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HomeMy WebLinkAbout1.01 Application-Part2USDA United States aim Department of Agr culture 4 \KS Natural Resources Conservation Service A product of the National Cooperative Soil Survey, a joint effort of the United States Department of Agriculture and other Federal agencies, State agencies including the Agricultural Experiment Stations, and local participants Custom Soil Resource Report for Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Marathon 32C Water Impoundment July 18, 2012 Preface Soil surveys contain information that affects land use planning in survey areas. They highlight soil limitations that affect various land uses and provide information about the properties of the soils in the survey areas. Soil surveys are designed for many different users, including farmers, ranchers, foresters, agronomists, urban planners, community officials, engineers, developers, builders, and home buyers. Also, conservationists, teachers, students, and specialists in recreation, waste disposal, and pollution control can use the surveys to help them understand, protect, or enhance the environment. Various land use regulations of Federal, State, and local governments may impose special restrictions on land use or land treatment. Soil surveys identify soil properties that are used in making various land use or land treatment decisions. The information is intended to help the land users identify and reduce the effects of soil limitations on various land uses. The landowner or user is responsible for identifying and complying with existing laws and regulations. Although soil survey information can be used for general farm, local, and wider area planning, onsite investigation is needed to supplement this information in some cases. Examples include soil quality assessments (http://soils.usda.gov/sqi/) and certain conservation and engineering applications. For more detailed information, contact your local USDA Service Center (http://offices.sc.egov.usda.gov/locator/app? agency=nrcs) or your NRCS State Soil Scientist (http://soils.usda.gov/contact/ state_offices/). Great differences in soil properties can occur within short distances. Some soils are seasonally wet or subject to flooding. Some are too unstable to be used as a foundation for buildings or roads. Clayey or wet soils are poorly suited to use as septic tank absorption fields. A high water table makes a soil poorly suited to basements or underground installations. The National Cooperative Soil Survey is a joint effort of the United States Department of Agriculture and other Federal agencies, State agencies including the Agricultural Experiment Stations, and local agencies. The Natural Resources Conservation Service (NRCS) has leadership for the Federal part of the National Cooperative Soil Survey. Information about soils is updated periodically. Updated information is available through the NRCS Soil Data Mart Web site or the NRCS Web Soil Survey. The Soil Data Mart is the data storage site for the official soil survey information. The U.S. Department of Agriculture (USDA) prohibits discrimination in all its programs and activities on the basis of race, color, national origin, age, disability, and where applicable, sex, marital status, familial status, parental status, religion, sexual orientation, genetic information, political beliefs, reprisal, or because all or a part of an individual's income is derived from any public assistance program. (Not all prohibited bases apply to all programs.) Persons with disabilities who require alternative means 2 for communication of program information (Braille, large print, audiotape, etc.) should contact USDA's TARGET Center at (202) 720-2600 (voice and TDD). To file a complaint of discrimination, write to USDA, Director, Office of Civil Rights, 1400 Independence Avenue, S.W., Washington, D.C. 20250-9410 or call (800) 795-3272 (voice) or (202) 720-6382 (TDD). USDA is an equal opportunity provider and employer. 3 Contents Preface 2 How Soil Surveys Are Made 6 Soil Map 8 Soil Map 9 Legend 10 Map Unit Legend 11 Map Unit Descriptions 11 Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties 13 55—Parachute-Irigul complex, 5 to 30 percent slopes 13 56—Parachute-Irigul-Rhone association, 25 to 50 percent slopes 14 Soil Information for All Uses 17 Suitabilities and Limitations for Use 17 Building Site Development 17 Corrosion of Concrete 17 Corrosion of Steel 21 Local Roads and Streets 25 Land Classifications 29 Ecological Site ID: NRCS Rangeland Site 29 Water Management 33 Excavated Ponds (Aquifer -Fed) 33 Pond Reservoir Areas 38 Soil Properties and Qualities 44 Soil Qualities and Features 44 Depth to a Selected Soil Restrictive Layer: Lithic bedrock 44 Drainage Class 48 Hydrologic Soil Group 52 Representative Slope 56 Unified Soil Classification (Surface) 60 Water Features 64 Depth to Water Table 64 Flooding Frequency Class 69 Soil Reports 74 Building Site Development 74 Roads and Streets, Shallow Excavations, and Lawns and Landscaping74 Land Classifications 76 Taxonomic Classification of the Soils 77 Soil Chemical Properties 78 Chemical Soil Properties 78 Soil Physical Properties 81 Physical Soil Properties 81 Soil Qualities and Features 85 Soil Features 85 Water Management 88 Ponds and Embankments 88 4 Custom Soil Resource Report References 91 5 How Soil Surveys Are Made Soil surveys are made to provide information about the soils and miscellaneous areas in a specific area. They include a description of the soils and miscellaneous areas and their location on the landscape and tables that show soil properties and limitations affecting various uses. Soil scientists observed the steepness, length, and shape of the slopes; the general pattern of drainage; the kinds of crops and native plants; and the kinds of bedrock. They observed and described many soil profiles. A soil profile is the sequence of natural layers, or horizons, in a soil. The profile extends from the surface down into the unconsolidated material in which the soil formed or from the surface down to bedrock. The unconsolidated material is devoid of roots and other living organisms and has not been changed by other biological activity. Currently, soils are mapped according to the boundaries of major land resource areas (MLRAs). MLRAs are geographically associated land resource units that share common characteristics related to physiography, geology, climate, water resources, soils, biological resources, and land uses (USDA, 2006). Soil survey areas typically consist of parts of one or more MLRA. The soils and miscellaneous areas in a survey area occur in an orderly pattern that is related to the geology, landforms, relief, climate, and natural vegetation of the area. Each kind of soil and miscellaneous area is associated with a particular kind of landform or with a segment of the landform. By observing the soils and miscellaneous areas in the survey area and relating their position to specific segments of the landform, a soil scientist develops a concept, or model, of how they were formed. Thus, during mapping, this model enables the soil scientist to predict with a considerable degree of accuracy the kind of soil or miscellaneous area at a specific location on the landscape. Commonly, individual soils on the landscape merge into one another as their characteristics gradually change. To construct an accurate soil map, however, soil scientists must determine the boundaries between the soils. They can observe only a limited number of soil profiles. Nevertheless, these observations, supplemented by an understanding of the soil -vegetation -landscape relationship, are sufficient to verify predictions of the kinds of soil in an area and to determine the boundaries. Soil scientists recorded the characteristics of the soil profiles that they studied. They noted soil color, texture, size and shape of soil aggregates, kind and amount of rock fragments, distribution of plant roots, reaction, and other features that enable them to identify soils. After describing the soils in the survey area and determining their properties, the soil scientists assigned the soils to taxonomic classes (units). Taxonomic classes are concepts. Each taxonomic class has a set of soil characteristics with precisely defined limits. The classes are used as a basis for comparison to classify soils systematically. Soil taxonomy, the system of taxonomic classification used in the United States, is based mainly on the kind and character of soil properties and the arrangement of horizons within the profile. After the soil scientists classified and named the soils in the survey area, they compared the 6 Custom Soil Resource Report individual soils with similar soils in the same taxonomic class in other areas so that they could confirm data and assemble additional data based on experience and research. The objective of soil mapping is not to delineate pure map unit components; the objective is to separate the landscape into landforms or landform segments that have similar use and management requirements. Each map unit is defined by a unique combination of soil components and/or miscellaneous areas in predictable proportions. Some components may be highly contrasting to the other components of the map unit. The presence of minor components in a map unit in no way diminishes the usefulness or accuracy of the data. The delineation of such landforms and landform segments on the map provides sufficient information for the development of resource plans. If intensive use of small areas is planned, onsite investigation is needed to define and locate the soils and miscellaneous areas. Soil scientists make many field observations in the process of producing a soil map. The frequency of observation is dependent upon several factors, including scale of mapping, intensity of mapping, design of map units, complexity of the landscape, and experience of the soil scientist. Observations are made to test and refine the soil - landscape model and predictions and to verify the classification of the soils at specific locations. Once the soil -landscape model is refined, a significantly smaller number of measurements of individual soil properties are made and recorded. These measurements may include field measurements, such as those for color, depth to bedrock, and texture, and laboratory measurements, such as those for content of sand, silt, clay, salt, and other components. Properties of each soil typically vary from one point to another across the landscape. Observations for map unit components are aggregated to develop ranges of characteristics for the components. The aggregated values are presented. Direct measurements do not exist for every property presented for every map unit component. Values for some properties are estimated from combinations of other properties. While a soil survey is in progress, samples of some of the soils in the area generally are collected for laboratory analyses and for engineering tests. Soil scientists interpret the data from these analyses and tests as well as the field -observed characteristics and the soil properties to determine the expected behavior of the soils under different uses. Interpretations for all of the soils are field tested through observation of the soils in different uses and under different levels of management. Some interpretations are modified to fit local conditions, and some new interpretations are developed to meet local needs. Data are assembled from other sources, such as research information, production records, and field experience of specialists. For example, data on crop yields under defined levels of management are assembled from farm records and from field or plot experiments on the same kinds of soil. Predictions about soil behavior are based not only on soil properties but also on such variables as climate and biological activity. Soil conditions are predictable over long periods of time, but they are not predictable from year to year. For example, soil scientists can predict with a fairly high degree of accuracy that a given soil will have a high water table within certain depths in most years, but they cannot predict that a high water table will always be at a specific level in the soil on a specific date. After soil scientists located and identified the significant natural bodies of soil in the survey area, they drew the boundaries of these bodies on aerial photographs and identified each as a specific map unit. Aerial photographs show trees, buildings, fields, roads, and rivers, all of which help in locating boundaries accurately. 7 Soil Map The soil map section includes the soil map for the defined area of interest, a list of soil map units on the map and extent of each map unit, and cartographic symbols displayed on the map. Also presented are various metadata about data used to produce the map, and a description of each soil map unit. 8 39° 34' 8" 39° 34' 0" Zo 74'880 740920 740960 741000 Custom Soil Resource Report Soil Map 741040 741080 741120 74160 74100 74140 ivirt 41 • v . C 3. M▪ - —co co co �o w.J r w . M • _ M a� N CO co co '• �' s - m co f' v co• •M co m v v ii�, w ' u ! �� JE — i , a _ v e �., s 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed onAsize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 0 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND Area of Interest (AOI) Area of Interest (AOI) Soils Soil Map Units Special Point Features Blowout Borrow Pit Clay Spot Closed Depression Gravel Pit Gravelly Spot Landfill Lava Flow Marsh or swamp Mine or Quarry Miscellaneous Water Perennial Water Rock Outcrop Saline Spot Sandy Spot Severely Eroded Spot Sinkhole Slide or Slip Sodic Spot Spoil Area Stony Spot Very Stony Spot I, Wet Spot A Other Special Line Features Gully Short Steep Slope Other Political Features 0 Cities Water Features Streams and Canals Transportation +++ Rails /wr Interstate Highways US Routes Major Roads y Local Roads MAP INFORMATION Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Map Unit Legend Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map Unit Symbol Map Unit Name Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes 8.3 48.6% Totals for Area of Interest 17.21 100.0% Map Unit Descriptions The map units delineated on the detailed soil maps in a soil survey represent the soils or miscellaneous areas in the survey area. The map unit descriptions, along with the maps, can be used to determine the composition and properties of a unit. A map unit delineation on a soil map represents an area dominated by one or more major kinds of soil or miscellaneous areas. A map unit is identified and named according to the taxonomic classification of the dominant soils. Within a taxonomic class there are precisely defined limits for the properties of the soils. On the landscape, however, the soils are natural phenomena, and they have the characteristic variability of all natural phenomena. Thus, the range of some observed properties may extend beyond the limits defined for a taxonomic class. Areas of soils of a single taxonomic class rarely, if ever, can be mapped without including areas of other taxonomic classes. Consequently, every map unit is made up of the soils or miscellaneous areas for which it is named and some minor components that belong to taxonomic classes other than those of the major soils. Most minor soils have properties similar to those of the dominant soil or soils in the map unit, and thus they do not affect use and management. These are called noncontrasting, or similar, components. They may or may not be mentioned in a particular map unit description. Other minor components, however, have properties and behavioral characteristics divergent enough to affect use or to require different management. These are called contrasting, or dissimilar, components. They generally are in small areas and could not be mapped separately because of the scale used. Some small areas of strongly contrasting soils or miscellaneous areas are identified by a special symbol on the maps. If included in the database for a given area, the contrasting minor components are identified in the map unit descriptions along with some characteristics of each. A few areas of minor components may not have been observed, and consequently they are not mentioned in the descriptions, especially where the pattern was so complex that it was impractical to make enough observations to identify all the soils and miscellaneous areas on the landscape. The presence of minor components in a map unit in no way diminishes the usefulness or accuracy of the data. The objective of mapping is not to delineate pure taxonomic classes but rather to separate the landscape into landforms or landform segments that have similar use and management requirements. The delineation of such segments on the map provides sufficient information for the development of resource plans. If intensive use of small areas is planned, however, onsite investigation is needed to define and locate the soils and miscellaneous areas. 