant shut initiate weed management activities prior to the start of construction and shall treat all inventoried noxious weeds in the project area prior to construction activities and shall forward a copy of the application records to. Garfield County Vegetation Management, PD Box 426, Rifle CO 81650. 13. During construction, before leaving the site, ell off road major construction equipment (graders, dozers, etc) working in areas of mapped noxious weeds should be power washed to reprove seeds, soil, and vegetative mailer. 14. The applicant shall provide the Vegetation Management Department with the original tags from each seed bag. 15. The security of S415,000 shall be held by Garfield County until vegetation Inas been successfully reestablisl?od according to the Reclamation Standards in the Garfield County Weed Management Plan. It Is the rosponslLllity of the applicant to contact the County, upon successful re -vegetation establishment, to request an inspection for security release consideration. 16. installation of the portions of the pipeline system and general construction activity in the areas where sensitive species activities are identified (Saga Grouse leks and active raptor nests) shall be performed outside of those limes and seasons that am seasons for breeding and nesting, in specific, the months of February through June. Those identified areas Include: Sections 19, 29, 32 end 33 of T5S, R96 W and Section 13 of T6S. R97W. DCT -4-2010 12:10 FROM: CARCO RCCT 9703845011 IIl�i'�� 1i `,,Nkf�Iiiitiorteirawag 1111 Ravapt1on ' 763630 02/20l209 2;44:06 A11 Baan A16.rta° 4 of 6 Rap Fee.$0.00 Doc Fas40.00 GARFIELD COUNTY CO TO:92637456 P:18 17. Any changes to the distribution or connection of this pipeline system or its contents shall require a new Administrative Permit, 18. An amendment to the mute for the pipeline in Section 29, T5S, R96 W of the PK has been permitted by the Planning Director, depicted below. The restrictions for installation and construction in #96 (above) shall be adhered to for this amended mute. OCT -4-2010 12:11 FROM:GARCO.RCCT 9703845811 W41161141:AliNitig a eititi iiNpiri iiii ui iia gec.ptionO: 7631530 02/2012009 03:40i38 Pio Jou' Mario* 6 of 6 Rio Fas:SO.00 Oe Fa.:0.00 OARF[ELO COUNTY CO 70:92637456 P:19 19. An amendment to the pipe size from one (1) 8 -inch diameter steel and one (1) 4 -inch Flexpipe for the pipeline In portions of Section 19 and 29, T5S, R96W of the P.M. (depleted below in red) has been permitted by the Planning ❑irecfor The restrictions for installation and construction in #16 (above) shall be adhered to for this amended route. OCT -4-3011 12:04 FROM: GnRCl7, ACCT 9703845011 SIU VI WINO WillOrfilnitlZilint III Raavptiontl: 763940 02/2712.",09 03,30.47 P11 Juan fl16arIon of 6 Ran Fea,S0.00 coo Fea:0.63 CARFIELP COUNTY co TO: S2637456 P:3 THIRD AMENDED ADMINISTRATIVE PERMIT for Marathon 011 Company. Marathon Fresh & Produced Water Pipeline System In accordance with and pursuant to Article LX of the Garfield County Unified Land Use Resolution of 2008, and Resolution No. 2005 - 53 of t'he Board of County Commissioners of Garfield County, State of Colorado, the Director of the Building and P laming Department hereby authorizes, by Administrative Permit, the following activity: The construction of 13.72 miles of both 8 -inch diameter steel pipe for fresh water and 4 -inch diameter Flexpipe for produced water in a system which distributes and collects, respectively, those fluids to andfrom related drilling operations in the area northwest of Parachute. The pipeline system is interred in a 100' right-of-way. T% Third Amended Administrative Permit (Amending Reception #759812, #762013, and #763530) is issued abject to the conditions set forth in Exhibit A (attached hereto), and &halI be valid only during compliance with such conditions and other applicable provisions of the Garfield County Zoning Resolution, Subdivision Regulations, Building Code, and outer regulations of the Board of County Commissioners ofGarfield Comity, Colorado. BUILDING AND PLANNING DEPARTMENT, GARFIELD] COUNTY, COLORADO Erect A. Building & Plarming Department, Director OCTA -2010 12:04 FROM ! GPRCO , ACC1 6703e450 1 i TO : 92637156 P:4 VIII N �+ 4�'rYi', !l��M1110:10,1141fgNitlilqi4� l 11111 aoa.ptrana: Taasao 02/27P70p9 01,30 4 Ph J.sry plh ria44 3 Q7 fi Rea Fle.ffl..D Baa Fee:O.ca Et;RFIEtp COUNTY CO Exhibit A 1. Any equipment used in construction or operation of a pipeline must comply with the Colorado Oil and Gas Conservation Commission Rules and Regulations, Section 852, Noise Abatement. Additionally, all power sources used in pipeline operations shall have electric motors or muffled Internal combustion engines. 2. Pipeline operations shall be located in a manner to minimize their visual impact and disturbance of the land surface. Facilities shall be painted in a uniform, non -contrasting, non-ret7octive color, to blend with the adjacent landscape. Right-of-way shell be located ire existing disturbed areas unless safety or visual concerns or other adverse surface impacts clearly dictate otherwise. 3. All access end overthe or overweight vehicle permits shall be obtained from the County Road & Bridge Department prior to beginning operation. Any new roads or intensified driveway accesses created as a result of the pipeline construction, intended to be permanent formalntenance and repair operations shall be placed behind a locked gate or other barriers preventing use by recreational vehicles. Any gates orbaniers need to be consistent with the surface owner's preferences. 4. All vehicles working within Garfield County Right of Ways will be licensed and registered in the State of Colorado. Ail vehicles hauling equipment and materials for the pipeline construction will abide by Garfield County Road & Bridge Departments oversize/overweight reguletlons. All vehicles requiring an oversize/overweight permit will send a letter showing proof that they can operate under a known bond holder on filo with Garfield County Road & Bridge Department before a permit will be issued, 5. The Applicant shall provide the County with a digital alignment of the pipeline once constructed in a format readable to the County Geographic Information System (GIS) analyst. 6. In no case shall an operatorengege in activities which Impact Fedora! or State threatened and endangered species. 7. Air contaminant emissions shall be In compliance with the applicable permit and control provisions of the Colorado Air Quality Control Program, Title 25, Resolution 7, C.R.S. OCT -4-2010 12:04 FROM: GiIRCfl i ACCT 97035345011 TO: 92637456 P:5 «Il I A PViliNll ! I Wrilet#WICIN AIN 1111 I R4c4ptior417 753940 ©213712009 03,3047 Art Jean Rlb.riao 3 al 6 qac F48.50.06 Oco F.a=q.eo OPFT Lo COUiJTY CO 8. All operations shall comply with alt applicable Federal and State Public Health and Environment, Noise, and Air and Water Quality Control .standards. 9. Any proposed waste disposal or treatment facilities shall comply with all requirements of the County individual Sewage Disposal System Regulations, 10. Should an abandoned pipelines be removed, it will be subject to the original re -vegetation and weed management requirements in the original application. 11. There will be no entrances to any County roads for the project and the only impact to tho County road system will be during the construction of the pipeline project, 12. The Applicont shall initiate weed management activities prior to the start of construction and shall treat all inventoried noxious weeds in the project area prior to construction activities end shall forward a copy of the application records to: Garfield County Vegetation Management, PO Box 426, Rifle CO 91650. 13. During construction, before leaving the site, all off road major construction equipment (gnsdors, dozers, etc) working in areas of mapped noxious weeds should be power washed to remove seeds, soil, and vegetative matter. 14. The applicant shall provide the Vegetation Management Department with the original tags from each send bag, 15. The security of $415,000 shall be held by Garfield County until vegetation has been successfully reestablished according fo the Reclamation Standards In the Garfield County Weed Management Plan, It Is the responsibility of the applicant to contact the County, upon successful re -vegetation establishment, to request an inspection for security release consideration.. 16. Installation of the portions of the pipeline system and general construction activity in the areas where sensitive species activities are identified (Sage Grouse leks and active raptor nests) shall be performed outside of those times and seasons that are seasons for breeding and nesting, In specific, April 15t to July 15°`' within 1/3 mile of nests of Red Tailed Hawks; April 15``' to August 15th within J mile of nests of Cooper Hawks; and April 1'r to May 31'' within elle miles for Granter Sege Grouse. Those Identified areas include: Sections 19, 29, 32 and 33 of T5S, R96 W end Section 13 of T6S, R97W. Nesting period stipulations OCT -4-2010 12:05 FROM:CRRCO1ACC7 9703845011 70:92637456 P:6 IONIC Nhi W%Ift h;N ilo.p 1t In t Rrcepi.fonkl: 763940 02/27/2009 63:38:47 P?1 dean Alaarlop o 4 a1 6 Roo Fea:S0.66 Poe Ffn:D.C© GARF:ELD COMITY CO have been determined by a qualified wildlife biologist and approved by the Division of Wildlife (DDM. 9% Any changes to the distribution or connection of this pipeline system or its contents shall require a new Administrative Permit. 