11 Custom Soil Resource Report An identifying symbol precedes the map unit name in the map unit descriptions. Each description includes general facts about the unit and gives important soil properties and qualities. Soils that have profiles that are almost alike make up a soil series. Except for differences in texture of the surface layer, all the soils of a series have major horizons that are similar in composition, thickness, and arrangement. Soils of one series can differ in texture of the surface layer, slope, stoniness, salinity, degree of erosion, and other characteristics that affect their use. On the basis of such differences, a soil series is divided into soil phases. Most of the areas shown on the detailed soil maps are phases of soil series. The name of a soil phase commonly indicates a feature that affects use or management. For example, Alpha silt loam, 0 to 2 percent slopes, is a phase of the Alpha series. Some map units are made up of two or more major soils or miscellaneous areas. These map units are complexes, associations, or undifferentiated groups. A complex consists of two or more soils or miscellaneous areas in such an intricate pattern or in such small areas that they cannot be shown separately on the maps. The pattern and proportion of the soils or miscellaneous areas are somewhat similar in all areas. Alpha -Beta complex, 0 to 6 percent slopes, is an example. An association is made up of two or more geographically associated soils or miscellaneous areas that are shown as one unit on the maps. Because of present or anticipated uses of the map units in the survey area, it was not considered practical or necessary to map the soils or miscellaneous areas separately. The pattern and relative proportion of the soils or miscellaneous areas are somewhat similar. Alpha - Beta association, 0 to 2 percent slopes, is an example. An undifferentiated group is made up of two or more soils or miscellaneous areas that could be mapped individually but are mapped as one unit because similar interpretations can be made for use and management. The pattern and proportion of the soils or miscellaneous areas in a mapped area are not uniform. An area can be made up of only one of the major soils or miscellaneous areas, or it can be made up of all of them. Alpha and Beta soils, 0 to 2 percent slopes, is an example. Some surveys include miscellaneous areas. Such areas have little or no soil material and support little or no vegetation. Rock outcrop is an example. 12 Custom Soil Resource Report Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties 55—Parachute-Irigul complex, 5 to 30 percent slopes Map Unit Setting Elevation: 7,600 to 8,800 feet Mean annual precipitation: 18 to 22 inches Mean annual air temperature: 36 to 40 degrees F Frost -free period: 65 to 90 days Map Unit Composition Parachute and similar soils: 60 percent Irigul and similar soils: 30 percent Description of Parachute Setting Landform: Mountains Landform position (two-dimensional): Shoulder, summit Landform position (three-dimensional): Mountaintop Down-slope shape: Linear Across -slope shape: Convex Parent material: Residuum weathered from shale and siltstone and/or residuum weathered from sandstone and shale Properties and qualities Slope: 5 to 30 percent Depth to restrictive feature: 20 to 40 inches to paralithic bedrock Drainage class: Well drained Capacity of the most limiting layer to transmit water (Ksat): Moderately low to moderately high (0.06 to 0.20 in/hr) Depth to water table: More than 80 inches Frequency of flooding: None Frequency of ponding: None Available water capacity: Low (about 4.0 inches) Interpretive groups Land capability (nonirrigated): 6e Ecological site: Mountain Loam (R048AY228C0) Typical profile 0 to 10 inches: Loam 10 to 25 inches: Very channery loam, extremely channery loam 25 to 29 inches: Unweathered bedrock Description of Irigul Setting Landform: Hills Landform position (two-dimensional): Backslope, shoulder, toeslope, summit, footslope Landform position (three-dimensional): Crest Down-slope shape: Convex Across -slope shape: Convex Parent material: Residuum weathered from sandstone and shale 13 Custom Soil Resource Report Properties and qualities Slope: 5 to 30 percent Depth to restrictive feature: 5 to 20 inches to lithic bedrock Drainage class: Well drained Capacity of the most limiting layer to transmit water (Ksat): Moderately low to moderately high (0.06 to 0.20 in/hr) Depth to water table: More than 80 inches Frequency of flooding: None Frequency of ponding: None Available water capacity: Very low (about 1.3 inches) Interpretive groups Land capability (nonirrigated): 7e Ecological site: Loamy Slopes (R048AY303C0) Typical profile 0 to 6 inches: Channery loam 6 to 13 inches: Very channery loam 13 to 17 inches: Unweathered bedrock 56—Parachute-Irigul-Rhone association, 25 to 50 percent slopes Map Unit Setting Elevation: 7,600 to 8,800 feet Mean annual precipitation: 18 to 22 inches Mean annual air temperature: 36 to 40 degrees F Frost -free period: 65 to 80 days Map Unit Composition Parachute and similar soils: 35 percent Irigul and similar soils: 30 percent Rhone and similar soils: 20 percent Description of Parachute Setting Landform: Mountains Landform position (two-dimensional): Summit, shoulder Landform position (three-dimensional): Mountaintop Down-slope shape: Linear Across -slope shape: Convex Parent material: Colluvium derived from sandstone and shale and/or residuum weathered from siltstone Properties and qualities Slope: 25 to 50 percent Depth to restrictive feature: 20 to 40 inches to paralithic bedrock Drainage class: Well drained Capacity of the most limiting layer to transmit water (Ksat): Moderately low to moderately high (0.06 to 0.20 in/hr) 14 Custom Soil Resource Report Depth to water table: More than 80 inches Frequency of flooding: None Frequency of ponding: None Available water capacity: Low (about 4.0 inches) Interpretive groups Land capability (nonirrigated): 7e Ecological site: Brushy Loam (R048AY238C0) Typical profile 0 to 10 inches: Loam 10 to 25 inches: Very channery loam, extremely channery loam 25 to 29 inches: Unweathered bedrock Description of Irigul Setting Landform: Hills Landform position (two-dimensional): Toeslope, summit, footslope, backslope, shoulder Landform position (three-dimensional): Crest Down-slope shape: Convex Across -slope shape: Convex Parent material: Residuum weathered from sandstone and shale Properties and qualities Slope: 25 to 50 percent Depth to restrictive feature: 5 to 20 inches to lithic bedrock Drainage class: Well drained Capacity of the most limiting layer to transmit water (Ksat): Moderately low to moderately high (0.06 to 0.20 in/hr) Depth to water table: More than 80 inches Frequency of flooding: None Frequency of ponding: None Available water capacity: Very low (about 1.3 inches) Interpretive groups Land capability (nonirrigated): 7e Ecological site: Loamy Slopes (R048AY303C0) Typical profile 0 to 6 inches: Channery loam 6 to 13 inches: Very channery loam 13 to 17 inches: Unweathered bedrock Description of Rhone Setting Landform: Hills, mountains Landform position (two-dimensional): Backslope, shoulder, summit, footslope Landform position (three-dimensional): Mountainflank, side slope Down-slope shape: Concave Across -slope shape: Concave Parent material: Colluvium derived from sandstone and shale and/or residuum weathered from sandstone and shale Properties and qualities Slope: 25 to 50 percent 15 Custom Soil Resource Report Depth to restrictive feature: 40 to 60 inches to paralithic bedrock Drainage class: Well drained Capacity of the most limiting layer to transmit water (Ksat): Moderately low to moderately high (0.06 to 0.20 in/hr) Depth to water table: More than 80 inches Frequency of flooding: None Frequency of ponding: None Available water capacity: Moderate (about 7.5 inches) Interpretive groups Land capability (nonirrigated): 7e Ecological site: Brushy Loam (R048AY238C0) Typical profile 0 to 10 inches: Loam 10 to 39 inches: Channery loam 39 to 55 inches: Very channery loam 55 to 59 inches: Unweathered bedrock Soil Information for All Uses Suitabilities and Limitations for Use The Suitabilities and Limitations for Use section includes various soil interpretations displayed as thematic maps with a summary table for the soil map units in the selected area of interest. A single value or rating for each map unit is generated by aggregating the interpretive ratings of individual map unit components. This aggregation process is defined for each interpretation. Building Site Development Building site development interpretations are designed to be used as tools for evaluating soil suitability and identifying soil limitations for various construction purposes. As part of the interpretation process, the rating applies to each soil in its described condition and does not consider present land use. Example interpretations can include corrosion of concrete and steel, shallow excavations, dwellings with and without basements, small commercial buildings, local roads and streets, and lawns and landscaping. Corrosion of Concrete "Risk of corrosion" pertains to potential soil -induced electrochemical or chemical action that corrodes or weakens concrete. The rate of corrosion of concrete is based mainly on the sulfate and sodium content, texture, moisture content, and acidity of the soil. Special site examination and design may be needed if the combination of factors results in a severe hazard of corrosion. The concrete in installations that intersect soil boundaries or soil layers is more susceptible to corrosion than the concrete in installations that are entirely within one kind of soil or within one soil layer. The risk of corrosion is expressed as 'low," "moderate," or "high." 17 39° 34' 8" 39° 34' 0" 740880 740920 740960 741p00 Custom Soil Resource Report Map—Corrosion of Concrete 741040 741080 741120 7411160 7411200 74140 108° 11' 29' o - o m co F o co M M V • - V o o cooo - 1. - " .fir L � '� _ � .. v M— . Ioo Jy ._ mM 4 1 t~ 11 �. ! V 0 / —R _� CO. V , , , ���� .' ice` ' 1 I CO d' /: mrn " ,011 09 co t 11.1 Ial t t , • + '-A 1 l 1 r# 1. , £ f2.7 J 1_.A � it, 1 O * �,cc� - ' I ► _ o ro r J 1 s 0. 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 0 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 High n Moderate n Low Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails ,.. Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Corrosion of Concrete Corrosion of Concrete— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Low 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Low 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Corrosion of Concrete Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 20 Custom Soil Resource Report Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Corrosion of Steel "Risk of corrosion" pertains to potential soil -induced electrochemical or chemical action that corrodes or weakens uncoated steel. The rate of corrosion of uncoated steel is related to such factors as soil moisture, particle -size distribution, acidity, and electrical conductivity of the soil. Special site examination and design may be needed if the combination of factors results in a severe hazard of corrosion. The steel in installations that intersect soil boundaries or soil layers is more susceptible to corrosion than the steel in installations that are entirely within one kind of soil or within one soil layer. The risk of corrosion is expressed as "low," "moderate," or "high." 21 108° 11' 46' 39° 34' 8" 740880 740920 740960 741,000 Custom Soil Resource Report Map—Corrosion of Steel 741.040 741080 741.120 7411 60 741.200 741.240 0 t �1 CD M- , N.M CO - 0 OD CO O O N coo OD RJB .M 'Cr00 00 CO CO V o 0 0 copo M O oo 39° 34' 0" i0 0 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 High n Moderate n Low Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails ,.. Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Corrosion of Steel Corrosion of Steel— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Moderate 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Moderate 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Corrosion of Steel Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 24 Custom Soil Resource Report Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Local Roads and Streets Local roads and streets have an all-weather surface and carry automobile and light truck traffic all year. They have a subgrade of cut or fill soil material; a base of gravel, crushed rock, or soil material stabilized by lime or cement; and a surface of flexible material (asphalt), rigid material (concrete), or gravel with a binder. The ratings are based on the soil properties that affect the ease of excavation and grading and the traffic -supporting capacity. The properties that affect the ease of excavation and grading are depth to bedrock or a cemented pan, hardness of bedrock or a cemented pan, depth to a water table, ponding, flooding, the amount of large stones, and slope. The properties that affect the traffic -supporting capacity are soil strength (as inferred from the AASHTO group index number), subsidence, linear extensibility (shrink -swell potential), the potential for frost action, depth to a water table, and ponding. The ratings are both verbal and numerical. Rating class terms indicate the extent to which the soils are limited by all of the soil features that affect the specified use. "Not limited" indicates that the soil has features that are very favorable for the specified use. Good performance and very low maintenance can be expected. "Somewhat limited" indicates that the soil has features that are moderately favorable for the specified use. The limitations can be overcome or minimized by special planning, design, or installation. Fair performance and moderate maintenance can be expected. "Very limited" indicates that the soil has one or more features that are unfavorable for the specified use. The limitations generally cannot be overcome without major soil reclamation, special design, or expensive installation procedures. Poor performance and high maintenance can be expected. Numerical ratings indicate the severity of individual limitations. The ratings are shown as decimal fractions ranging from 0.01 to 1.00. They indicate gradations between the point at which a soil feature has the greatest negative impact on the use (1.00) and the point at which the soil feature is not a limitation (0.00). The map unit components listed for each map unit in the accompanying Summary by Map Unit table in Web Soil Survey or the Aggregation Report in Soil Data Viewer are determined by the aggregation method chosen. An aggregated rating class is shown for each map unit. The components listed for each map unit are only those that have the same rating class as listed for the map unit. The percent composition of each component in a particular map unit is presented to help the user better understand the percentage of each map unit that has the rating presented. Other components with different ratings may be present in each map unit. The ratings for all components, regardless of the map unit aggregated rating, can be viewed by generating the equivalent report from the Soil Reports tab in Web Soil Survey or from the Soil Data Mart site. Onsite investigation may be needed to validate these interpretations and to confirm the identity of the soil on a given site. 25 39° 34' 8" 39° 34' 0" 108° 11' 46' 740680 740920 740960 7411000 Custom Soil Resource Report Map—Local Roads and Streets 7411040 7411080 7411120 741160 74100 74140 N 0 O OD CD M M a V el 0 0 0 M- 0 M oo 0 0 .M M 0 OJ V 9.. o •..r a � '� M_ Mf • � d0. firoi:„. L., (I) ef,,_,.„,_ 4. *4 ,0,1„,, it ..,,, i0 27. 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5” x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 Very limited 0 Somewhat limited 0 Not limited Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails rw,r Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Tables—Local Roads and Streets Local Roads and Streets— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Component name (percent) Rating reasons (numeric values) Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Very limited Parachute (60%) Slope (1.00) 8.8 51.4% Frost action (0.50) Irigul (30%) Depth to hard bedrock (1.00) Slope (1.00) 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Very limited Parachute (35%) Slope (1.00) 8.3 48.6% Frost action (0.50) Irigul (30%) Depth to hard bedrock (1.00) Slope (1.00) Rhone (20%) Slope (1.00) Frost action (0.50) Totals for Area of Interest 17.2 100.0% Local Roads and Streets— Summary by Rating Value Rating Acres in AOI Percent of AOI Very limited 17.2 100.0% Totals for Area of Interest Rating Options—Local Roads and Streets 17.2 Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. 100.0% A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. 28 Custom Soil Resource Report The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff. None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Land Classifications Land Classifications are specified land use and management groupings that are assigned to soil areas because combinations of soil have similar behavior for specified practices. Most are based on soil properties and other factors that directly influence the specific use of the soil. Example classifications include ecological site classification, farmland classification, irrigated and nonirrigated land capability classification, and hydric rating. Ecological Site ID: NRCS Rangeland Site An "ecological site ID" is the symbol assigned to a particular ecological site. An "ecological site" is the product of all the environmental factors responsible for its development. It has characteristic soils that have developed over time; a characteristic hydrology, particularly infiltration and runoff, that has developed over time; and a characteristic plant community (kind and amount of vegetation). The vegetation, soils, and hydrology are all interrelated. Each is influenced by the others and influences the development of the others. For example, the hydrology of the site is influenced by development of the soil and plant community. The plant community on an ecological site is typified by an association of species that differs from that of other ecological sites in the kind and/or proportion of species or in total production. Descriptions of ecological sites are provided in the Field Office Technical Guide, which is available in local offices of the Natural Resources Conservation Service. 29 39° 34' 8" 39° 34' 0" 740880 740920 740960 Custom Soil Resource Report Map—Ecological Site ID: NRCS Rangeland Site 741000 7411040 7411080 741120 74160 74100 74140 0 0 m oo ✓ _ r ♦ _. V O O O O l mM 03 O O CO M V V 00 O j o O O cc,..M COW W CO M R V O o CO CO CO LO ,M co a co V C O C N Ol CO 11 M CO CO O •I — C OJ , r co'''� +. OJ ,—y __ co Ili 0 -' 4441, f 1 _w «1 r • . • y • 47, , i #S ! ; _ -i a cov 4.. ° t n 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 0 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 R048AY228C0 n R048AY238C0 Not rated or not available Political Features 0 Cities Water Features Streams and Canals Transportation +++ Rails /ore Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Ecological Site ID: NRCS Rangeland Site Ecological Site ID: NRCS Rangeland Site— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes R048AY228C0 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes R048AY238C0 8.3 48.6% Totals for Area of Interest 17.2 100.0% Rating Options—Ecological Site ID: NRCS Rangeland Site Class: NRCS Rangeland Site Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be 32 Custom Soil Resource Report considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Lower The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Water Management Water Management interpretations are tools for evaluating the potential of the soil in the application of various water management practices. Example interpretations include pond reservoir area, embankments, dikes, levees, and excavated ponds. Excavated Ponds (Aquifer -Fed) Excavated ponds (aquifer -fed) are pits or dugouts that extend to a ground -water aquifer or to a depth below a permanent water table. Excluded are ponds that are fed only by surface runoff and embankment ponds that impound water 3 feet or more above the original surface. Excavated ponds are affected by depth to a permanent water table, saturated hydraulic conductivity (Ksat) of the aquifer, and quality of the water as inferred from the salinity of the soil. Depth to bedrock and the content of large stones affect the ease of excavation. The ratings are both verbal and numerical. Rating class terms indicate the extent to which the soils are limited by all of the soil features that affect the specified use. "Not limited" indicates that the soil has features that are very favorable for the specified use. Good performance and very low maintenance can be expected. "Somewhat limited" indicates that the soil has features that are moderately favorable for the specified use. The limitations can be overcome or minimized by special planning, design, or installation. Fair performance and moderate maintenance can be expected. "Very limited" indicates that the soil has one or more features that are unfavorable for the specified use. The limitations generally cannot be overcome without major soil reclamation, special design, or expensive installation procedures. Poor performance and high maintenance can be expected. Numerical ratings indicate the severity of individual limitations. The ratings are shown as decimal fractions ranging from 0.01 to 1.00. They indicate gradations between the point at which a soil feature has the greatest negative impact on the use (1.00) and the point at which the soil feature is not a limitation (0.00). The map unit components listed for each map unit in the accompanying Summary by Map Unit table in Web Soil Survey or the Aggregation Report in Soil Data Viewer are determined by the aggregation method chosen. An aggregated rating class is shown for each map unit. The components listed for each map unit are only those that have the same rating class as listed for the map unit. The percent composition of each component in a particular map unit is presented to help the user better understand the percentage of each map unit that has the rating presented. 33 Custom Soil Resource Report Other components with different ratings may be present in each map unit. The ratings for all components, regardless of the map unit aggregated rating, can be viewed by generating the equivalent report from the Soil Reports tab in Web Soil Survey or from the Soil Data Mart site. Onsite investigation may be needed to validate these interpretations and to confirm the identity of the soil on a given site. 34 39° 34' 8" 39° 34' 0" 108° 11' 46' 740680 740920 740960 Custom Soil Resource Report Map—Excavated Ponds (Aquifer -Fed) 7411000 7411040 741,080 7411120 741160 7411200 7411240 N 0 O CO CO co a V 0 0 V co co W W co co 7 — V o 0 o o co co co -co N W M co NI- e o 0 co m co —M c0 0 n) co a V O 0 N M— co V 9 .• F•' # 0. caii:.. (I) ef,2- 4. *4 ,0,1„,, it 2 io a 27. 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 Very limited 0 Somewhat limited 0 Not limited Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails rw,r Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Tables—Excavated Ponds (Aquifer -Fed) Excavated Ponds (Aquifer -Fed)— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Component name (percent) Rating reasons (numeric values) Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Very limited Parachute (60%) Depth to water (1.00) 8.8 51.4% Irigul (30%) Depth to water (1.00) 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Very limited Parachute (35%) Depth to water (1.00) 8.3 48.6% Irigul (30%) Depth to water (1.00) Rhone (20%) Depth to water (1.00) Totals for Area of Interest 17.2 100.0% Excavated Ponds (Aquifer -Fed)— Summary by Rating Value Rating Acres in AOI Percent of AOI Very limited 17.2 100.0% Totals for Area of Interest 17.2 Rating Options—Excavated Ponds (Aquifer -Fed) 100.0% Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more 37 Custom Soil Resource Report than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Pond Reservoir Areas Pond reservoir areas hold water behind a dam or embankment. Soils best suited to this use have low seepage potential in the upper 60 inches. The seepage potential is determined by the saturated hydraulic conductivity (Ksat) of the soil and the depth to fractured bedrock or other permeable material. Excessive slope can affect the storage capacity of the reservoir area. The ratings are both verbal and numerical. Rating class terms indicate the extent to which the soils are limited by all of the soil features that affect the specified use. "Not limited" indicates that the soil has features that are very favorable for the specified use. Good performance and very low maintenance can be expected. "Somewhat limited" indicates that the soil has features that are moderately favorable for the specified use. The limitations can be overcome or minimized by special planning, design, or installation. Fair performance and moderate maintenance can be expected. "Very limited" indicates that the soil has one or more features that are unfavorable for the specified use. The limitations generally cannot be overcome without major soil reclamation, special design, or expensive installation procedures. Poor performance and high maintenance can be expected. Numerical ratings indicate the severity of individual limitations. The ratings are shown as decimal fractions ranging from 0.01 to 1.00. They indicate gradations between the point at which a soil feature has the greatest negative impact on the use (1.00) and the point at which the soil feature is not a limitation (0.00). The map unit components listed for each map unit in the accompanying Summary by Map Unit table in Web Soil Survey or the Aggregation Report in Soil Data Viewer are determined by the aggregation method chosen. An aggregated rating class is shown for each map unit. The components listed for each map unit are only those that have the same rating class as listed for the map unit. The percent composition of each component in a particular map unit is presented to help the user better understand the percentage of each map unit that has the rating presented. 38 Custom Soil Resource Report Other components with different ratings may be present in each map unit. The ratings for all components, regardless of the map unit aggregated rating, can be viewed by generating the equivalent report from the Soil Reports tab in Web Soil Survey or from the Soil Data Mart site. Onsite investigation may be needed to validate these interpretations and to confirm the identity of the soil on a given site. 39 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 7411000 Custom Soil Resource Report Map—Pond Reservoir Areas 7411040 741,080 7411120 741160 7411200 7411240 108° 11' 29" CO CO co a a 0 0 a a co co co ..l• coB W W co N r a o 0 o o co co co -co N0 M co o 0 co m 0) in co co c0 0 0') cn a a O 0 N M 0')) a 9 .• o •' a �'�M_ 2,44 N a0. firoi:„. L., (I) ef,„,- 4. *4 ,0,1„,, it 2 27. 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5” x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 Very limited 0 Somewhat limited 0 Not limited Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails rw,r Interstate Highways US Routes Major Roads Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Tables—Pond Reservoir Areas Pond Reservoir Areas—Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Component name (percent) Rating reasons (numeric values) Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Very limited Parachute (60%) Slope (1.00) 8.8 51 4% Seepage (0.72) Depth to bedrock (0.26) Irigul (30%) Depth to bedrock (1.00) Slope (1.00) 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Very limited Parachute (35%) Slope (1.00) 8.3 48.6% Seepage (0.72) Depth to bedrock (0.26) Irigul (30%) Slope (1.00) Depth to bedrock (1.00) Rhone (20%) Slope (1.00) Seepage (0.72) Depth to bedrock (0.00) Totals for Area of Interest 17.2 100.0% Pond Reservoir Areas— Summary by Rating Value Rating Acres in AOI Percent of AOI Very limited 17.2 100.0% Totals for Area of Interest 17.2 100.0% Rating Options—Pond Reservoir Areas Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. 42 Custom Soil Resource Report For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. 43 Custom Soil Resource Report Soil Properties and Qualities The Soil Properties and Qualities section includes various soil properties and qualities displayed as thematic maps with a summary table for the soil map units in the selected area of interest. A single value or rating for each map unit is generated by aggregating the interpretive ratings of individual map unit components. This aggregation process is defined for each property or quality. Soil Qualities and Features Soil qualities are behavior and performance attributes that are not directly measured, but are inferred from observations of dynamic conditions and from soil properties. Example soil qualities include natural drainage, and frost action. Soil features are attributes that are not directly part of the soil. Example soil features include slope and depth to restrictive layer. These features can greatly impact the use and management of the soil. Depth to a Selected Soil Restrictive Layer: Lithic bedrock A "restrictive layer" is a nearly continuous layer that has one or more physical, chemical, or thermal properties that significantly impede the movement of water and air through the soil or that restrict roots or otherwise provide an unfavorable root environment. Examples are bedrock, cemented layers, dense layers, and frozen layers. This theme presents the depth to the user selected type of restrictive layer as described in for each map unit. If no restrictive layer is described in a map unit, it is represented by the "> 200" depth class. This attribute is actually recorded as three separate values in the database. A low value and a high value indicate the range of this attribute for the soil component. A "representative" value indicates the expected value of this attribute for the component. For this soil property, only the representative value is used. 44 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 Custom Soil Resource Report Map—Depth to a Selected Soil Restrictive Layer: Lithic bedrock 740960 7411000 7411040 741080 741120 co o.viiikr. 7411160 7411200 7411240 108° 11' 29' 0 0 v v co 0 cs- co W W co co 7 4- 0 0 0 0 o 0 co co co W m co v 4- 0 0 00 0 CO <D in CO CO CO CO CO CO CO d V o o N N eco 0) m m co V 4. co co CO co W ./ r co co 7 ico oe m 4 0) i0 27. 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 0-25 0 25-50 0 50 - 100 0 100 - 150 0 150 - 200 0 > 200 Political Features p Cities Water Features Streams and Canals Transportation +++ Rails ,.. Interstate Highways US Routes Major Roads sv Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Depth to a Selected Soil Restrictive Layer: Lithic bedrock Depth to a Selected Soil Restrictive Layer: Lithic bedrock— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating (centimeters) Acres in AOI Percent of AO1 55 Parachute-Irigul complex, 5 to 30 percent slopes >200 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes >200 8.3 48.6% Totals for Area of Interest 17.2 100.0% Rating Options—Depth to a Selected Soil Restrictive Layer: Lithic bedrock Units of Measure: centimeters Restriction Kind: Lithic bedrock Aggregation Method: Dominant Component Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Component" returns the attribute value associated with the component with the highest percent composition in the map unit. If more than one component shares the highest percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie- break" rule indicates whether the lower or higher attribute value should be returned in the case of a percent composition tie. The result returned by this aggregation method may or may not represent the dominant condition throughout the map unit. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be 47 Custom Soil Resource Report considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Lower The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Interpret Nulls as Zero: No This option indicates if a null value for a component should be converted to zero before aggregation occurs. This will be done only if a map unit has at least one component where this value is not null. Drainage Class "Drainage class (natural)" refers to the frequency and duration of wet periods under conditions similar to those under which the soil formed. Alterations of the water regime by human activities, either through drainage or irrigation, are not a consideration unless they have significantly changed the morphology of the soil. Seven classes of natural soil drainage are recognized -excessively drained, somewhat excessively drained, well drained, moderately well drained, somewhat poorly drained, poorly drained, and very poorly drained. These classes are defined in the "Soil Survey Manual." 48 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 7411000 Custom Soil Resource Report Map—Drainage Class 741040 741080 741120 7411160 7411200 7411240 108° 11' 29' co o co , M Co o co -a �1 t. . V o W i o ! 0 MM a i` e 0t' ro r t, d f • • .• ik 0 • 0. 0fff 1 v �co • p 1 O N V O CO 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 Excessively drained 0 Somewhat excessively drained 0 Well drained 0 Moderately well drained 0 Somewhat poorly drained 0 Poorly drained 0 Very poorly drained Subaqueous Not rated or not available Political Features • Cities Water Features Streams and Canals Transportation +++ Rails ,.. ▪ Interstate Highways US Routes Major Roads ▪ Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Drainage Class Drainage Class— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes Well drained 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes Well drained 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Drainage Class Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 51 Custom Soil Resource Report Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Hydrologic Soil Group Hydrologic soil groups are based on estimates of runoff potential. Soils are assigned to one of four groups according to the rate of water infiltration when the soils are not protected by vegetation, are thoroughly wet, and receive precipitation from long - duration storms. The soils in the United States are assigned to four groups (A, B, C, and D) and three dual classes (ND, B/D, and C/D). The groups are defined as follows: Group A. Soils having a high infiltration rate (low runoff potential) when thoroughly wet. These consist mainly of deep, well drained to excessively drained sands or gravelly sands. These soils have a high rate of water transmission. Group B. Soils having a moderate infiltration rate when thoroughly wet. These consist chiefly of moderately deep or deep, moderately well drained or well drained soils that have moderately fine texture to moderately coarse texture. These soils have a moderate rate of water transmission. Group C. Soils having a slow infiltration rate when thoroughly wet. These consist chiefly of soils having a layer that impedes the downward movement of water or soils of moderately fine texture or fine texture. These soils have a slow rate of water transmission. Group D. Soils having a very slow infiltration rate (high runoff potential) when thoroughly wet. These consist chiefly of clays that have a high shrink -swell potential, soils that have a high water table, soils that have a claypan or clay layer at or near the surface, and soils that are shallow over nearly impervious material. These soils have a very slow rate of water transmission. If a soil is assigned to a dual hydrologic group (ND, B/D, or C/D), the first letter is for drained areas and the second is for undrained areas. Only the soils that in their natural condition are in group D are assigned to dual classes. 52 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 7411000 Custom Soil Resource Report Map—Hydrologic Soil Group 7411040 741080 741120 7411160 7411200 74140 108° 11' 29" o a a co co co W W m M 7 V o 0 o o co co M� nth o 00 0 N) a o (oo m co h� co o 0 0 M a V O 0 lf,N N M� W V o . ); N O . t I 0 P. gj e „,_0. 4. .: de, Jo -1- ,, ' Y- '4. ' 'i co ,, ,, , ..., , • ,mc,_ ... 27. 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5” x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 A 0 ND 0 0 B/D 0 C/D 0 Not rated or not available Political Features p Cities Water Features Streams and Canals The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Transportation Garfield and Mesa Counties +++ Rails Survey Area Data: Version 5, Feb 1, 2008 /ore Interstate Highways US Routes Major Roads f Local Roads Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Hydrologic Soil Group Hydrologic Soil Group— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes B 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes B 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Hydrologic Soil Group Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 55 Custom Soil Resource Report Tie-break Rule: Higher The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Representative Slope Slope gradient is the difference in elevation between two points, expressed as a percentage of the distance between those points. The slope gradient is actually recorded as three separate values in the database. A low value and a high value indicate the range of this attribute for the soil component. A "representative" value indicates the expected value of this attribute for the component. For this soil property, only the representative value is used. 56 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 7411000 Custom Soil Resource Report Map—Representative Slope 7411040 741,080 7411120 741;60 7411200 7411240 108° 11' 29' co co M� Z co M co O co V O O cv N Lo M� { �M oo .o- V 0 0 •g- c co co W W co co R -o O 1 11 w • co oo NI-�".. 4 - v S., ,o- 0 0 740880 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND Area of Interest (AOI) Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 0-5 0 5-15 0 15-30 0 30 - 45 LI 45 - 60 Not rated or not available Political Features p Cities Water Features Streams and Canals Transportation +++ Rails rw,r Interstate Highways US Routes Major Roads . Local Roads MAP INFORMATION Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Representative Slope Representative Slope— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating (percent) Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes 18.0 8.8 51.4% 56 Parachute-lrigul-Rhone association, 25 to 50 percent slopes 38.0 8.3 48.6% Totals for Area of Interest 17.2 100.0% Rating Options—Representative Slope Units of Measure: percent Aggregation Method: Dominant Component Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Component" returns the attribute value associated with the component with the highest percent composition in the map unit. If more than one component shares the highest percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie- break" rule indicates whether the lower or higher attribute value should be returned in the case of a percent composition tie. The result returned by this aggregation method may or may not represent the dominant condition throughout the map unit. Component Percent Cutoff. None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Higher 59 Custom Soil Resource Report The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Interpret Nulls as Zero: No This option indicates if a null value for a component should be converted to zero before aggregation occurs. This will be done only if a map unit has at least one component where this value is not null. Unified Soil Classification (Surface) The Unified soil classification system classifies mineral and organic mineral soils for engineering purposes on the basis of particle -size characteristics, liquid limit, and plasticity index. It identifies three major soil divisions: (i) coarse-grained soils having less than 50 percent, by weight, particles smaller than 0.074 mm in diameter; (ii) fine- grained soils having 50 percent or more, by weight, particles smaller than 0.074 mm in diameter; and (iii) highly organic soils that demonstrate certain organic characteristics. These divisions are further subdivided into a total of 15 basic soil groups. The major soil divisions and basic soil groups are determined on the basis of estimated or measured values for grain -size distribution and Atterberg limits. ASTM D 2487 shows the criteria chart used for classifying soil in the Unified system and the 15 basic soil groups of the system and the plasticity chart for the Unified system. The various groupings of this classification correlate in a general way with the engineering behavior of soils. This correlation provides a useful first step in any field or laboratory investigation for engineering purposes. It can serve to make some general interpretations relating to probable performance of the soil for engineering uses. For each soil horizon in the database one or more Unified soil classifications may be listed. One is marked as the representative or most commonly occurring. The representative classification is shown here for the surface layer of the soil. 60 39° 34' 8" 39° 34' 0" 740880 740920 740960 Custom Soil Resource Report Map—Unified Soil Classification (Surface) 7411000 7411040 7411080 7411120 74160 74100 74140 o O m m 0 4 0 CO 00 y • C'R �M V ♦ _. V O O M M MmM co W co co V V O O O O M M MmM co W M M R V O N MCO� , 1 a ,.. _ of co— co' • a c0_t • �t M y . 4 Y� * _ 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 Co 0 39° 34' 8" 39° 33' 59" Custom Soil Resource Report Area of Interest (AOI) Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 CH 0 CL 0 CL -A (proposed) 0 CL -K (proposed) 0 CL -ML 0 CL -O (proposed) 0 CL -T (proposed) 0 GC 0 GC -GM 0 GM 0 GP 0 GP -GC 0 GP -GM 0 GW 0 GW -GC 0 GW -GM 0 MH 0 MH -A (proposed) 0 MH -K (proposed) 0 MH -O (proposed) 0 MH -T (proposed) MAP LEGEND 0 ML 0 ML -A (proposed) 0 ML -K (proposed) 0 ML -O (proposed) 0 ML -T (proposed) 0 OH 0 OH -T (proposed) 0 OL 0 PT 0 SC 0 SC -SM 0 SM 0 SP 0 SP -SC 0 SP -SM U SW sw-sc SW -SM Not rated or not available Political Features Cities Water Features Streams and Canals Transportation +++ Rails /w,r Interstate Highways US Routes Major Roads Jy Local Roads MAP INFORMATION Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Unified Soil Classification (Surface) Unified Soil Classification (Surface)— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes CL 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes CL 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Unified Soil Classification (Surface) Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 63 Custom Soil Resource Report Tie-break Rule: Lower The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Layer Options: Surface Layer Foran attribute of a soil horizon, a depth qualification must be specified. In most cases it is probably most appropriate to specify a fixed depth range, either in centimeters or inches. The Bottom Depth must be greater than the Top Depth, and the Top Depth can be greater than zero. The choice of "inches" or "centimeters" only applies to the depth of soil to be evaluated. It has no influence on the units of measure the data are presented in. When "Surface Layer" is specified as the depth qualifier, only the surface layer or horizon is considered when deriving a value for a component, but keep in mind that the thickness of the surface layer varies from component to component. When "All Layers" is specified as the depth qualifier, all layers recorded for a component are considered when deriving the value for that component. Whenever more than one layer or horizon is considered when deriving a value for a component, and the attribute being aggregated is a numeric attribute, a weighted average value is returned, where the weighting factor is the layer or horizon thickness. Water Features Water Features include ponding frequency, flooding frequency, and depth to water table. Depth to Water Table "Water table" refers to a saturated zone in the soil. It occurs during specified months. Estimates of the upper limit are based mainly on observations of the water table at selected sites and on evidence of a saturated zone, namely grayish colors (redoximorphic features) in the soil. A saturated zone that lasts for less than a month is not considered a water table. This attribute is actually recorded as three separate values in the database. A low value and a high value indicate the range of this attribute for the soil component. A "representative" value indicates the expected value of this attribute for the component. For this soil property, only the representative value is used. 64 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 7411000 Custom Soil Resource Report Map—Depth to Water Table 741040 741080 741120 7411160 7411200 7411240 108° 11' 29' oo co co co a r � 0 0 v v co 0 c.0 co W W co co 7 4- 0 0 0 0 o 0 co co co W m co v 4- 0 0 00 0 CO CO in CO CO CO CO OJ CO M d V o o N N eco 0) m m co V 4. co co CO co 0 ▪ ./ r co co 7 ico re •J .11'4 -56 f ell o v 0. a ��,, ,,, - +€ v ti i0 0 74088 0 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 0-25 0 25-50 0 50 - 100 0 100 - 150 0 150 - 200 0 > 200 Political Features p Cities Water Features Streams and Canals Transportation +++ Rails ,.. Interstate Highways US Routes Major Roads sv Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Depth to Water Table Depth to Water Table— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (CO682) Map unit symbol Map unit name Rating (centimeters) Acres in AOI Percent of AO1 55 Parachute-Irigul complex, 5 to 30 percent slopes >200 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes >200 8.3 17.2 48.6% Totals for Area of Interest 100.0% 67 Custom Soil Resource Report Rating Options—Depth to Water Table Units of Measure: centimeters Aggregation Method: Dominant Component Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Component" returns the attribute value associated with the component with the highest percent composition in the map unit. If more than one component shares the highest percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie- break" rule indicates whether the lower or higher attribute value should be returned in the case of a percent composition tie. The result returned by this aggregation method may or may not represent the dominant condition throughout the map unit. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. Tie-break Rule: Lower The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Interpret Nulls as Zero: No This option indicates if a null value for a component should be converted to zero before aggregation occurs. This will be done only if a map unit has at least one component where this value is not null. Beginning Month: January Ending Month: December 68 Custom Soil Resource Report Flooding Frequency Class Flooding is the temporary inundation of an area caused by overflowing streams, by runoff from adjacent slopes, or by tides. Water standing for short periods after rainfall or snowmelt is not considered flooding, and water standing in swamps and marshes is considered ponding rather than flooding. Frequency is expressed as none, very rare, rare, occasional, frequent, and very frequent. "None" means that flooding is not probable. The chance of flooding is nearly 0 percent in any year. Flooding occurs less than once in 500 years. "Very rare" means that flooding is very unlikely but possible under extremely unusual weather conditions. The chance of flooding is less than 1 percent in any year. "Rare" means that flooding is unlikely but possible under unusual weather conditions. The chance of flooding is 1 to 5 percent in any year. "Occasional" means that flooding occurs infrequently under normal weather conditions. The chance of flooding is 5 to 50 percent in any year. "Frequent" means that flooding is likely to occur often under normal weather conditions. The chance of flooding is more than 50 percent in any year but is less than 50 percent in all months in any year. "Very frequent" means that flooding is likely to occur very often under normal weather conditions. The chance of flooding is more than 50 percent in all months of any year. 69 39° 34' 8" 39° 34' 0" 108° 11' 46' 740880 740920 740960 Custom Soil Resource Report Map—Flooding Frequency Class 741000 741040 741080 741120 7411 60 74100 74140 00 CO CO le j - ;2111111111 oo co CO M a V el 00 0 0 o o co (D Mm ..co, CO CO CO M a e o 0 CO (0 1 in (ham ,M CO CO CO M a V O 0 CV (O co V co co io a 0 0 740880 740920 740960 Map Scale: 1:1,940 if printed on Asize (8.5" x 11") sheet. 