18. An amendment to the route for the pipeline In Section 29, T5S, R96Wof the P.M. has been permitted by the Planning Director, depicted below. The restrictions for installation and construction !n #16 (above) shall be adhered to for this amended route. OCT -4-2010 12.05 PROM:GARCO,ACCT 9703245011 TO:92637156 P¢7 11111 11eiair [iYili1,111111 lt.e� tiv�tt: �d3�ca a2/7i7F,T 63:;©:17 Pfi Joan Fifgriap 0 n1 3 Rao Feo;$0,OG! Doc Fa.6. ii FIELD COUNTY CO 19. An amendment to the pipe size from one (1) 8 -inch diameter steel and one (1) 4 -inch Flexpfpe pipes to two (2) ,t -inch Flexplpe pipes for the pipeline in portions of Section 19 end 29, T5S, R96W of the Pio. (depicted below in red) has been permitted by the Planning Director. The restrictions for Installation and construction in #16 (above) shall he adhered to for this amended route.. 20. An amendment has been permitted by the Planning Director to locate the two (2) 4 -Inch Ffexpipe for the pipeline into a ROW owned by EPCO, fnc. through an agreement between Marathon Oil Company and EPCO, Inc. and permitted for use by Marathon Oil Company in the portions of they pipeline (depicted in red). This permitting is based upon Marathon 011 Company's representation that EPCO, Inc.'s right-of-way is the same right-of-way Marathon Oil Company was granted by the surface owners. .....Utr't61411 4 DCT-9-2010 12:11 1=RO1:GARCO1RCCT 9703945111 NIII Phi PZIKAI lltC ik11,10V1iTifinq MIN f 1! II Reception#: 775283 19afe62O0i 1674:2W AMAra Fie;$4.0 boo�Feoip.E6rCARFLEL] COUNTY CO TD:922637455 P:20 FOURTH AMENDED ADMINISTRATIVE PERMIT for Marathon Oil Company. Marathon Fresh & Produced Water Pipeline System In accordance with and pursuant to Article IX of the Garfield County Unified Land Use Resolution of 2008, as amended, and Resolution No. 2005 - 53 of the Board of County Commissioners of Garfield County, State of Colorado, the Director of the Building and Planning Department hereby authorizes, by Administrative Permit, the following activity: The construction of 13.72 miles of both 8 -inch diameter steel pipe for fresh water and 4 -inch diameter Flexpipe for produced water in a system which distributes and collects, respectively, those fluids to and from related drilling operations in the area northwest of Parachute. The pipeline system is interred in a 100' right-of-way. The Fourth Amended Administrative Permit (Amending Reception (#763940,41759812, #762013, and ##763530) is issued subject to the conditions set forth in Exhibit A (attached hereto), and shall be valid only during compliance with such conditions and other applicable provisions of the Garfield County Zoning Resolution, Subdivision Regulations, Building Code, and other regulations of the Board of County Commissioners of Garfield County, Colorado. BUILDING AND PLANNING DEPARTMENT, GARFIELD COUNTY, COLORADO Fred A. Jarman, AICP Building & PIanning De • malt, Director QCT -4-2010 12:12 FROM:GARCO,ACCT 9703845011 70:92237455 P:21 EIJI Pii+ Vl"C 11461 VI 1eilti1i; 'I I 0'l 11111 Rrceptlona: 778283 Q0I12I2t 1D. 44.22 Rh Joan Aibor100 2 cF 8 Aso 3'06°53.03 Dao F40 0.00 GARFIELD COUNTY CO .Exhibit A 1. Any equipment used in construction or operation of a pipeline must comply with the Colorado Oil and Gas Conservation Commission Rules end Regulations, Section 802, Noise Abatement. Additionally, all power sources used in pipeline operations shall have electric motors or muffled internal combustion engines. 2. Pipeline operations shall be located in a manner to minimize their visual impact and disturbance of the land surface. Facilities shall be painted in n uniform, non -contrasting, non -reflective color, to blend with the adjacent landscape. Right-of-way shall be located in existing disturbed areas unless safety or visual concerns or other adverse surface impacts clearly dictate otherwise. 3. Ail access and oversize or overweight vehicle permits shall be obtained from the County Road & Bridge Department prior to beginning operation. Any new roads or intensified driveway accesses created as a result of the pipeline construction, intended to be permanent for maintenance and repair operations shall. be placed behind a locked gate or other barriers preventing use by recreational vehicles. Any gates or barriers need to be consistent with the surface owner's preferences. 4. All vehicles working within Garfield County Right of Ways will be licensed and registered in the State of Colorado. All vehicles hauling equipment and materiels for the pipeline construction will abide by Garfield County Road & Bridge Departments oversize/overweight regulations. All vehicles requiring en oversize/overweight permit will send a letter showing proof that they can operate undera known bond holder on file with Garfield County Road & Bridge Deportment before a permit will he issued. 5. The Applicant shall provide the County with a digital alignment of the pipeline once constructed in a format readable to the County Geographic information System pis) analyst 6. In no case shall an operator engage in activities which impact Federal or State threatened and endangered species. 7. Alr contaminant emissions shall be in compliance with the applicable permit and control provisions of the Colorado Air Quality Control Program, Title 25, Resolution 7, C.R.S. OCT -4-2010 12:12 FROM, GRRCU, ACCT 970 3845011 T0: 926; 7156 P:22 lei fdFiff� �ifi'rYY�f!111 1�1�C f ,1111 RocIptlon1: 770263 851f6V202,9 of 6ir Roo F 0:44:29 AM a olOW Doo C oO 3oan RRFII LD county co 8. All operations shall comply with all applicable Federal and State Public Health and Environment, Noise, and Air and Water Quality Control standards, 9. Any proposed waste disposal or Treatment facilities shall cornpfy with all requirements of the County Individual Sewage Disposal System Regulations. 10. Should an abandoned pipeline be removed, it will be subject to the original re -vegetation and weed management requirements in the original application. 11. Them will be no entrances to any County roads for the project and the only Impact to the County road system will be during the construction of the pipeline project. 12. The Applicant shall initiate weed management activities prior to the start of construction end shall treat ell inventoried noxious weds in the project area prior to construction activities and shell forward a copy of the application records to: Garfield County Vegetation Management, PO Box 426, Rifle CO 81650, 13. During construction, before leaving the site, all off road major construction equipment (graders, dozers, etc) working in ames of mapped noxious weeds should be power washed to remove seeds, soil, end vegetetive'natter, 14. The applicant shall provide the Vegetation Management Department with the original tags from each seed bag. 15. The security of $415,000 shall be held by Garfield County until vegetation has been successfully reestablished according to the Reclamation Standards in the Garfield County Weed Management Plan. It is the responsibility of the applicant to contact the County, upon successful re -vegetation establishment, to request an inspection for security release consideration. 16. Installation of the portions of the pipeline system and general construction activity in the areas where sensitive species activities are identified (Sage Grouse lake and active raptor nests) shall be performed outside of those times and seasons that are seasons for breading and nesting, in specific, April 15r'' to July 15h within 1/3 mile of nests of Red Tailed Hawks; April le to August 15th within N mile of nests of Cooper Hawks; and April 13r to May 311r within 6110 miles for Greater Sage Grouse. Those identified arras include: Sections 19, 29, 32 and 33 of T5S, R98W end Section 13 of T6S, ROW. Nesting period stipulations OCT -4-2010 12::1.3 FROM:GARCO.ACCT 9703845011 TO:9263?456 P:23 VIII AAP11 'I+ fi� �Ge11.I 01111INI `I Cl�� kocept iantl : 775283 0911Bl2069 18:44.29 Al Joan Allgerlao 4 of S Rev Pea :40.00 coo Foo:O. 8 GRRFjELO COURTY CO have been determined by a qualified wildlife biologist end approved by the Division of Wildlife (DOW). 17. Any changes to the distribution or connection of this pipeline system or its contents shall require a new Administrative Permit. 