741000 0 25 50 100 741040 Meters 150 0 100 200 400 741080 Feet 600 741120 741160 741200 741240 C 39° 34' 8" 39° 33' 59" Custom Soil Resource Report MAP LEGEND MAP INFORMATION Area of Interest (AOI) Map Scale: 1:1,940 if printed on A size (8.5" x 11") sheet. Area of Interest (AOI) Soils Soil Map Units Soil Ratings 0 None 0 Very Rare 0 Rare 0 Occasional 0 Frequent 0 Very Frequent Political Features O Cities Water Features Streams and Canals Transportation +++ Rails ,.. Interstate Highways US Routes Major Roads sv Local Roads The soil surveys that comprise your AOI were mapped at 1:24,000. Warning: Soil Map may not be valid at this scale. Enlargement of maps beyond the scale of mapping can cause misunderstanding of the detail of mapping and accuracy of soil line placement. The maps do not show the small areas of contrasting soils that could have been shown at a more detailed scale. Please rely on the bar scale on each map sheet for accurate map measurements. Source of Map: Natural Resources Conservation Service Web Soil Survey URL: http://websoilsurvey.nrcs.usda.gov Coordinate System: UTM Zone 12N NAD83 This product is generated from the USDA-NRCS certified data as of the version date(s) listed below. Soil Survey Area: Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Survey Area Data: Version 5, Feb 1, 2008 Date(s) aerial images were photographed: 8/29/2005; 6/30/2005 The orthophoto or other base map on which the soil lines were compiled and digitized probably differs from the background imagery displayed on these maps. As a result, some minor shifting of map unit boundaries may be evident. Custom Soil Resource Report Table—Flooding Frequency Class Flooding Frequency Class— Summary by Map Unit — Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties (C0682) Map unit symbol Map unit name Rating Acres in AOI Percent of AOI 55 Parachute-Irigul complex, 5 to 30 percent slopes None 8.8 51.4% 56 Parachute-Irigul-Rhone association, 25 to 50 percent slopes None 8.3 17.2 48.6% Totals for Area of Interest 100.0% Rating Options—Flooding Frequency Class Aggregation Method: Dominant Condition Aggregation is the process by which a set of component attribute values is reduced to a single value that represents the map unit as a whole. A map unit is typically composed of one or more "components". A component is either some type of soil or some nonsoil entity, e.g., rock outcrop. For the attribute being aggregated, the first step of the aggregation process is to derive one attribute value for each of a map unit's components. From this set of component attributes, the next step of the aggregation process derives a single value that represents the map unit as a whole. Once a single value for each map unit is derived, a thematic map for soil map units can be rendered. Aggregation must be done because, on any soil map, map units are delineated but components are not. For each of a map unit's components, a corresponding percent composition is recorded. A percent composition of 60 indicates that the corresponding component typically makes up approximately 60% of the map unit. Percent composition is a critical factor in some, but not all, aggregation methods. The aggregation method "Dominant Condition" first groups like attribute values for the components in a map unit. For each group, percent composition is set to the sum of the percent composition of all components participating in that group. These groups now represent "conditions" rather than components. The attribute value associated with the group with the highest cumulative percent composition is returned. If more than one group shares the highest cumulative percent composition, the corresponding "tie-break" rule determines which value should be returned. The "tie-break" rule indicates whether the lower or higher group value should be returned in the case of a percent composition tie. The result returned by this aggregation method represents the dominant condition throughout the map unit only when no tie has occurred. Component Percent Cutoff: None Specified Components whose percent composition is below the cutoff value will not be considered. If no cutoff value is specified, all components in the database will be considered. The data for some contrasting soils of minor extent may not be in the database, and therefore are not considered. 72 Custom Soil Resource Report Tie-break Rule: More Frequent The tie-break rule indicates which value should be selected from a set of multiple candidate values, or which value should be selected in the event of a percent composition tie. Beginning Month: January Ending Month: December 73 Custom Soil Resource Report Soil Reports The Soil Reports section includes various formatted tabular and narrative reports (tables) containing data for each selected soil map unit and each component of each unit. No aggregation of data has occurred as is done in reports in the Soil Properties and Qualities and Suitabilities and Limitations sections. The reports contain soil interpretive information as well as basic soil properties and qualities. A description of each report (table) is included. Building Site Development This folder contains a collection of tabular reports that present soil interpretations related to building site development. The reports (tables) include all selected map units and components for each map unit, limiting features and interpretive ratings. Building site development interpretations are designed to be used as tools for evaluating soil suitability and identifying soil limitations for various construction purposes. As part of the interpretation process, the rating applies to each soil in its described condition and does not consider present land use. Example interpretations can include corrosion of concrete and steel, shallow excavations, dwellings with and without basements, small commercial buildings, local roads and streets, and lawns and landscaping. Roads and Streets, Shallow Excavations, and Lawns and Landscaping Soil properties influence the development of building sites, including the selection of the site, the design of the structure, construction, performance after construction, and maintenance. This table shows the degree and kind of soil limitations that affect local roads and streets, shallow excavations, and lawns and landscaping. The ratings in the table are both verbal and numerical. Rating class terms indicate the extent to which the soils are limited by all of the soil features that affect building site development. Not limited indicates that the soil has features that are very favorable for the specified use. Good performance and very low maintenance can be expected. Somewhat limited indicates that the soil has features that are moderately favorable for the specified use. The limitations can be overcome or minimized by special planning, design, or installation. Fair performance and moderate maintenance can be expected. Very limited indicates that the soil has one or more features that are unfavorable for the specified use. The limitations generally cannot be overcome without major soil reclamation, special design, or expensive installation procedures. Poor performance and high maintenance can be expected. Numerical ratings in the table indicate the severity of individual limitations. The ratings are shown as decimal fractions ranging from 0.01 to 1.00. They indicate gradations between the point at which a soil feature has the greatest negative impact on the use (1.00) and the point at which the soil feature is not a limitation (0.00). Local roads and streets have an all-weather surface and carry automobile and light truck traffic all year. They have a subgrade of cut or fill soil material; a base of gravel, 74 Custom Soil Resource Report crushed rock, or soil material stabilized by lime or cement; and a surface of flexible material (asphalt), rigid material (concrete), or gravel with a binder. The ratings are based on the soil properties that affect the ease of excavation and grading and the traffic -supporting capacity. The properties that affect the ease of excavation and grading are depth to bedrock or a cemented pan, hardness of bedrock or a cemented pan, depth to a water table, ponding, flooding, the amount of large stones, and slope. The properties that affect the traffic -supporting capacity are soil strength (as inferred from the AASHTO group index number), subsidence, linear extensibility (shrink -swell potential), the potential for frost action, depth to a water table, and ponding. Shallow excavations are trenches or holes dug to a maximum depth of 5 or 6 feet for graves, utility lines, open ditches, or other purposes. The ratings are based on the soil properties that influence the ease of digging and the resistance to sloughing. Depth to bedrock or a cemented pan, hardness of bedrock or a cemented pan, the amount of large stones, and dense layers influence the ease of digging, filling, and compacting. Depth to the seasonal high water table, flooding, and ponding may restrict the period when excavations can be made. Slope influences the ease of using machinery. Soil texture, depth to the water table, and linear extensibility (shrink -swell potential) influence the resistance to sloughing. Lawns and landscaping require soils on which turf and ornamental trees and shrubs can be established and maintained. Irrigation is not considered in the ratings. The ratings are based on the soil properties that affect plant growth and trafficability after vegetation is established. The properties that affect plant growth are reaction; depth to a water table; ponding; depth to bedrock or a cemented pan; the available water capacity in the upper 40 inches; the content of salts, sodium, or calcium carbonate; and sulfidic materials. The properties that affect trafficability are flooding, depth to a water table, ponding, slope, stoniness, and the amount of sand, clay, or organic matter in the surface layer. Information in this table is intended for land use planning, for evaluating land use alternatives, and for planning site investigations prior to design and construction. The information, however, has limitations. For example, estimates and other data generally apply only to that part of the soil between the surface and a depth of 5 to 7 feet. Because of the map scale, small areas of different soils may be included within the mapped areas of a specific soil. The information is not site specific and does not eliminate the need for onsite investigation of the soils or for testing and analysis by personnel experienced in the design and construction of engineering works. Government ordinances and regulations that restrict certain land uses or impose specific design criteria were not considered in preparing the information in this table. Local ordinances and regulations should be considered in planning, in site selection, and in design. Report—Roads and Streets, Shallow Excavations, and Lawns and Landscaping [Onsite investigation may be needed to validate the interpretations in this table and to confirm the identity of the soil on a given site. The numbers in the value columns range from 0.01 to 1.00. The larger the value, the greater the potential limitation. The table shows only the top five limitations for any given soil. The soil may have additional limitations] 75 Custom Soil Resource Report Roads and Streets, Shallow Excavations, and Lawns and Landscaping- Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Pct. of map unit Local roads and streets Shallow excavations Lawns and landscaping Rating class and limiting features Value Rating class and limiting features Value Rating class and limiting features Value 55-Parachute-Irigul complex, 5 to 30 percent slopes Parachute 60 Very limited Very limited Very limited Slope 1.00 Slope 1.00 Slope 1.00 Frost action 0.50 Depth to soft bedrock 0.84 Depth to bedrock 0.84 Cutbanks cave 0.10 Droughty 0.65 Irigul 30 Very limited Very limited Very limited Depth to hard bedrock 1.00 Depth to hard bedrock 1.00 Droughty 1.00 Slope 1.00 Slope 1.00 Depth to bedrock 1.00 Slope 1.00 Gravel content 0.05 56-Parachute-Irigul- Rhone association, 25 to 50 percent slopes Parachute 35 Very limited Very limited Very limited Slope 1.00 Slope 1.00 Slope 1.00 Frost action 0.50 Depth to soft bedrock 0.84 Depth to bedrock 0.84 Cutbanks cave 0.10 Droughty 0.65 Irigul 30 Very limited Very limited Very limited Depth to hard bedrock 1.00 Depth to hard bedrock 1.00 Slope 1.00 Slope 1.00 Slope 1.00 Droughty 1.00 Depth to bedrock 1.00 Gravel content 0.05 Rhone 20 Very limited Very limited Very limited Slope 1.00 Slope 1.00 Slope 1.00 Frost action 0.50 Cutbanks cave 0.10 Land Classifications This folder contains a collection of tabular reports that present a variety of soil groupings. The reports (tables) include all selected map units and components for each map unit. Land classifications are specified land use and management groupings that are assigned to soil areas because combinations of soil have similar behavior for specified practices. Most are based on soil properties and other factors that directly influence the specific use of the soil. Example classifications include ecological site classification, farmland classification, irrigated and nonirrigated land capability classification, and hydric rating. 76 Custom Soil Resource Report Taxonomic Classification of the Soils The system of soil classification used by the National Cooperative Soil Survey has six categories (Soil Survey Staff, 1999 and 2003). Beginning with the broadest, these categories are the order, suborder, great group, subgroup, family, and series. Classification is based on soil properties observed in the field or inferred from those observations or from laboratory measurements. This table shows the classification of the soils in the survey area. The categories are defined in the following paragraphs. ORDER. Twelve soil orders are recognized. The differences among orders reflect the dominant soil -forming processes and the degree of soil formation. Each order is identified by a word ending in sol. An example is Alfisols. SUBORDER. Each order is divided into suborders primarily on the basis of properties that influence soil genesis and are important to plant growth or properties that reflect the most important variables within the orders. The last syllable in the name of a suborder indicates the order. An example is Udalfs (Ud, meaning humid, plus alfs, from Alfisols). GREAT GROUP. Each suborder is divided into great groups on the basis of close similarities in kind, arrangement, and degree of development of pedogenic horizons; soil moisture and temperature regimes; type of saturation; and base status. Each great group is identified by the name of a suborder and by a prefix that indicates a property of the soil. An example is Hapludalfs (Hapl, meaning minimal horizonation, plus udalfs, the suborder of the Alfisols that has a udic moisture regime). SUBGROUP. Each great group has a typic subgroup. Other subgroups are intergrades or extragrades. The typic subgroup is the central concept of the great group; it is not necessarily the most extensive. Intergrades are transitions to other orders, suborders, or great groups. Extragrades have some properties that are not representative of the great group but do not indicate transitions to any other taxonomic class. Each subgroup is identified by one or more adjectives preceding the name of the great group. The adjective Typic identifies the subgroup that typifies the great group. An example is Typic Hapludalfs. FAMILY. Families are established within a subgroup on the basis of physical and chemical properties and other characteristics that affect management. Generally, the properties are those of horizons below plow depth where there is much biological activity. Among the properties and characteristics considered are particle -size class, mineralogy class, cation -exchange activity class, soil temperature regime, soil depth, and reaction class. A family name consists of the name of a subgroup preceded by terms that indicate soil properties. An example is fine -loamy, mixed, active, mesic Typic Hapludalfs. SERIES. The series consists of soils within a family that have horizons similar in color, texture, structure, reaction, consistence, mineral and chemical composition, and arrangement in the profile. References: Soil Survey Staff. 1999. Soil taxonomy: A basic system of soil classification for making and interpreting soil surveys. 2nd edition. Natural Resources Conservation Service. U.S. Department of Agriculture Handbook 436. Soil Survey Staff. 2006. Keys to soil taxonomy. 10th edition. U.S. Department of Agriculture, Natural Resources Conservation Service. (The soils in a given survey area may have been classified according to earlier editions of this publication.) 77 Custom Soil Resource Report Report—Taxonomic Classification of the Soils [An asterisk by the soil name indicates a taxadjunct to the series] Taxonomic Classification of the Soils— Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Soil name Family or higher taxonomic classification Irigul Parachute Loamy -skeletal, mixed Lithic Cryoborolls Loamy -skeletal, mixed Typic Cryoborolls Rhone Fine -loamy, mixed Pachic Cryoborolls Soil Chemical Properties This folder contains a collection of tabular reports that present soil chemical properties. The reports (tables) include all selected map units and components for each map unit. Soil chemical properties are measured or inferred from direct observations in the field or laboratory. Examples of soil chemical properties include pH, cation exchange capacity, calcium carbonate, gypsum, and electrical conductivity. Chemical Soil Properties This table shows estimates of some chemical characteristics and features that affect soil behavior. These estimates are given for the layers of each soil in the survey area. The estimates are based on field observations and on test data for these and similar soils. Depth to the upper and lower boundaries of each layer is indicated. Cation -exchange capacity is the total amount of extractable cations that can be held by the soil, expressed in terms of milliequivalents per 100 grams of soil at neutrality (pH 7.0) or at some other stated pH value. Soils having a low cation -exchange capacity hold fewer cations and may require more frequent applications of fertilizer than soils having a high cation -exchange capacity. The ability to retain cations reduces the hazard of ground -water pollution. Effective cation -exchange capacity refers to the sum of extractable cations plus aluminum expressed in terms of milliequivalents per 100 grams of soil. It is determined for soils that have pH of less than 5.5. Soil reaction is a measure of acidity or alkalinity. It is important in selecting crops and other plants, in evaluating soil amendments for fertility and stabilization, and in determining the risk of corrosion. Calcium carbonate equivalent is the percent of carbonates, by weight, in the fraction of the soil less than 2 millimeters in size. The availability of plant nutrients is influenced by the amount of carbonates in the soil. Gypsum is expressed as a percent, by weight, of hydrated calcium sulfates in the fraction of the soil less than 20 millimeters in size. Gypsum is partially soluble in water. Soils that have a high content of gypsum may collapse if the gypsum is removed by percolating water. 78 Custom Soil Resource Report Salinity is a measure of soluble salts in the soil at saturation. It is expressed as the electrical conductivity of the saturation extract, in millimhos per centimeter at 25 degrees C. Estimates are based on field and laboratory measurements at representative sites of nonirrigated soils. The salinity of irrigated soils is affected by the quality of the irrigation water and by the frequency of water application. Hence, the salinity of soils in individual fields can differ greatly from the value given in the table. Salinity affects the suitability of a soil for crop production, the stability of soil if used as construction material, and the potential of the soil to corrode metal and concrete. Sodium adsorption ratio (SAR) is a measure of the amount of sodium (Na) relative to calcium (Ca) and magnesium (Mg) in the water extract from saturated soil paste. It is the ratio of the Na concentration divided by the square root of one-half of the Ca + Mg concentration. Soils that have SAR values of 13 or more may be characterized by an increased dispersion of organic matter and clay particles, reduced saturated hydraulic conductivity and aeration, and a general degradation of soil structure. 79 Custom Soil Resource Report Chemical Soil Properties– Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Depth Cation- exchange capacity Effective cation- exchange capacity Soil reaction Calcium carbonate Gypsum Salinity Sodium adsorption ratio In meq/100g meq/100g pH Pct Pct mmhos/cm 55—Parachute-Irigul complex, 5 to 30 percent slopes Parachute 0-10 10-25 — 6.6-7.3 0 0 0 0 10-25 10-20 — 6.6-7.3 0 0 0 0 25-29 — — — — — — — Irigul 0-6 10-20 — 6.6-7.8 0 0 0 0 6-13 5.0-15 — 6.6-7.8 0 0 0 0 13-17 — — — — — — — 56—Parachute-Irigu I -Rhone association, 25 to 50 percent slopes Parachute 0-10 10-25 — 6.6-7.3 0 0 0 0 10-25 10-20 — 6.6-7.3 0 0 0 0 25-29 — — — — — — — Irigul 0-6 10-20 — 6.6-7.8 0 0 0 6-13 5.0-15 — 6.6-7.8 0 0 0 13-17 — — — — — — il Rhone 0-10 15-30 — 6.6-7.3 0 0 0 0 10-39 10-20 — 6.6-7.3 0 0 0 0 39-55 10-20 — 6.6-7.3 0 0 0 0 55-59 — — — — — — — 80 Custom Soil Resource Report Soil Physical Properties This folder contains a collection of tabular reports that present soil physical properties. The reports (tables) include all selected map units and components for each map unit. Soil physical properties are measured or inferred from direct observations in the field or laboratory. Examples of soil physical properties include percent clay, organic matter, saturated hydraulic conductivity, available water capacity, and bulk density. Physical Soil Properties This table shows estimates of some physical characteristics and features that affect soil behavior. These estimates are given for the layers of each soil in the survey area. The estimates are based on field observations and on test data for these and similar soils. Depth to the upper and lower boundaries of each layer is indicated. Particle size is the effective diameter of a soil particle as measured by sedimentation, sieving, or micrometric methods. Particle sizes are expressed as classes with specific effective diameter class limits. The broad classes are sand, silt, and clay, ranging from the larger to the smaller. Sand as a soil separate consists of mineral soil particles that are 0.05 millimeter to 2 millimeters in diameter. In this table, the estimated sand content of each soil layer is given as a percentage, by weight, of the soil material that is less than 2 millimeters in diameter. Silt as a soil separate consists of mineral soil particles that are 0.002 to 0.05 millimeter in diameter. In this table, the estimated silt content of each soil layer is given as a percentage, by weight, of the soil material that is less than 2 millimeters in diameter. Clay as a soil separate consists of mineral soil particles that are less than 0.002 millimeter in diameter. In this table, the estimated clay content of each soil layer is given as a percentage, by weight, of the soil material that is less than 2 millimeters in diameter. The content of sand, silt, and clay affects the physical behavior of a soil. Particle size is important for engineering and agronomic interpretations, for determination of soil hydrologic qualities, and for soil classification. The amount and kind of clay affect the fertility and physical condition of the soil and the ability of the soil to adsorb cations and to retain moisture. They influence shrink - swell potential, saturated hydraulic conductivity (Ksat), plasticity, the ease of soil dispersion, and other soil properties. The amount and kind of clay in a soil also affect tillage and earthmoving operations. Moist bulk density is the weight of soil (ovendry) per unit volume. Volume is measured when the soil is at field moisture capacity, that is, the moisture content at 1/3- or 1/10 - bar (33kPa or 10kPa) moisture tension. Weight is determined after the soil is dried at 105 degrees C. In the table, the estimated moist bulk density of each soil horizon is expressed in grams per cubic centimeter of soil material that is less than 2 millimeters in diameter. Bulk density data are used to compute linear extensibility, shrink -swell potential, available water capacity, total pore space, and other soil properties. The moist bulk density of a soil indicates the pore space available for water and roots. 81 Custom Soil Resource Report Depending on soil texture, a bulk density of more than 1.4 can restrict water storage and root penetration. Moist bulk density is influenced by texture, kind of clay, content of organic matter, and soil structure. Saturated hydraulic conductivity (Ksat) refers to the ease with which pores in a saturated soil transmit water. The estimates in the table are expressed in terms of micrometers per second. They are based on soil characteristics observed in the field, particularly structure, porosity, and texture. Saturated hydraulic conductivity (Ksat) is considered in the design of soil drainage systems and septic tank absorption fields. Available water capacity refers to the quantity of water that the soil is capable of storing for use by plants. The capacity for water storage is given in inches of water per inch of soil for each soil layer. The capacity varies, depending on soil properties that affect retention of water. The most important properties are the content of organic matter, soil texture, bulk density, and soil structure. Available water capacity is an important factor in the choice of plants or crops to be grown and in the design and management of irrigation systems. Available water capacity is not an estimate of the quantity of water actually available to plants at any given time. Linear extensibility refers to the change in length of an unconfined clod as moisture content is decreased from a moist to a dry state. It is an expression of the volume change between the water content of the clod at 1/3- or 1/10 -bar tension (33kPa or 10kPa tension) and oven dryness. The volume change is reported in the table as percent change for the whole soil. The amount and type of clay minerals in the soil influence volume change. Linear extensibility is used to determine the shrink -swell potential of soils. The shrink - swell potential is low if the soil has a linear extensibility of less than 3 percent; moderate if 3 to 6 percent; high if 6 to 9 percent; and very high if more than 9 percent. If the linear extensibility is more than 3, shrinking and swelling can cause damage to buildings, roads, and other structures and to plant roots. Special design commonly is needed. Organic matter is the plant and animal residue in the soil at various stages of decomposition. In this table, the estimated content of organic matter is expressed as a percentage, by weight, of the soil material that is less than 2 millimeters in diameter. The content of organic matter in a soil can be maintained by returning crop residue to the soil. Organic matter has a positive effect on available water capacity, water infiltration, soil organism activity, and tilth. It is a source of nitrogen and other nutrients for crops and soil organisms. Erosion factors are shown in the table as the K factor (Kw and Kf) and the T factor. Erosion factor K indicates the susceptibility of a soil to sheet and rill erosion by water. Factor K is one of six factors used in the Universal Soil Loss Equation (USLE) and the Revised Universal Soil Loss Equation (RUSLE) to predict the average annual rate of soil loss by sheet and rill erosion in tons per acre per year. The estimates are based primarily on percentage of silt, sand, and organic matter and on soil structure and Ksat. Values of K range from 0.02 to 0.69. Other factors being equal, the higher the value, the more susceptible the soil is to sheet and rill erosion by water. Erosion factor Kw indicates the erodibility of the whole soil. The estimates are modified by the presence of rock fragments. Erosion factor Kf indicates the erodibility of the fine -earth fraction, or the material less than 2 millimeters in size. 82 Custom Soil Resource Report Erosion factor T is an estimate of the maximum average annual rate of soil erosion by wind and/or water that can occur without affecting crop productivity over a sustained period. The rate is in tons per acre per year. Wind erodibility groups are made up of soils that have similar properties affecting their susceptibility to wind erosion in cultivated areas. The soils assigned to group 1 are the most susceptible to wind erosion, and those assigned to group 8 are the least susceptible. The groups are described in the "National Soil Survey Handbook." Wind erodibility index is a numerical value indicating the susceptibility of soil to wind erosion, or the tons per acre per year that can be expected to be lost to wind erosion. There is a close correlation between wind erosion and the texture of the surface layer, the size and durability of surface clods, rock fragments, organic matter, and a calcareous reaction. Soil moisture and frozen soil layers also influence wind erosion. Reference: United States Department of Agriculture, Natural Resources Conservation Service. National soil survey handbook, title 430 -VI. (http://soils.usda.gov) 83 Custom Soil Resource Report Physical Soil Properties- Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Depth Sand Silt Clay Moist bulk density Saturated hydraulic conductivity Available water capacity Linear extensibility Organic matter Erosion factors Wind erodibility group Wind erodibility index Kw Kf T In Pct Pct Pct g/cc micro m/sec In/In Pct Pct 55-Parachute- Irigul complex, 5 to 30 percent slopes Parachute 0-10 -42- -38- 15-20- 25 1.25-1.40 4.23-14.11 0.14-0.17 0.0-2.9 3.0-6.0 .20 .20 3 5 56 10-25 -41- -37- 18-22-25 1.25-1.40 4.23-14.11 0.07-0.09 0.0-2.9 1.0-2.0 .10 .28 25-29 - - - - 0.42-1.41 - - - Irigul 0-6 -40- -38- 18-23- 27 1.25-1.40 4.23-14.11 0.10-0.13 0.0-2.9 1.0-3.0 .15 .28 1 6 48 6-13 -40- -38- 18-23- 27 1.25-1.40 4.23-14.11 0.07-0.09 0.0-2.9 0.0-0.5 .15 .43 13-17 „ - - - 0.42-1.41 - - - 56-Parachute- Irigul-Rhone association, 25 to 50 percent slopes Parachute 0-10 -42- -38- 15-20- 25 1.25-1.40 4.23-14.11 0.14-0.17 0.0-2.9 3.0-6.0 .20 .20 3 5 56 10-25 -41- -37- 18-22- 25 1.25-1.40 4.23-14.11 0.07-0.09 0.0-2.9 1.0-2.0 .10 .28 25-29 - - - - 0.42-1.41 - - - Irigul 0-6 -40- -38- 18-23- 27 1.25-1.40 4.23-14.11 0.10-0.13 0.0-2.9 1.0-3.0 .15 .28 1 6 6-13 -40- -38- 18-23- 27 1.25-1.40 4.23-14.11 0.07-0.09 0.0-2.9 0.0-0.5 .15 .43 13-17 - - - - 0.42-1.41 - - - Rhone 0-10 -39- -37- 20-24- 27 1.25-1.40 4.23-14.11 0.14-0.17 0.0-2.9 3.0-6.0 .20 .20 4 6 48 10-39 -39- -37- 20-24- 27 1.25-1.40 4.23-14.11 0.14-0.17 0.0-2.9 1.0-3.0 .15 .28 39-55 -39- -37- 20-24- 27 1.25-1.40 4.23-14.11 0.07-0.09 0.0-2.9 0.0-1.0 .15 .37 55-59 - - - - 0.42-1.41 - - - 84 Custom Soil Resource Report Soil Qualities and Features This folder contains tabular reports that present various soil qualities and features. The reports (tables) include all selected map units and components for each map unit. Soil qualities are behavior and performance attributes that are not directly measured, but are inferred from observations of dynamic conditions and from soil properties. Example soil qualities include natural drainage, and frost action. Soil features are attributes that are not directly part of the soil. Example soil features include slope and depth to restrictive layer. These features can greatly impact the use and management of the soil. Soil Features This table gives estimates of various soil features. The estimates are used in land use planning that involves engineering considerations. A restrictive layer is a nearly continuous layer that has one or more physical, chemical, or thermal properties that significantly impede the movement of water and air through the soil or that restrict roots or otherwise provide an unfavorable root environment. Examples are bedrock, cemented layers, dense layers, and frozen layers. The table indicates the hardness and thickness of the restrictive layer, both of which significantly affect the ease of excavation. Depth to top is the vertical distance from the soil surface to the upper boundary of the restrictive layer. Subsidence is the settlement of organic soils or of saturated mineral soils of very low density. Subsidence generally results from either desiccation and shrinkage, or oxidation of organic material, or both, following drainage. Subsidence takes place gradually, usually over a period of several years. The table shows the expected initial subsidence, which usually is a result of drainage, and total subsidence, which results from a combination of factors. Potential for frost action is the likelihood of upward or lateral expansion of the soil caused by the formation of segregated ice lenses (frost heave) and the subsequent collapse of the soil and loss of strength on thawing. Frost action occurs when moisture moves into the freezing zone of the soil. Temperature, texture, density, saturated hydraulic conductivity (Ksat), content of organic matter, and depth to the water table are the most important factors considered in evaluating the potential for frost action. It is assumed that the soil is not insulated by vegetation or snow and is not artificially drained. Silty and highly structured, clayey soils that have a high water table in winter are the most susceptible to frost action. Well drained, very gravelly, or very sandy soils are the least susceptible. Frost heave and low soil strength during thawing cause damage to pavements and other rigid structures. Risk of corrosion pertains to potential soil -induced electrochemical or chemical action that corrodes or weakens uncoated steel or concrete. The rate of corrosion of uncoated steel is related to such factors as soil moisture, particle -size distribution, acidity, and electrical conductivity of the soil. The rate of corrosion of concrete is based mainly on the sulfate and sodium content, texture, moisture content, and acidity of the soil. Special site examination and design may be needed if the combination of factors results in a severe hazard of corrosion. The steel or concrete in installations that intersect soil boundaries or soil layers is more susceptible to corrosion than the steel 85 Custom Soil Resource Report or concrete in installations that are entirely within one kind of soil or within one soil layer. For uncoated steel, the risk of corrosion, expressed as low, moderate, or high, is based on soil drainage class, total acidity, electrical resistivity near field capacity, and electrical conductivity of the saturation extract. For concrete, the risk of corrosion also is expressed as low, moderate, or high. It is based on soil texture, acidity, and amount of sulfates in the saturation extract. 