18. An amendment to the route for the pipeline in Section 29, T5S, R96Wof the P.M. has been permitted by the Planning Director, depicted below. The restrictions for installation and construction in #16 (above) shall be adhered to for this amended mute. OCT -4-2010 12:13 FROM:GRRCO,ACCT 9703845011 TO:92837456 P:24 111Wit irI N# l ICINTA4I '/ ni 1111 R.r.p°nil: 77.52E13 GS/ 12000 !0:44:29 AM Jinn Alhpprioo 3 0f 6 Rao Foc:S0,00 000 Fas:0,00 6R:RFIaO cou ry co 19. An amendment to the pipe sire from one (1) 8 -inch diameter steel and one (1) 4 -inch Flexpipe pipes to two (2) 4 -inch F!expipe pipes for the pipeline in portions of Section 19 end 29, T5S, R96W of the P.M. (depicted below In red) has been permitted by the Planning Director. The restrictions for Installation and construction in #16 (above) shall be adhered to for this amended route. 20_An amendment has been permitted by the Planning Director to locate the two (2) 4 -Inch FlexpIpe for the pipeline into a ROW owned byEPC©, Inc. through an agreement between Marathon Oil Company end EPCQ, Inc. and permitted for use by Marathon Oil Company in the portions of the pipeline (depicted in red). This permitting is based upon Marathon Oil Company's representation that EPC©, Inc.'s right-of-way is the same right-of-way Marathon Oil Company was granted by the surface owners. 1111 FeINPIIITIMIALNl�h.II I�� IIS 11 III Reception#: 775283 09!1612009 10;44:29"AM Jean AlberIoo•. 6 of 6 Reo Fee:MOD Doc Fae:0.60 GARFIELD COUNTY CO 21. An amendment has been permitted by the Planning Director allowing Marathon Oil Company to locate one (1) 8 -inch steel and one(1) 4 -inch Flexpipe for the pipeline into an easement granted by Chevron (USA) Inc., co -locating with a pipeline easement from Chevron (USA), Inc. to EPCO, Inc. as depicted below. 1, .,n+...,r lnaa 1 .•Jry =ere 'M ea,yal J+v.«PCA • yr.• eY'.M�1+Ltsr ,gl war.f I . emacs G f.rrI9 w� y,rcV :;gar ;>ws+F.'���+;= ,OLSSON 2 S ocr+ffl Octiber 57,-2009 Garfield County BUILDING & PLANNING DEPARTMENT Mr. Curtis Ryland, Operations Superintendent Marathon Oil Company 743 Horizon Ct., Suite 220 Grand Junction, CO 81503 RE: Fifth Amendment (PDPA-9-09-6118) to Pipeline Development Plan (PDP12908} Marathon Oil Company Fresh and Produced Water System Pipeline Dear Mr. Ryland, Upon review, we have found that the September 21, 2009, application for a Pipeline Development Plan Amendment is technically complete and does not represent a substantial change from the original permit. Attached to this letter is the approved Fifth Amended Administrative Permit with exhibit. The exhibit portion of the Amendment references and replaces the previous Amended Administrative Permits. Project Summary. The original permit was for the installation of 13.72 miles of 8° diameter steel pipe and 4" diameter Flexpipe for the transport of produced water and fresh water. The pipeline location is northwest of Parachute in Sections 5S 96W, 6S 96W, and 6S 97W. This amendment allows two 4" diameter Flexpipe water lines to be placed in 16,000 feet of trench instead of the 8" steel pipe and 4" Flexpipe originally permitted. The location of this change to two 4" Flexplpes is where Enterprise is Installing the Cascade Pipeline Lateral under Grading Permit 9-09-1247. Upon receiving this letter and signed permit, Marathon can commencew1th installing the two 4" Flexpipe fines. Within a week, a recorded version of the attached permit will be sent to Marathon and Olsson Associates. Please feel free to contact this office if you have any questions. Sincerely, ohn Nie oehner, Project Enginee 970,945-8 Cc: Fred Jarman, Director Doug Dennison, Casson Associates 108 Eighth Street, Suite 401 • tGlenwaod Springs, CO 81601 (970) 945-8212. (970) 285-7972 • Fax. (970) 384-3470 OCT --1-2010 12:15 FRDM: CARCO, ACCT 9703845011 ticArtriltilleVirldilreirKONFILlilai � 11111 O106/Z009 02:66,63 AM Jean Alberica Qi 5 R. Fee.$0.0D Ooe Fee,0,00 GAF/FIB-0 COUNTY CO TO:92637456 P:25 FIFTH AEND D A.DMINISTRA TI NE PERMIT for Marathon Oil Company. Marathon Fresh & Produced Water Pipeline System In accordance with and pursuant to Article IX of the Garfield County Unified Land Use Resolution of 2008, as amended, and Resolution No. 2005.53 of the Board of County Commissioners of Garfield County, State of Colorado, the Director of the Building and Planning Department hereby authorizes, by Administrative Permit, the following activity: Original Permit: The construction of 13.72 miles of both 8 -inch diameter steel pipe for fresh water and 4 -inch diameter Flexpipe for produced water in a system which distributes and collects, respectively, those fluids to and from related drilling operations in the area northwest of Parachute. Fifth Amendment: Allows 4" Flexpipe to be used instead of 8" steel pipe in 16,000 feet of trench length. This Fifth Amended Administrative Permit (Amending Reception (#775283, 4763940, #759812, 0762013, and #763530) is issued subject to the conditions set forth in Exhibit A (attached hereto), and shall be valid only during compliance with such conditions and other applicable provisions of the Garfield County Zoning Resolution, Subdivision Regulations, Building Code, and other regulations of the Board of County Commissioners of Garf eld County, Colorado. BUILDING AND PLANNING DEPARTMENT, GARFIELD COUNTY, COLORADO Fred A. Jarrna.n '1 V Building & Planning Department, Director OCT -4-2c310 12:15 FROM:6RRCO.rtCCT 970345011 1111 AA �iL �� f�� 1'Cii+ l a��iir �� 1��1 ,�,W' 11 Iii R4c.ptiantf: 775991 10/0GI2009 09:$5053 Flit Joan Alb rtao 2 o 8 Rao raa:$0.00 0oo Fua:0.O0 GRRFIELD C0J1 TY CO Exhibit A TO:92637456 P:27 1. Any equipment used in construction or operation of o pipeline must comply with the Colorado Oil and Gas Conservation Commission Rules and Regulations, Section 802, Noise Abatement. Additionally, aft power sources used in pipeline operations shall have electric motors orrnuffled internal combustion engines. 2. Pipeline operations shall be located in a manner to minimize (heir visual impact and disturbance of the land surface. Facilities shall be painted in s uniform, non -contrasting, non reflective color, to blend with the adjacent landscape. Right-of-way shell be located in existing disturbed areas unless safety or visual concerns or other adverse surface impacts clearly dictate otherwise. 3. All access and oversize or overweight vehicle permits shall be obtained from the County Road & Bridge Department prior to beginning operation. Any new roads or intensified driveway accesses created as a result of the pipeline construction, intended to be permanent for maintenance end repair operations shall be pieced behind a locked gate or other beaters preventing uses by recreational vehicles. Any gates or barriers need to be consistent with the surface owner's preferences. 4. All vehicles working within Garfield County Right of Ways will be licensed and registered in the State of Colorado. All vehicles hauling equipment and matarlals for the pipeline construction will abide by Garfield County Road & Bridge Departments oversize/overweight regulations. All vehicles requiring an oversize/overweight permit will send a totter showing proof that they can operate under a known bond holder on file with Garfield County Road & Bridge Department before a perrrmit will be Issued. The Applicant shall provide the County with a digital alignment of the pipeline onco constructed in a format readable to the County Geographic Information System (GIS) analyst. 6. In no case shall an operator engage in activities which impact Federal or State threatened and endangered species. 7. Air contaminant emissions shall be in compliance with the applicable permit end control provisions of the Colorado Air Quality Control Program, Title 25, Resolution 7, C, R. S. OCT -4-2010 12:16 FROM:GARCO,ACCT 9703845011 ton atII I`.wilwil Iii 1111 Rfc9pt4att t 775987 10/05/2009 09:85.83 A.loan Riberioo 3 of 8 Roo Fief°, [ H on Doo Fse:0.60 GARFIELO COUNTY CO TO:92637456 P:28 8. All operations shall comply with all applicable Federal and State Public Health and Environment, Noise, and Air and Water Quality Control standards. 9. Any proposed waste disposal or treatment facilities shall comply with all requirements of the County Individual Sewage Disposal System Regulations. 10. Should an abandoned pipeline be removed, it will be subject to the original re -vegetation and weed management requirements in the original application. 11. There will be no entrances to any County roads for the project and the only impact to the County road system will be during the construction of the pipeline project. 12. The Applicant shall Initiate weed management activities priorto the start of construction and shall treat all inventoried noxious weeds in the project area prior to construction activities and shell forward a copy of the application records to: Garfield County Vegetation Management, PO Box 426, Rifle CO 81654. 