86 Custom Soil Resource Report Soil Features– Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Restrictive Layer Subsidence Potential for frost action Risk of corrosion Kind Depth to top Thickness Hardness Initial Total Uncoated steel Concrete In In In In 55—Parachute- Irigul complex, 5 to 30 percent slopes Parachute Paralithic bedrock 20-40 — Weakly cemented 0 — Moderate Moderate Low Irigul Lithic bedrock I 5-20 — InduratedTM- 0 — Low III Moderate Low 56—Parachute- Irigul-Rhone association, 25 to 50 percent slopes Parachute Paralithic bedrock 20-40 — Weakly cemented 0 — Moderate Moderate Low Irigul Lithic bedrock 1 5-20 Indurated fl 1 = Low T Moderate P Low — Rhone Paralithic bedrock 40-60 — Weakly cemented 0 — Moderate Moderate Low 87 Custom Soil Resource Report Water Management This folder contains a collection of tabular reports that present soil interpretations related to water management. The reports (tables) include all selected map units and components for each map unit, limiting features and interpretive ratings. Water management interpretations are tools for evaluating the potential of the soil in the application of various water management practices. Example interpretations include pond reservoir area, embankments, dikes, levees, and excavated ponds. Ponds and Embankments This table gives information on the soil properties and site features that affect water management. The degree and kind of soil limitations are given for pond reservoir areas; embankments, dikes, and levees; and aquifer -fed excavated ponds. The ratings are both verbal and numerical. Rating class terms indicate the extent to which the soils are limited by all of the soil features that affect these uses. Not limited indicates that the soil has features that are very favorable for the specified use. Good performance and very low maintenance can be expected. Somewhat limited indicates that the soil has features that are moderately favorable for the specified use. The limitations can be overcome or minimized by special planning, design, or installation. Fair performance and moderate maintenance can be expected. Very limited indicates that the soil has one or more features that are unfavorable for the specified use. The limitations generally cannot be overcome without major soil reclamation, special design, or expensive installation procedures. Poor performance and high maintenance can be expected. Numerical ratings in the table indicate the severity of individual limitations. The ratings are shown as decimal fractions ranging from 0.01 to 1.00. They indicate gradations between the point at which a soil feature has the greatest negative impact on the use (1.00) and the point at which the soil feature is not a limitation (0.00). Pond reservoir areas hold water behind a dam or embankment. Soils best suited to this use have low seepage potential in the upper 60 inches. The seepage potential is determined by the saturated hydraulic conductivity (Ksat) of the soil and the depth to fractured bedrock or other permeable material. Excessive slope can affect the storage capacity of the reservoir area. Embankments, dikes, and levees are raised structures of soil material, generally less than 20 feet high, constructed to impound water or to protect land against overflow. Embankments that have zoned construction (core and shell) are not considered. In this table, the soils are rated as a source of material for embankment fill. The ratings apply to the soil material below the surface layer to a depth of 5 or 6 feet. It is assumed that soil layers will be uniformly mixed and compacted during construction. The ratings do not indicate the ability of the natural soil to support an embankment. Soil properties to a depth even greater than the height of the embankment can affect performance and safety of the embankment. Generally, deeper onsite investigation is needed to determine these properties. Soil material in embankments must be resistant to seepage, piping, and erosion and have favorable compaction characteristics. Unfavorable features include less than 5 feet of suitable material and a high content of stones or boulders, organic matter, or 88 Custom Soil Resource Report salts or sodium. A high water table affects the amount of usable material. It also affects trafficability. Aquifer -fed excavated ponds are pits or dugouts that extend to a ground -water aquifer or to a depth below a permanent water table. Excluded are ponds that are fed only by surface runoff and embankment ponds that impound water 3 feet or more above the original surface. Excavated ponds are affected by depth to a permanent water table, Ksat of the aquifer, and quality of the water as inferred from the salinity of the soil. Depth to bedrock and the content of large stones affect the ease of excavation. Information in this table is intended for land use planning, for evaluating land use alternatives, and for planning site investigations prior to design and construction. The information, however, has limitations. For example, estimates and other data generally apply only to that part of the soil between the surface and a depth of 5 to 7 feet. Because of the map scale, small areas of different soils may be included within the mapped areas of a specific soil. The information is not site specific and does not eliminate the need for onsite investigation of the soils or for testing and analysis by personnel experienced in the design and construction of engineering works. Government ordinances and regulations that restrict certain land uses or impose specific design criteria were not considered in preparing the information in this table. Local ordinances and regulations should be considered in planning, in site selection, and in design. Report—Ponds and Embankments [Onsite investigation may be needed to validate the interpretations in this table and to confirm the identity of the soil on a given site. The numbers in the value columns range from 0.01 to 1.00. The larger the value, the greater the potential limitation. The table shows only the top five limitations for any given soil. The soil may have additional limitations] Ponds and Embankments– Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Pct. of map unit Pond reservoir areas Embankments, dikes, and levees Aquifer -fed excavated ponds Rating class and limiting features Value Rating class and limiting features Value Rating class and limiting features Value 55—Parachute-Irigul complex, 5 to 30 percent slopes Parachute 60 Very limited Somewhat limited Very limited Slope 1.00 Thin layer 0.96 Depth to water 1.00 Seepage 0.72 Depth to bedrock 0.26 Irigul 30 Very limited Very limited Very limited Depth to bedrock 1.00 Thin layer 1.00 Depth to water 1.00 Slope 1.00 Seepage 0.25 89 Custom Soil Resource Report Ponds and Embankments– Douglas -Plateau Area, Colorado, Parts of Garfield and Mesa Counties Map symbol and soil name Pct. of map unit Pond reservoir areas Embankments, dikes, and levees Aquifer -fed excavated ponds Rating class and limiting features Value Rating class and limiting features Value Rating class and limiting features Value 56—Parachute-Irigul- Rhone association, 25 to 50 percent slopes Parachute 35 Very limited Somewhat limited Very limited Slope 1.00 Thin layer 0.96 Depth to water 1.00 Seepage 0.72 Depth to bedrock 0.26 Irigul 30 Very limited Very limited Very limited Slope 1.00 Thin layer 1.00 Depth to water 1.00 Depth to bedrock 1.00 Seepage 0.25 Rhone 20 Very limited Somewhat limited Very limited Slope 1.00 Seepage 0.25 Depth to water 1.00 Seepage 0.72 Thin layer 0.02 Depth to bedrock 0.01 90 References American Association of State Highway and Transportation Officials (AASHTO). 2004. Standard specifications for transportation materials and methods of sampling and testing. 24th edition. American Society for Testing and Materials (ASTM). 2005. Standard classification of soils for engineering purposes. ASTM Standard D2487-00. Cowardin, L.M., V. Carter, F.C. Golet, and E.T. LaRoe. 1979. Classification of wetlands and deep -water habitats of the United States. U.S. Fish and Wildlife Service FWS/OBS-79/31. Federal Register. July 13, 1994. Changes in hydric soils of the United States. Federal Register. September 18, 2002. Hydric soils of the United States. Hurt, G.W., and L.M. Vasilas, editors. Version 6.0, 2006. Field indicators of hydric soils in the United States. National Research Council. 1995. Wetlands: Characteristics and boundaries. Soil Survey Division Staff. 1993. Soil survey manual. Soil Conservation Service. U.S. Department of Agriculture Handbook 18. http://soils.usda.gov/ Soil Survey Staff. 1999. Soil taxonomy: A basic system of soil classification for making and interpreting soil surveys. 2nd edition. Natural Resources Conservation Service, U.S. Department of Agriculture Handbook 436. http://soils.usda.gov/ Soil Survey Staff. 2006. Keys to soil taxonomy. 10th edition. U.S. Department of Agriculture, Natural Resources Conservation Service. http://soils.usda.gov/ Tiner, R.W., Jr. 1985. Wetlands of Delaware. U.S. Fish and Wildlife Service and Delaware Department of Natural Resources and Environmental Control, Wetlands Section. United States Army Corps of Engineers, Environmental Laboratory. 1987. Corps of Engineers wetlands delineation manual. Waterways Experiment Station Technical Report Y-87-1. United States Department of Agriculture, Natural Resources Conservation Service. National forestry manual. http://soils.usda.gov/ United States Department of Agriculture, Natural Resources Conservation Service. National range and pasture handbook. http://www.glti.nrcs.usda.gov/ United States Department of Agriculture, Natural Resources Conservation Service. National soil survey handbook, title 430 -VI. http://soils.usda.gov/ United States Department of Agriculture, Natural Resources Conservation Service. 2006. Land resource regions and major land resource areas of the United States, the Caribbean, and the Pacific Basin. U.S. Department of Agriculture Handbook 296. http://soils.usda.gov/ 91 Custom Soil Resource Report United States Department of Agriculture, Soil Conservation Service. 1961. Land capability classification. U.S. Department of Agriculture Handbook 210. 92 Geologic and Soils Hazards Report Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 NATURAL AND GEOLOGIC HAZARDS ASSESSMENT REPORT MARATHON OIL COMPANY 32C PRODUCED WATER POND SE 1/4, SW 1/4 SECTION 32, T5S, R96W, 6TH P.M. GARFIELD COUNTY, COLORADO PREPARED FOR MARATHON OIL COMPANY 743 HORIZON COURT, SUITE 220 GRAND JUNCTION, COLORADO 81506 PREPARED BY OLSSON ASSOCIATES 4690 TABLE MOUNTAIN DRIVE, SUITE 200 GOLDEN, COLORADO 80403 JANUARY 2014 PROJECT No. 012-1372 OkOLSSON ASSOCIATES Natural and Geologic Hazard Report Preface Garfield County, Colorado, finalized the Land Use and Development Code (LUDC) with an effective date of July 15, 2013. According to Section 7-108 Use of Land Subject to Natural Hazards of the Garfield County LUDC "Land subject to identified Natural and Geologic Hazards, such as falling rock, landslides, snow slides, mud flows, radiation, flooding, or high water tables, shall not be developed unless it has been designed to eliminate or mitigate the potential effects of hazardous site conditions as designed by a qualified professional engineer and as approved by the County." The LUDC requires a Natural and Geologic Hazard Study be prepared by a qualified professional geologist be submitted with a development plan or plat. The LUDC defines a geologic hazard as "A geologic phenomenon that is so adverse to past, current, or foreseeable construction or land use as to constitute a significant hazard to public health and safety or to property. The LUDC defines a Hazard Area as "An area that contains oris directly affected by a geologic hazard, including but not limited to the following types of areas." 1f A. Avalanche Area. "A mass of snow or ice and other material that may become incorporated therein as such mass moves rapidly down a Slope." B. Landslide Area. "An area with demonstrably active mass movement of rock and soil where there is a distinct surface rupture or zone of weakness that separates the landslide material from more stable underlying material." C. Mudflow Debris Area. "An area subject to rapid mud and debris movement or deposit occurring after mobilization by heavy rainfall or snowmelt runoff. Such areas are formed by successive episodes of deposition of mud and debris." D. Radioactive Area. "An area subject to various types of radiation emission from radioactive minerals that occur in natural or manmade deposits of rock, soil, or water." E. Potentially Unstable Soils. "An area of land identified as having soils that may cause damage to structures, such as buildings and roadways, as a result of over saturation or some other outside influence." According to the Garfield County LUDC Section 4-203 Description of Submittal Requirements, the professional qualifications for preparation and certification of certain documents required by this Code are as follows: "Geologist. Geology reports shall be prepared by either a member of the American Institute of Professional Geologists, a member of the Association of Engineering Geologists, or a qualified geotechnical engineer licensed in the State of Colorado." Geologic Hazard Report 32C Water Impoundment Garfield County, CO i Olsson Associates Golden, Colorado January 2014 A search of the Colorado Department of Regulatory Agencies (DORA) Licensed Professionals and Businesses indicates that Colorado licenses "professional engineers" and "engineer interns" but does not appear to have a license specific to "geotechnical engineers." Currently, the state of Colorado does not require licensure or registration of geologists. Colorado Revised Statutes do require that geologic reports be prepared or authorized by a professional geologist. However, "Professional Geologist" is a term defined in Colorado Statutes. The references for these Statutes are shown here: 34-1-201. Definitions. As used in this part 2, unless the context otherwise requires: (1) "Geologist" means a person engaged in the practice of geology. (2) "Geology" means the science which treats of the earth in general; the earth's processes and its history; investigation of the earth's crust and the rocks and other materials which compose it; and the applied science of