13. During construction, before leaving the site, all off road major construction equipment (graders, dozers, etc) working in areas of mapped noxious weeds should be power washed to remove seeds, soil, and vegetative matter 14. The applicant shall provide the Vegetation Management Department with the original fags from each seed beg. 15. The security of $415,000 shall be held by Garfield County until vegetation has been successfully reestablished according to the Reclamation Standards In the Garfield County Weed Management Plan. It is the responsibility of the applicant to contact the County, upon successful re -vegetation establishment, to request an inspection for security release consideration. 16. installation of the portions of the pipeline system and general construction activity in the areas where sensitive species activities are Identified (Sege Grouse leks and active raptor nests) shall be performed outside of those times and seasons that are seasons for breeding and nesting, in specific, April I e to July 15th within 113 mile of nests of Red Tailed Hawks; April 15t' to August 15th within 54 mile of nests of Cooper Hawks; and April 151 to May 31'1 within 6110 miles for Greater Sege Grouse. Those identified areas include: Sections 19, 29, 32 and 33 of T5S, R96W and Section 13 of T6S, R97W. Wasting period stipulations OCT -4-2010 12:16 FROM:GARCOOICCT 5703845011 TO:92637456 P:29 Recapt1onb: 775997 loi06/r2QO9 09:55:63 N7 Jean Mir -too 1 o1 5 Rea faa:50.00 Doti Feei0.60 6RRFIELO COUNTY CO have been determined by a qualified wildlife biologist and approved by the Division of Wildlife (DDWW. 17. Any changes to the distribution orconnectlon of this pipeline system or its contents shall inquire a new Administrative Permit 18. An amendment to the route for the pipeline in Section 29, T5S, R95Wof the P.M. has been permitted by the Planning Director, depicted below. The restrictions for installation and construction in #16 (above) shall be adhered to for this amended mute. OCT -4-2010 12:17 FROM:6ARCO.PCCT 9703845011 R.ciptianti: 775587 S0/08126A°i OR 69.£3 AM Juin Alberto° 5 of 8 Roo Fra 10 00 Cao r...0 00 GARFIELD GOU`ITY CO TO :92637456 P:30 19. An amendment to the pipe size from one (1) 6 -inch diameter steel and one (1) 4 -Inch Flexpips pipes to two (2) 4 -inch Flexpipe pipes for the pipeline in portions of Section 19 and 29, T5S, R96W of the P.M. (depicted below in red) has been permitted by the Planning Director. The restrictions for installation and construction in #16 (above) shall be adhered to for this amended route. 20. An amendment has been permitted by the Planning Director to locate the two (2) 4 -inch Flexpfpe for the pipeline into a ROW owned by EPCO, Inc, through an agreement between Marathon Oil Company and EPCO, Inc. and permitted for use by Marathon Oil Company in the portions of the pipeline (depicted In red), This pormitting is based upon Marathon Oil Company's representation that EPCO, Inc, 's right-of-way Is the same right-of-way Marathon Oil Company was granted by the surface owners. OCF-4-2013 12:17 FROM:GARCO.ACCT 9703945011 TO:92637456 Irl F't' 141111411114N 11114 LI1 JP 1 Rscspt1oMl' 775987 10/06,2009 00:66063 A -imam Alhtr;;e,9 6 of 6 Rip Fee $0 00 00c Fps 0 00 ( RFIEL0 COUNTY CO 21. An amendment has been permitted by the Planning Director allowing Marathon Oil Company to locate one (1) 8 -inch steel and one (1) 4 -inch Flexplpe for the pipeline into an easement granted by Chevron (USA) Inc., co -locating with a pipeline easement from Chevron (USA), Inc. to EPCO, Inc. 22. An amendment to allow two 4" diameter Flexplpe water lines to be placed in 16,000 feet of french instead of the 8" steel pips and 4" Flexplpe onglnally permitted. The location of this change to two 4" Flexplpes Is where Enterprise is installing the Cascade Pipeline Lateral under Grading Permit 9-09-1247. Project Address Garfield County Building & Planning Department 10880 Street Suite 401 Glenwood Springs, CO 61601 - Phone: is70}91S- 212 Fax (070)384 70 Parcel No, Permit NO, GRAD -9-09-1281 I Permit Type: Grading Permit Work Classtrication: Major Permit Status: Active Issue Date: 9i2412009 Expires: 03123/2010 Subdivision Section Township Range DEBEQUE, CO 216912200012 Owier 1nformallon Address Phone Cell Chevron USA Inc 760 Horizon DR Grand Junction CO 81506 907-245.6255 Contractors Phone Primary Contractor Barnard Pipeline Inc (206)778438e Yes Proposed Construction Installs grading to be able to iniali 13000 ft of 2 4" fiexpipe lines for water transportation. FEES DUE Fee Malo( Grading Fee Total: Amount $400.00 $400.00 FEES PAID VaiNation: Total Sq Feet: 0.00 390000 Inv Total Paytype Amt Paid Amt Due Inv fl GRAD -$-09.1977D 5400.00 Check it 1034 S400 Oft so.Do Required Inspections: For Irsipecdona cad; 1(970)384-5003 Inspection Slle VIa11 Final IVR 000 126 IMPORTANT: APPLicAITOH Is HEREBY MADE To THE 6UILDING OFFICIAL FOR A PERM T SUBJECT TO THE CONDITIONS AND RESTRICTIONS SET FORTH ON THIS APPLICATION AND THE FOLLOWING: 1. Ftnal Inspection of the work authorized by this permit is required. A Certificate of Occupancy must bo obtained prior to use and oonapanry of new buildings, structures and remodeling work Applicant Copy This permit/Oen review expires by time limitation and becomes null and void if the work authorteed by the peanil is not commenced within 180 days from the data of porm:l Issuance or if aha permit is not obtainyd yilhin ISO days from the dela of plan submittal. This p.rmit expires and becomes null and void If any work authorized by iitts permit is suspended or abandoned for 1e0 e arse althea days or 14 no progressive work has Won verlred by passing a re qulrod County inspection for a ,period of 100 consec Lilly& days. Thursday, September 24, 2009 Noise Assessment Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 O\OLSSON ASSOCIATES April 1, 2014 Vicki Schoeber Marathon Oil Company 743 Horizon Court, Suite 220 Grand Junction, CO 81506 Subject: Noise Analysis —32C Produced Water Pond Facility Garfield County, Colorado Dear Ms. Schoeber, At the request of Marathon Oil Company (Marathon) Olsson Associates (Olsson) has conducted an assessment of noise generating equipment installed at the 32C Produced Water Pond Facility. The intent of this assessment was to review the equipment specifications provided by the manufacturer (Attachment A), and determine if the equipment's operation would be in compliance with the noise limits set forth in the Colorado Oil and Gas Conservation Commission (COGCC) Rule 802. Noise Generating Equipment Noise from multiple sources does not increase overall sound pressure levels. There is a slight increase if multiple sources exist that emit the same noise level, but that is not the case for this facility. For this assessment we have determined the loudest piece of noise generating equipment is the motor for the hydra cell pump. Compliance Point The COGCC Rule 802 uses the property line or 350 feet from the noise generating equipment, whichever is greater, as the compliance point for oil and gas operations. These points are used to allow for noise generating equipment while protecting neighboring properties from impacts related to noise. The facility is in a remote location away from residential areas and is used mainly for oil and gas industrial purposes. We would like to demonstrate that the noise levels at 350 feet from the noise generating equipment are within compliance of the levels required under COGCC Rule 802. The property line is several hundred feet more distance than 350 feet used in this study. The noise pressure levels calculated at the property line would be much lower but we have chosen 350 feet to be conservative. Maximum Permissible Noise Levels As prescribed in COGCC Rule 802, in remote locations, where there is no reasonably proximate occupied structure or designated outside activity area, the light industrial standard may be applicable. The night time maximum permissible noise limit is 65 db(A) for light industrial areas. The equipment will be operated during daytime hours only. 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com 012-1372 Noise Analysis —32C Produced Water Pond Facility 04/01/14 Calculated Sound Pressure Levels The motor is rated to a sound pressure level of 92 dB(A) at 1 meters (3.3 feet) by the manufacturer (see Attachment A). Extrapolation to 350 ft. dBA1 = 92 dB (A) (Noise Rating of Motor) D2 = 350 ft. (COGCC Compliance Distance) D1 = 3.3 ft. (Distance of Noise Rating from Manufacturer) dBA2 = 51.5 dB (A) (Calculated dB (A) at 350 ft.) COGCC Rule 802(c) 1 - dB(A)Distance 2 = dB(A)Distance 1 - 20 x logio(Distance2/Distance,) Olsson has assessed the potential noise level at 350 feet using the noise/distance extrapolation equation provided in COGCC Rule 802 and the motor's noise rating. The calculated sound pressure level at 350 feet from the equipment will be approximately 51.5 dB(A) Conclusion The noise pressure calculation shows that the levels should be well below the night time light industrial limit at 350 feet from the equipment. This sound pressure level is calculated and actual noise levels may be measured during equipment operation to insure regulatory compliance. Statement of Qualification I am a multi -disciplinary Project Manager at Olsson Associates. I have coordinated many Noise Control Regulation Compliance Assessments over 5 years at existing and planned noise generating equipment installations in Colorado. If you have any questions regarding this assessment, please contact me at 970-263-7800. Sincerely, Olsson Associates Ken Kreie Senior Scientist Enclosures — Attachment A — Manufacturer Noise Rating Specifications Cc: Project File ATTACHMENT A KU BOTA APP 'LUCA TION MANUAL (2) Fuel Consumption Specific at Net Intermittent (SAE J1349) Model Fuel Engine Speed r/min 2000 2400 2800 3200 3600 W:3972 Gasoline Brake Horse Power kW 14 8 17 8 20 6 22.2 23.1 HP 19 8 23 9 27 6 29.8 31 0 PS 20 1 24.2 28 0 30 2 31 4 Fuel. Consumption g/kW•hr 404 398 371 351 334 g/HP•hr 301 297 276 262 249 g/PS•hr 297 292 272 258 245 IbJHP•hr 0 664 0 654 0 609 0577 0 549 DF972 Gasoline Brake Horse Power kW 148 178 20.6 22.2 23.1 HP 19 5 23 9 27 6 29 8 31 0 PS 20 1 24 2 28 0 30.2 31.4 Fuel Consumption gfkV .hr 404 398 371 351 334 g/HP•hr 301 297 276 262 249 giPS•hr 297 292 272 258 245 IbT1-1P•hr 0 664 0 654 0 609 0.577 0 549 LPG Brake Horse Power kW 14 7 17 8 20 1 21-'2 22 0 HP 19 8 23 8 26 9 28 5 29 5 PS 20 1 24 1 27 3 28 9 29.9 Fuel Consumption gikWhr 301 287 286 292 299 g/HP•hr 224 214 213 218 223 g/PS.hr 221 211 210 215 216 IbIHP•hr 0.494 0 471 0.470 0 480 0 491 Note: Conversion rates tx 1 kW 1.35962 PS = 1.34048 HP ;x 1 PS = 0.7355 kW = 0.985925 HP * 1 HP=0.7457 kW=#.01428 PS * 1 kg = 2.20462 lb (1 g = 0.00220462 lb) ✓ 1 Ib = 0.45359 kg (3) Noise Level These data show the average noise level at four points Note [Measurement conditions] c With radiator, cooling fan, air cleaner and muffler. [2-10j Load x Amin Fuel Unit Sound Pressure at 1 m (3.3 ft) WG972 DF972 014 x 3850 Gasoline dB (A) 90 0 LPG dB (A) 90 0 4/4 x 3600 18 6 kW (25 0 HP) Gasoline dB (A) 92 0 LPG dB (A) 92 0 Dui x 1500 Gasoline dB (A) 72 0 L PG LPG -,- dB (A) `' ti These data show the average noise level at four points Note [Measurement conditions] c With radiator, cooling fan, air cleaner and muffler. [2-10j Figures Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 Legend 0 32C Water Impoundment - Route to Facility Highway - Local Roads 0 0.5 1 2 Miles N PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 2/5/13 ACTIVITY MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO ab‘OLSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 FIGURE ACT - 1 213527300015 213532100009 BERRY COMPANY 32C Water Impoundment 213533400010 216902200019 PRATHER RICHARD 216904400003 Parcels represented with labels are witihin 200' of affected parcel Legend 0 32C Water Impoundment =Parcel 213532100009 (880 Acres) 0 Parcels Route to Facility 0 0.225 0.45 Miles 0.9 PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 6/17/2013 ADJACENT PARCEL MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO O\OLSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 FIGURE AP - 1 Floodplain Data provided Garfield County GIS Database Legend 0 32C Water Impoundment FloodPlain Highway - Local Roads 0 0.5 1 2 Miles PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 7/18/12 FLOODPLAIN MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO O\OLSSON ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION. CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE F-1 Geology Data provided by the USGS Geological Survey 32C Water Impoundment - -. Legend O 32C Water Impoundment Geology Type Tu - Unita formation ICIFeet W 0 125 250 500 s PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 7/18/12 GEOLOGY MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO Os\OLSSON ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION. CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE G-1 CI fIEVRON USA INC I 11 1213529100008 ...c....../„..../7 -----r\---- 1 - 1 I 1 I 1 5 S 7 r / 5S96W I I: —�— _ __ !-- BF Y PETROLEUM D I f MARATHONIL 1 2135321000 9' I i I I 0 I -_____ BERRY PETRO EUMIAND ry MARATHO • I 216901100027 -� i -_-� 5S95 r. HEVRO USA INC .CIEVRON'USA INC 21691 200412 217118200008 OXY USA INC 216921400026! PUCKETT ND COMPANY 101300001 • Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 1 inch equals 1 mile 2 3 Miles ATTACHMENT 1 - PIPELINE ROW MAP FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE: 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN Abikanliaihr CORDILLERAN f I 5S97W CHEVRON USA INC 12135291(0008 5S96"r,. I r �B R2Y PETROLEUM MARATHON OIL. 213532104019 .47 CHE IRON USA INC ..213533400010 ' BERRY PETROIJEUM AND MARATHO 21690110 _L_ 1~ I • I L. i f `6 S 0-61/V:' - —&S HEVRON USA INC I 21691g200012 HEVRON USA INC. 217118200008 OXY USA I. C 92140 '. 6 Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 1 inch equals 0.75 mile 2 Miles ATTACHMENT 2 - PIPELINE ROW MAP DETAIL OF NORTHERN SEGMENT OF ROW FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE: 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN arr CORDILLERAN i HEVRON US* INC 21691 22000'I12 a i c 6 S 97 W .9F - / PUCKETTL41D COMPANY /101300001 Manifold & Pump Location Proposed Water Lines Affected Parcels Exsiting Private Roads County Roads Marathon Lease 0 0.5 1 inch equals 0.5 mile 1 2 Miles ATTACHMENT 3 - PIPELINE ROW MAP DETAIL OF SOUTHERN SEGMENT OF ROW FRESH & PRODUCED WATER LINES MARATHON OIL CO GARFIELD COUNTY, COLORADO REVISION DATE 09/23/08 REVISION NUMBER 01 DRAWN BY: LS APPROVED BY: DD PROJECT # EG07149 SCALE' AS SHOWN arr CORDILLERAN ABRI 1 A3' 6000 4000 2000 1000 500 0 5001000 2000 4000 6000 EXISTING 19C LATERAL ys �y1 1 EXISTING PAD 596-19C ROPQ.6:.. AD 696-1StA EXISTING Q. 20CLATERAL\ EXISTING PAD 596-200 EXISTING NOITgHTEEELLIIPE NE i 1-4"POLYLII4t 7 gsRic, 30'ROPOSED PAO5-?rC,Z, EXISTING 91A LATERAL P e ROPOSED PAD 596-20A PROP SED ,PAD 6-29A STING `-4 NORTHERN PIPELINE 2 - 4" POLY LINE EXISTING PAD 586-29C EXISTING 310 LATERAL EXISTING PAD 596-31A yS1,� 31t EXISTING 32C LATERAL `EXISTING aPONDA r EXISTING . EXISTING PONDC PAD 696-32C EXISTING PAD 596-310 l EXISTING LATHAM LAYDOWN EXISTING`' PAD 59633C - I EXISTING NORTHERN PIPELINE -4- POLYLINES .51 5 EXISTING e LAYDOWN LINE 2 -8" STEEL UNE 1 -4" POLY LINE PROPOSED Pf1D 697-2A Sw 2' L P ROPOSED PAD 598-334 EXISTING NORTHERN PIPELINE 2 - 8" STEEL LINE 1-4" POLY LINE 1 34' 1 EXISTING PAD 595-340 PROPQSED /' PAD 697-1A — EXISTING 341)L4TERA EXISTING I 35D LATERAL __ ! PROPOSED - PAD 69 EXISTING PAD 697-1C O (STING 1C LATERAL EXISTING PAD 697-20 EXISTING 2C LATERAL CDP EXISTING PAD 697-214 PROPOSED PAD 697-22A LJ r t s EXISTING PAD 697-11 11 EXISTING_ 11X ERAL ROPOSED PAD 697-11 ij PROPOSED PAD 697-11C EXISTING CENTRAL PIPELINE 1 LINE -4" POLY UN ' PROPOSED 1 AD 697-14C- EXISTING CENTRAL PIPELINE ti 1 4" POLY LINES EXISTING PAD 697-23X EXISTING SAD PROPOSED PAD 697-227 ?ROPO6ED PAD 69 -21C-0-' rt `` CASCADE LATERAL 2-4"POLYUNES PROPOSED $6611 :9A PAD 697-28A 21 2 1 EXISTING PAD 697-28C STING 23X LATERAL CASCADELATERALJ 2 -4" POLY LINES EXISTIN '. . CENTRAL PIPELINE 1 - S" STEEL LINE 1 -4" POLY UNES 6Sf X23 — PROPOSED PAD 697-23Dm +I + 7 2-4"POLYUNEES�J Lr �IQ PROPOSED PAD 697-23C PROPOSED PAD i 97-2613 PROPOSED_ PAD 697-26C PROPOSED PAD 897-28AA L fQ EXISTING PAD 697-1X (STING 1X LATERAL ROPOSED 0a-" PAD 696.60 GARDEN GULCH LATERAL 2 - 4" POLY LINES ( 12A LATETE RAL EXISTING iEXIS EXISTING ENE STING 1 - 4" POLY LINES PAD 897-12A 076 12 EXISTING CENTRAL PIPELINE 1-8" STEEL UNE 1-4" POLY LINES X13 1EXISTINGPAD 697-1W 17113C LATERAEXISTING , STING PAD 596-35D ROPOSED PAD 696-5A T EXISTING _ 15 C 1 - PAD 698-50 1 GARDEN GULCH LATERAL -4" POLY UNES-I EXISTING 18C EXTENSION LINE 1 -4" POLYLINE EXIS PING 18C EXTENSION UNE 1 -4" POLYLINE 2 I4" 1 PROPOSED - PAD 697-35A I 35 PROPOSED PAD 797-2A PPADROP79OS7-E2DBN� 1I f1 PORAL 2.4"POLYUNES ROPOSED PAD 797-2D PRQPOSED PAO 797-111--t LJ RICA PROPOSED 1 f PAD 797-11C -"sal` f I vi 1 1 1 PkWILY- PROPOSED OSED J '� 797-14A PROPOSED PAD 797-11D HAYSTACK LATERAL 2-4" POLY UNES X36 1VtEXISTING PAD 696-18A 6a#? ISTING -- 8� -1 's_ 184 LATERAL 0 EXISTING ! ill 15C LATERAL EXISTING PAD 696-18C +II AttgAt eks A13' i i LEGEND O EXIS77NG VALVE CAN EXIS77NG WATER LINES ■ EXISTING PAD LOCATION EXIS77NG ROADS WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS 550 E457 SECOND NORM PHONE 307-876-3638 GREEN RIVER WY 307-976-9839 www wMmlthpe. oom WATER LINE MAP AND VALVE CAN LOCATIONS ENTIRE PROJECT AREA MARATHON OIL COMPANY P.0. BOX .3128 5555 Son Felipe Houston, TX 77253 Houston, IX 77056 DRAWN 8Y: CED DATE: 03/25/2010 CHECKED 8Y: W -1D JOB NO: 25099 SCALE NOTED SHEET 1 OF 1 REVISIONS: 0 32C Water Impoundment - Garden Gulch Road - Garden Gulch Extension Road - Marathon 32C Access Road - CountyRoads022509 Highways 0 0.5 1 2 Miles N S PROJECT NO: 012-1372 DRAWN BY: Jonathan Harris DATE: 01/23/2014 ROAD ACCESS MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO O\O LSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 FIGURE RA -1 1 Soil Data provided by USDA Web Soil Survey 32C Water Impoundment Location cE Legend 0 32C Water Impoundment Soil Type I= 52 - Northwater-Adel complex, 5-50% slopes 55 - Parachute-Irigul complex, 5-30% slopes 56 - Parachute-Irigul-Rhone association, 25-50% slopes 57 - Parachute -Rhone loams, 5-30% slopes 63 - Silas loam, 1-12% slopes Feet W 0 125 250 500 N 0 E PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 7/18/12 SOILS MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO ON OLSSON ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION, CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE S-1 if It • ../f/J'clia I. II 10 Vir 3 -mile radium indicated by dark red circle Pam -4r Legend 32C Water Impoundment =Parcel 213532100009 (880 Acres) r i Parcels 03 -mile Radius 0 0.5 1 2 Miles N s PROJECT NO: 012-1372 DRAWN BY: Jenna Muhlbach DATE: 7/18/12 VICINITY MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO CYS1 OLSSON ASSOCIATES 826 21-1/2 ROAD GRAND JUNCTION, CO 81505 TEL 970.263.7800 FAX 970.263.7456 FIGURE V-1 213527300015 ENCANA OIL & GAS'(USA) INC 213533400010 CHEVRON USA INC 216901100027 BERRY PETROLEUM COMPANY & 216901200001 LATHAM, THOMAS F & GINGER L •216904400003 OXY USA WTP LP 216902200019 JOJO PROPERTIES LLC -' 216912200012 CHEVRON USA INC 217117200953 BLM 216914100022 JOJO PROPERTIES LLC U 32C Water Impoundment - Garden Gulch Road Garden Gulch Extension Road - Marathon 32C Access Road PROJECT NO: 012-1372 DRAWN BY: Jonathan Harris DATE: 04/02/2014 County Road PARCEL MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO 0 0.25 0.5 O\O LSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 Miles w FIGURE P-1 N NTC Responses Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 O‘OLSSON ASSOC r ATE S January 30, 2014 Glenn Hartmann, Senior Planner Garfield County - Community Development Department 108 8`h Street, Suite 401 Glenwood Springs, CO. 81601 RE: Marathon 32C LIR Application LIPA 7775 — Response to NTC Letter Dear Glenn, Please accept the following information and attachments as a response to the NTC letter for the Marathon 320 LIR application. This letter and additional documents will provide the necessary information to allow for a complete review of this request. LUDC 4-203 B. General Application Materials • Ownership — Please provide a copy of the recorded deed(s) that reflects the acquisition of 100% interest in the subject property by Berry Petroleum and a copy of the recorded deed which transfers an interest to Marathon from Berry Petroleum. Olsson acquired these deeds and they are included with this response as Attachment A. • Statement of Authority — Provide a recorded copy of the Limited Power of Attorney provided by Marathon which names Eric Ward as Marathon's attorney-in-fact. Olsson has included the recorded Statement of Authority as Attachment B to this response. • Project Narrative — The narrative briefly mentions future water treatment opportunities and the Site Plan shows locations of proposed tanks, water treatment unit, and storage unit. Is it the goal of the Applicant for these items to be reviewed and approved as part of this application? Yes, it is the intent of this application to approve these items so they could be placed at this facility. Presently, the application doesn't provide enough information to review the impacts of the proposed equipment. The proposed water treatment equipment will consist of a series of skid mounted filters plus two 400 bbl storage tanks as depicted on the site plan. The skid mounted filtering equipment may be 'located on the site or removed to be used or stored off-site as determined by field operations. The exact treatment process and level of treatment will be determined by the intended use of the water. It is anticipated that all equipment associated with this treatment process will be exempt from CDPHE air quality permitting due to the limited emissions it will 760 Horizon Drive, Suite 102, Grand Junction, CO. 81506 Phone 970.263.7800 www.olssonassociates.com generate. Any treated water will be reused in the field and will not increase the traffic on the public road system beyond what is anticipated in the basic traffic analysis. The storage building will protect tools and equipment that will remain on site to service any treatment facility and the water impoundment. LUDC 4-203 D. Site Plan The following information is missing from the Site Plan. Please add the following information to the Site Plan. • Topography Contours — Please label the existing pond contours. What is the elevation of the well pad? How does the site drain? Is there a berm around this site? • Fences — Locate on the plan all existing and proposed fencing. • Site Features — Please put all existing and proposed produced water pipelines/easements, on this plan. Also, if there are any other proposed features (i.e., manifold pads, etc.) for the site that are to be considered at part of this review, please show them on this plan. • Vegetative Cover -- What is the vegetative cover of the site's slopes and adjacent to the subject site? No existing vegetation is shown on the Site Pian. • Elevations -- Elevation drawings showing existing grade, finished grade, and height of the existing and proposed structures above existing grade are required. • Signs — Please show the location and size of signs for the purpose of identification, advertising, and traffic control. A revised site plan is included as Attachment C to this response. LUDC 4-203 E. Grading and Drainage Plan • Provide a plan as per this section and supports the narrative provided under the Grading and Drainage Plan tab in the application. A plan package (LIR Plans) has been prepared (9 sheets) to be considered the Grading and Drainage Plan and is included as Attachment D. The plan package includes the following: • Cover Sheet • Location Map • Site Plan • Grading Plan and Pond Sections • Roadway Plan and Profile • Proposed Site Details • Fence Details • Anchor Trench and Liner Details • Drainage Summary 1. Site Map. A Site Map showing locations of any existing structures, Waterbodies or hydrologic features on the site, including intermittent water features, Wetlands, and the 100 -year Floodplain boundaries. The Location Map includes a listing of the hydrologic features in the area. There are no streams, wetlands, or 100 -year floodplain boundaries within the project site itself. The site is located on a relative high point as illustrated by the contours within the Site Plan. The physical structures at the site are labeled on the Site Plan. 2 2. Drainage Structures. a. Locations of existing and proposed drainage structures or natural drainage features affecting site drainage on the parcel and within 10 feet adjacent to the site boundary, including street gutters, storm sewers, drainage channels, and other water conveyance structures; and Wetlands or other Waterbodies receiving storm Runoff from the site. The site is located on a relative high point. A small portion of off-site drainage sheet flows towards the site. The topography is such that the stormwater cannot be diverted, therefore, this stormwater is accounted for with the Drainage Report. The basin can be seen within the Drainage Summary. Otherwise stormwater drains away from the site. b. Preliminary engineering design and construction features for drainage structures to be constructed. No drainage structures are required to be constructed. Stormwater from off-site and on-site is discussed within the Drainage Report. 3. Topography. Existing topography at reasonable contour intervals to provide necessary detail of the site. The map should extend a minimum of 10 feet beyond the property line and show the location of the property line. The existing topography is shown on both the Site Plan and the Grading Plan and Pond Sections. The topography is shown at 1 foot contour intervals. 4. Grading Plan. A grading plan showing the proposed topography at reasonable contour intervals that provides necessary detail of the site. The plan shall show elevations, dimensions, location, extent, and Slope of all proposed clearing, and Grading including building site and driveway grades. The proposed grading is shown on the Grading Plan and Pond Sections. No additional grading is anticipated. Detailed spot elevations of the improvements are shown to illustrate the changes. Sections of the pond are included to show the slopes of the proposed grades. The contour interval is 1 foot. In addition a Roadway Plan and Profile sheet was developed to illustrate the existing grades of the access road. No improvements to the roadway are anticipated. 5. Soil Stockpile and Snow Storage Areas. Probable locations of soil stockpiles and snow storage areas. No new soil stockpiles are anticipated due to the minor levels of earthwork required. Existing soil stockpiles are stabilized with a native seed mix and will be used for the final reclamation of the pad after all the existing and any future gas wells no longer produce. An area of snow storage is shown on the Site Plan 6. Drainage Plan. Proposed drainage plan. A Drainage Report is included with the submittal A Drainage Summary is included with the plan package. 7. Equipment Storage Areas. Location of storage areas designated for equipment, fuel, lubricants, chemical, and waste storage with an explanation of spill containment structures. 3 Equipment storage is not anticipated at this location. 8. Temporary Roads. Location of temporary roads designed for use during the construction period. No temporary roads are anticipated with the construction. Existing roadways will be utilized. 9. Areas of Steep Slope. Areas with Slope of 20% or greater shall be identified by location and percentage of Slope, both for the existing site conditions and within the developed area. The areas of steep slope are labeled on the Site Ran. 10. Construction Schedule. Construction schedule indicating the anticipated starting and completion time periods of the site Grading and/or construction sequence, including the installation and removal of erosion and sediment control measures, and the estimated duration of exposure of each area prior to the completion of temporary erosion and sediment control measures. The construction schedule includes 16 weeks including mobilization and demobilization. Stormwater management is ongoing at the site and throughout the field. Therefore, stormwater management is negligible in the schedule. 11. Permanent Stabilization. A brief description of how the site will be stabilized after construction is completed. Grading at the site is limited to within the pond. Upon completion, a synthetic pond liner will be placed within the pond. This is illustrated within the Anchor Trench and Pond Liner Details. The pond liner will serve as stabilization for the proposed grading. 12. Erosion Control Measures. Plan view drawings of all erosion and sediment control measures showing approximate locations and site drainage patterns for construction phases and final design elements. Text may be necessary to accompany and explain the drawings. Typical erosion control measures should be depicted using standard map symbols. An active stormwater management plan is implemented by Marathon throughout their field. This site is included within that plan. Erosion Control Measures for the area can be seen within the Stormwater Management Plan (SUMP) and is include as Attachment E. Erosion control measures for the planned earthwork are not required since the activity is within the pond. 13. Estimated Cost. Estimated total cost, including installation and maintenance, of the required temporary soil erosion and sediment control measures. An estimated construction cost of $2,000.00 for temporary soil and erosion control measures was determined. This was used to improve drainage and prevent water from collecting and entering the pond. This site is stabilized and inspected on a monthly basis to determine if any maintenance is required for compliance with COGCC rules. 14. Calculations. Any calculations made for determining rainfall, Runoff, sizing any sediment basins, diversions, conveyance, or detention/retention facilities. 4 Calculations are included within the Drainage Report. 15. Neighboring Areas. A description of neighboring areas with regard to land use and existing pertinent features such as lakes, streams, structures, roads, etc. A description of the nearby water features is included within the Drainage Report as well as labeled on the Location Map. The surrounding land uses are all related to oil and gas operations. 16. Stormwater Management. A description of the stormwater management planning concept for the site, including both structural and nonstructural best management practices. An electronic version of the SWMP is included with this submittal as Attachment E. In addition a Drainage Report was also included with the original application. 17. Stormwater Management Plan. Copy of the stormwater management plan application to CDPHE with date of submittal. An electronic version of the SWMP is included with the submittal as Attachment E. 18. Reclamation Plan. A reclamation plan consistent with the standards in section 7-207. A reclamation plan is not required per code section 7-208 since the site is currently stabilized. The earthwork is limited to within the pond. The pad also contains existing natural gas wells and has the potential of additional wells that would significantly extend the life of the well pad. 19. Hydraulic Calculations. Hydrologic, hydraulic, and all other calculations used to size and design drainage facilities and/or structural BMPs. Hydraulic Calculations are shown within the Drainage Report. 20. Maintenance Requirements. Maintenance requirements for all proposed BMPs should be discussed including access, schedules, costs, and designation of a responsible party. Maintenance Requirements are shown within the SWMP. 21. Spill Prevention Control and Countermeasures Plan, if Applicable. A SPCC Plan will be required for any facility with the potential to discharge oil of any kind or in any form including, but not limited to, petroleum, fuel oil, sludge, oil refuse and oil mixed with wastes, in quantities that may be harmful to navigable water and adjoining shoreline, per EPA regulations. Spill Prevention Control and Countermeasures Plan (SPCC) for this facility was included with the application. 22. Additional Information or Detail. Other information or data and additional detail as may be reasonably required by the Director. Additional detail of the project is included within the plan package. 5 23. Signature Blocks. Signature block for owner or legal agent acknowledging the review and acceptance of responsibility, and a signature and stamped statement by the qualified individual acknowledging responsibility for the preparation of the Grading and Drainage Plan. The plans within the plan package as well as the Drainage Report are signed and sealed by a Colorado registered professional engineer, LUDC 4-203 G. Impact Analysis • Soil Characteristics — The narrative under Impact Analysis and NRCS soil survey was provided which indicates the soils type found on-site, however no analysis of that type of soil impact on the existing and proposed development was included. A qualified individual is required to provide this information however there is no indication who completed the analysis. Soil Characteristics are included in the reformatted Natural and Geological Hazard Assessment Report. This report is signed by a qualified Professional Geologist and is included as Attachment F. • Geology and Hazards — The Geologic and Soils Hazards Report states that The water storage Site appears to have been constructed so it is expected that a major increase in construction effort or special design were necessary and were performed to mitigate these hazards, and/or intensive maintenance is required for the existing Site with regard to the steep slope, depth of rock, and potential for seepage." What evidence supports this assumption? Please clarify. How will proposed construction on-site address/mitigate the geologic hazards? The pond is located in native soil on the cut side of the pad. The pond will have two liners and a leak detection to address the potential of leaks. Natural hazards are not anticipated to have a detrimental impact on the facility. A Geohydrology Report is provided in the application and it is unclear who wrote this report. Please provide evidence this report was written by a qualified professional. Olsson has reformatted the Natural and Geological Hazard Assessment Report. This report is signed by a qualified Professional Geologist. • Groundwater and Aquifer Recharge Areas — Please clarify what Best Management Practices presently exist or will be implemented on-site to control stormwater run-off and soil erosion. This information is available in the SWMP for Pad Site 596-32C. The pad perimeter is bermed at the top of downhill slopes, the downhill toe of the slope is also bermed or has fiber rolls installed, a sediment pond/depression was placed on the pad, and disturbed areas off of the pad were seeded and hydro -mulched. In the application it states that Marathon's objective is to minimize the need for off-site disposal. How much produced water is stored on-site and how does the Applicant prevent it from entering adjacent water bodies and the groundwater? 6 • The facility is designed to hold 35,279 bbls as working capacity. This allows 2 feet of free -board. • The 2 feet of free -board will accommodate direct precipitation that may enter the impoundment and allows a safety margin. • The facility is designed to prevent impacts to adjacent water bodies and groundwater. The impoundment is lined with two 60 mil reinforced Polyethylene (RPE) liners over bentonite mats. • The facility is designed with leak detection. • Four wells are installed to monitor groundwater. How much is anticipated to be trucked off-site for disposal? Marathon intends to transport most of the water via pipeline. Trucking wilt occur only as a last resort. • Nuisances — Please provide an entire copy of the air quality permit for this site as well as additional demonstration of how you will comply with this standard. Are there any other air permits required for other equipment on-site? Do you have an air permit for the proposed equipment? The entire copy of the air quality permit is included with the response as Attachment G. Air quality permits compliance is based on through -put which is monitored and documented. Marathon evaluates their facilities on a yearly basis to determine if additional permits are required or existing permits need modification. • Hours of Operation — Please clarify what "regular basis" means in the narrative of this section. The site is visually inspected approximately five times a week during daylight hours, and formally inspected on a monthly basis. LUDC 4-203 L. Traffic Study • The narrative indicates that majority of the produced water will be piped to the site and only as needed by truck. Please clarify what "only as needed by truck" means. How many truck trips are anticipated? The intent of the facility is to transport water via pipeline. Trucks will be used only when this option is not available. The traffic analysis states that approximately 10% of the trips will include trucks which will amount to 1,460 truck trips on the public road system during the 20 year life of the facility. This averages 73 trips per year on the public road system. Does the Traffic Study take into consideration trucks leaving the site to dispose the produced water? Yes. How many trips are leaving the site are anticipated? The traffic analysis states that approximately 10% of the trips will include trucks which will amount to 1,460 trucks trips on the public road system during the 20 year life of the facility Half of this amount will be entering and half will be leaving the larger property. This averages 73 trips per year on the public road system. 7 LUDC - Article 7 Divisions 1, 2, and 3 7-105 Central Water Distribution and Wastewater Systems • The application indicates that portable toilets will be used on-site. In order to determine if the land use is adequately served please provide a letter of service from a licensed hauler and identify where the by-product will be disposed. Marathon has obtained a new will serve letter from Redi Services and is included with this response as Attachment H. 7-107 Access and Roadways • The application indicates that the site is accessed by Garden Gulch Road and other private roads. Please clarify where Garden Gulch Road ends and the other private roads begin. Olsson has created a new figure to demonstrate the location of the access roads and is included as Attachment I. • The Applicant is responsible for demonstrating legal and physical access to the site. Documentation is provided for Garden Gulch Road but doesn't address the other private roads - are there easements or agreements related to the other private road system? The agreement for the access (lease) road off of the Garden Gulch Extension Road is provided with this response as Attachment J. This agreement allows Marathon to access their property in Section 32 across land owned by Chevron. What are the physical characteristics of the other private roads and do they meet County Standards in Article 7? If these roads don't meet the standards of Article 7, a waiver of standards as per Section 4-118 may be submitted. Once Garfield County determines the status of the Garden Gulch Road and the Garden Gulch Extension Road relative to previous approvals a more complete description of the physical characteristics of the private road will be provided. • The Garden Gulch Road license is conditioned on each Garden Gulch Road participant paying to Garden Gulch, LLC the annual maintenance costs of the road. Please provide evidence that Marathon is current on its payment of annual maintenance costs to assure that Marathon's license is active. Marathon is current on its payment to the Garden Gulch, LLC. Documents confirming the status of Marathon's financial contribution will be provided as Attachment K when they become available. • The Road Construction and Maintenance Agreement lacks a signature on behalf of Chevron (Page 13 of 36 of the Road Construction and Maintenance Agreement). Please provide a license grant or similar instrument that has been executed by Chevron. Please review the document that was provided including Exhibit "C". This directs PDC to proceed with the construction of Garden Gulch Road and is signed by Chevron. Additional 8 exhibits assign cost sharing to operators including Marathon. This document has been used to demonstrate legal access on this road since it was executed in 2007. 7-108 Use of Land Subject to Natural Hazards • Please address radiation on the subject site. Olsson has reformatted the Natural and Geological Hazard Assessment Report to address radiation. This analysis concluded that there are no significant radioactive mineral deposits known in the immediate area of the site. 7-109 Fire Protection • Please provide the Emergency Response Plan so it can be determined if it is adequate. A CD rather than a paper copy can be submitted. A CD with the entire Emergency Response Plan is included with this response as Attachment M. 7-205 Environmental Quality • Please provide the Stormwater Management Plan (SWMP) for the site. What are the SWMP's BMPs being used and where are they located on-site? A CD with the entire SWMP is included with this response as Attachment E. The pad perimeter is bermed at the top of downhill slopes, the downhill toe of the slope is also bermed or has fiber rolls installed, a sediment pond/depression was placed on the pad, and disturbed areas off of the pad were seeded and hydro -mulched. 7-1001 Additional Standards for Industrial Uses • How do you know that the facility complies with the COGCC Noise Standards? A noise analysis is provided as Attachment N to this response. This analysis demonstrates that the equipment will comply with the COGCC standards for remote locations and produce approximately 51.5 dB(a) at a distance of 350 feet from the source of the noise. Other Comments • The Landscape Plan is a submittal requirement for all Limited impact applications however Section 7-303 excludes industrial uses from a requirement to meet Landscape Standards making this submittal requirement 'not applicable'. No waiver is required. No action required. • The Improvements Agreement and Development Agreement are hereby waived as submittal requirements. No action required. 9 • To be better understand how this application addresses impacts to wildlife, please submit the Colorado Parks and Wildlife's Wildlife Mitigation Plan for this site. Appendix A of the Wildlife Mitigation Plan is included as Attachment 0 with this response. Please contact me if you have any questions regarding this information. Sincere)ii______ Jeff Hofman cc: Eric Ward Vicki Schoeber Attachments: A. Recorded Deeds — Lathams to Berry and Berry to Marathon B. Recorded Statement of Authority /POA C. Revised Site Plan D. LIR Plans E. SWMP (On CD) F. Natural and Geological Hazard Assessment Report G. Air Permit H. Will Serve Letter Roadway Figure J. Access (Lease) Road Agreement K. Garden Gulch Payment Status Letter TBD L. Road Construction and Maintenance Agreement M. ERP (On CD) N. Noise Analysis O. Wildlife Management Plan 10 (AOLSSON ASSOCIATES April 17, 2014 Glenn Hartmann, Senior Planner Garfield County - Community Development Department 108 8th Street, Suite 401 Glenwood Springs, CO. 81601 RE: Marathon 32C LIR Application LIPA 7775 — Response to NTC Letter Dear Glenn, Please accept the attached information that will complete the response to the NTC letter issued for this application. This information includes: Waiver Request - Addendum — This addendum contains a waiver of submittal materials for the Garden Gulch Road and the Garden Gulch Road Extension in relationship to Policy 04-01 and a waiver of standards of table 7-107 for both of these roads. Additionally, a waiver is being request for the table 7-107 standards consisting of right-of-way, ditch dimensions, cross -slope, and maximum percent grade for the Marathon Lease Road. Marathon Lease Road Assessment — This report contains the analysis of the Marathon Lease Road and an assessment of the road condition compared to the Primitive Roadway -Driveway standards found in table 7-107. Access Analysis — This document and the associated attachments demonstrate legal access to a public right-of-way. It includes a map that identifies land ownership along the access roads, agreements to construct, maintain and travel over the roads leading to the Marathon 32C facility. Additionally, a letter from the company that manages the Garden Gulch Road and Garden Gulch Road Extension establishing that Marathon is current on its payment of annual maintenance costs is included. These documents complete the information requested in the NTC letter. Please contact me if you have any questions. Sincerely, Jeff Hofman 760 Horizon Drive, Suite 102, Grand Junction, CO. 81506 Phone 970.263.7800 www.olssonassociates.com