utilizing knowledge of the earth's history, processes, constituent rocks, minerals, liquids, gases, and other materials for the use of mankind. (3) "Professional geologist" is a person who is a graduate of an institution of higher education which is accredited by a regional or national accrediting agency, with a minimum of thirty semester hours (forty-five quarter) hours of undergraduate or graduate work in a field of geology and whose post baccalaureate training has been in the field of geology with a specific record of an additional five years of geological experience to include no more than two years of graduate work. (4) 34-1-202. Reports containing geologic information. Any report required by law or by rule and regulation, and prepared as a result of or based on a geologic study or on geologic data, or which contains information relating to geology, as defined in section 34-1-201 (2), and which is to be presented for any state agency, political subdivision of the state, or recognized state or local board or commission, shall be prepared or approved by a professional geologist as defined in section 34-1-201(3). Geologic Hazard Report 32C Water Impoundment Garfield County, CO ii Olsson Associates Golden, Colorado January 2014 Professional Geologist Certification By means of this certification, I attest that: - I am qualified to prepare a Natural and Geologic Hazard Study in accordance with the provisions of Section 7-207 of the Garfield County LUDC, and that I am a member of the American Institute of Professional Geologists per LUDC 4-203. - Although I have not visited the proposed Site I am familiar with the geology and have performed field work in the area of the proposed Marathon 32C located in the SE 1/4 SW '/4 Section 32, Township 5 South, Range 96 West, 6th Principal Meridian in Garfield County, Colorado. - Although the Colorado Geological Survey does not currently have a licensing or registration program for professional geologists practicing in the state of Colorado, there are requirements within local and State statutes that require that geologic reports be prepared by a professional geologist. I attest that I meet the requirements of the Colorado Geological Survey's definition of a professional geologist having completed and met the educational requirements of the Colorado Geological Survey definition. - I am a licensed Professional Geologist and Professional Geoscientist in other States, including Utah and Wyoming which do have licensing programs for professional geologists. - I have reviewed published geologic maps and reports applicable to this area and have considered the implications of these conditions in the context of the proposed development. - This report has been prepared in accordance with good scientific principles and engineering practices including consideration of applicable industry standards, and with consideration of the requirements of the National Association of State Boards of Geology. The conclusions and recommendations contained in this report are based on information available and known to me at the time of this report. Good scientific principles and standard engineering practices were taken into consideration to in arriving at the conclusions and recommendations made in this report. James W. Hix Senior Geologist Date: 1/27/2014 Note: The PG's certification does not relieve the owner/operator of the facility of the duty to review this report or fully implementing the recommendations in accordance with all applicable Federal, State, and local requirements in order to achieve the desired goals or objectives. Geologic Hazard Report 32C Water Impoundment Garfield County, CO Olsson Associates Golden, Colorado January 2014 TABLE OF CONTENTS Natural and Geologic Hazard Report Preface Professional Geologist Certification TABLE OF CONTENTS iv FIGURES iv 1.0 EXECUTIVE SUMMARY 1 2.0 GENERAL SITE LOCATION AND BACKGROUND 2 2.1 Project and Site Description 2 2.2 Structural Geology 2 2.3 Site Bedrock Geology 3 2.4 Soil 3 2.5 Hydrologic Setting 4 2.6 Aquifers 4 3.0 NATURAL AND GEOLOGIC HAZARD ASSESSMENT 6 3.1 Utilities 6 3.2 Avalanche Hazard Area 6 3.3 Landslide Areas or Potential Landslide Hazard Areas 6 3.4 Rockfall Areas 7 3.5 Alluvial Fan Hazard Areas 7 3.6 Unstable or Potentially Unstable Slopes 7 3.7 Corrosive or Expansive Soils and Rock 7 3.8 Mudflow and Debris Fan Areas 7 3.9 Development Over Faults 8 3.10 Flood Prone Areas 8 3.11 Collapsible Soils 8 3.12 Mining Activity 9 3.13 Radioactivity 9 4.0 Conclusions and Recommendations 11 5.0 References 12 FIGURES List of Figures Vicinity Map — V1 Geology Map — G1 Soils Map — S1 Surface Water — SW1 Floodplain Map — F1 Geologic Hazard Report 32C Water Impoundment Garfield County, CO iv Olsson Associates Golden, Colorado January 2014 1.0 EXECUTIVE SUMMARY Olsson Associates (Olsson) was contracted by Noble Energy to assess natural and geologic hazards potentially present in the area of the proposed 32C Surface Water Impoundment located in the SE 1/4, SW 1/4 Section 32, Township 5 South, Range 96 West, of the 6th Principal Meridian, Garfield County, Colorado. The site lies at an elevation greater than 8,340 feet above mean sea level (amsl) as shown on the attached Vicinity Map — V1. The purpose of this report is to identify geologic conditions that may pose hazards to a land development project in order that appropriate mitigation or avoidance techniques may be implemented as described in the Garfield County LUDC. According to the Garfield County LUDC, Section 7-207, the types of natural and geologic hazards identified pertain to the following: A. Utilities; B. Development in Avalanche Hazard Areas; C. Development in Landslide Hazard Areas; D. Development in Rock -fall Hazard Areas; E. Development in Alluvial Fan Hazard Areas; F. Slope Development; G. Development on Corrosive or Expansive Soils and Rock; H. Development in Mudflow Areas; and 1. Development Over Faults. This report presents Olsson findings following an evaluation of these and other geologic hazards potentially affecting the site and proposed development. The Marathon 32C Water Impoundment (Site) was found to be suitable for the proposed development with consideration of the following identified geologic hazards. • Slope is a limitation associated with the Parachute-Irigul complex soils. • According to the Slope Hazard Study Areas 1, 2, & 3, Garfield County, the area to the north and northwest of the town of Parachute is an area identified with Major Slope Hazards. The map does not include the site area which is further north. The site area is on a ridge between two drainages where the slopes are gentler than in adjacent areas. The water impoundment was constructed on the cut side of the pad. The water impoundment has been engineered and designed to mitigate the limitations for slopes in the area. This report should be read in its entirety, including but not limited to the conclusions and recommendations in section 4.0. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 1 Olsson Associates Golden, Colorado January 2014 2.0 GENERAL SITE LOCATION AND BACKGROUND Marathon Oil Company (Marathon) contracted Olsson Associates (Olsson) to conduct a natural and geologic hazards assessment as part of the proposed development of the 32C Water Impoundment. The proposed facility will be used to store produced water. The following sections provide information about the proposed development and the site geologic setting. The site surface and bedrock geology is shown on the Geology Map — G1. 2.1 Project and Site Description The proposed 32C Water Impoundment is located to the northwest of the town of Parachute, Colorado off of County Road 215. The site is located in the SE 1/4 SW '/4 Section 32, T5S, R96W, 6th P.M. and is located in parcel # 213532100009. 2.2 Structural Geology The water impoundment Site is located in the southeastern part of the Piceance Basin. The Piceance Basin is an irregularly-shaped elongated basin formed by tectonic forces associated with the Laramide orogeny. These tectonic forces down warped the earth's crust and formed the Piceance Basin as a result of the uplift of the surrounding Colorado Rocky Mountains and the Colorado Plateau. The Piceance Basin is the major structural geologic feature in the region. It is bound to the east by the Grand Hogback monocline, the White River Uplift to the northeast, the Gunnison Uplift to the south, the Uncompahgre Uplift to the south and southwest, the Douglas Creek Arch to the west-northwest, and the axial basin uplift to the north (Grout and Verbeek, 1992). Sedimentary rocks in the southwestern Piceance Basin gently dip to the north - northeast except where this regional dip is interrupted by low -amplitude folds. Numerous small sub - parallel northwest trending folds have been identified in the Green River Formation within the basin. The Divide Creek and Wolf Creek anticlines are two gentle, north-northwest trending, gas producing intrabasin folds located near the eastern margin of the Piceance Basin. The Grand Hogback monocline, located near Rifle Colorado, defines the eastern margin of the basin and is the surface expression of a basement block thrust wedge that resulted from southwest- to west-southwest compression late during the Laramide orogeny. There are no faults shown on the Preliminary Geologic Map of the Circle Dot Gulch Quadrangle, Garfield County, Colorado (Hail, 1982). A fault is a fracture in rock along which movement has occurred. Mountains are bound by faults and are a visible indication of a structural weakness in the earth's crust. The Colorado Rocky Mountains are bound by faults; however, these faults are not always visible at the ground surface either because the fault trace is `blind' meaning that the fault does not have surface expression since it does not cut across overlying sedimentary bedrock units, or that it has been buried and concealed by unconsolidated sediments deposited over the area where the faults are present. There are no known major faults that have mapped in the area of the Site. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 2 Olsson Associates Golden, Colorado January 2014 2.3 Site Bedrock Geology According the Preliminary Geologic Map of the Circle Dot Gulch Quadrangle (Hail, 1982) the bedrock mapped in the project area consists of the late Eocene -age Uinta Formation. In western Colorado, the Uinta Formation is composed of silty sandstone, siltstone and marlstone. The Uinta Formation that can approach 1,000 feet in thickness (Self and others, 2010). Underlying the Uinta Formation is the Parachute Creek member of Eocene -age Green River Formation. The intergranular space in these rocks is filled with sodium and calcium bicarbonate cements, but fracture zones increase permeability substantially. The Parachute Creek member consists of light -gray to light -brown weathered marlstone containing kerogen, a waxy hydrocarbon. The marlstone that contains large concentrations of kerogen is referred to as "oil shale". Oil shale is generally less permeable and forms confining units. The Mahogany ledge is a rich oil -shale zone in the Parachute Creek Member which is an important marker bed in the area. Other members of the Green River Formation, in descending order, include the Garden Gulch member, Douglas Creek Member, and Anvil Points Member, which overlie the Wasatch Formation. Underlying the Green River Formation are the early Eocene- and Paleocene Wasatch and Fort Union Formations as well as the Cretaceous Mesaverde Group (Robson and Banta, 1995). A bore log of Marathon's well 596-32A-#18, which is located at the project site indicates that the top of the Wasatch Formation was encountered at a depth of 4,720 feet below ground level (bgl), indicating that the combined thickness of the Uinta and Green River Formations exceeds 4,700 feet in the project area (Colorado Oil and Gas Conservation Commission website, accessed October 3rd, 2012). 2.4 Soil The Soils Map — S1 shows the area soil types. Soils, consisting of the following units, are within the study area around the32C Water Impoundment: Soil of the Parachute-Irigul complex, 5 to 30 percent slopes, was mapped in the vicinity of the Site. This complex is characterized as a loam to extremely channery loam that ranges in depth between 20 and 40 inches. The soil is well drained with low available water capacity. Water transmitting capacity ranges from moderately low to moderately high (0.06-0.2 in/hr). The parent material of the soil is residuum from weathered bedrock, which typically is composed of siltstone, sandstone, or shale in the vicinity of the facility. Also present on the western extent the facility area is the Parachute-Irigul-Rhone association, 25-50 percent slopes. This association has similar physical and textural characteristics to the Parachute-Irigul complex, although the Rhone member has a greater potential depth (up to 55 inches in thickness) that is derived from colluvium. The Site is located on a saddle between two drainages — Little Creek to the northeast and House Log Gulch to the southeast. The terrain surrounding the Site undulates creating a hummocky upland area parallel to the drainages. The slopes in the vicinity of the Site are gentler than those adjacent to the drainages. The depth to bedrock is expected to lie at depths Geologic Hazard Report 32C Water Impoundment Garfield County, CO 3 Olsson Associates Golden, Colorado January 2014 of 20 inches to 40 inches below ground surface (bgs). This is a limitation for shallow excavations and some construction projects. 2.5 Hydrologic Setting Surface water features within two miles of the project site include the northeast -sloping Little Creek to the north and House Log Gulch to the south. The Site is located about 1,000 feet south of Little Creek and 2,100 feet north of House Log Gulch and sits approximately 320 feet and 240 feet in elevation above the two creeks, respectively. Both streams are shown on the USGS 1:24,000 topographic map (Circle Dot Gulch Quadrangle) to have perennial flow, although no flow records are available to determine the flow conditions in these drainages. Four springs have been mapped within 2 miles of the facility on the Circle Dot Gulch Quadrangle topographic map. One mapped spring is located within the House Log Gulch Drainage about 1.2 miles southwest of the facility. A second spring is mapped in the source area of Circle Dot Gulch, and two other springs are identified within the Willow Creek drainage northwest of the facility. Each of the identified springs within 2 miles of the project site are located near the upper headwall areas of the drainages previously described. Flow rates and duration of the springs are not presently known. The hydrology of the area around the proposed water impoundment Site is controlled by Little Creek and House Log Gulch which both drain to Parachute Creek to the northeast as shown on the Surface Water Map (SW -1). 2.6 Aquifers According to the Colorado Department of Water Resources CDSS Map Viewer, no alluvial aquifers are mapped in the vicinity of the facility. However, as noted in the previous section, springs indicate the presence of shallow groundwater in the area. Over half of the precipitation at higher elevations in the Piceance Basin falls as winter precipitation, of which serves as a groundwater recharge source in the form of snowpack (Taylor, 1987). The residuum material on the Roan Plateau acts as an absorptive veneer that transmits snowmelt as recharge to the underlying bedrock during the spring runoff period (Topper and others, 2003). The shallow groundwater enters the groundwater flow system via the surficial residuum and through downward movement, eventually enters into fractures, joints and other cavities considered secondary porosity in the underlying bedrock aquifer. Based on the surface topography, shallow groundwater movement in materials above the Tertiary bedrock most likely follows the surface gradient towards the east/northeast where the surface drainages empty off the Roan Plateau and into the West Parachute Creek valley. Depth to shallow groundwater can range from less than 20 feet in the narrow drainages and near the identified springs to beyond 100 feet on the divides that separate the drainages. Since the project location is over 200 feet above the nearest drainage and is situated on a local flow divide, it is likely that groundwater is greater than 100 feet in depth below the project site area. Three monitoring wells, one up -gradient and two down -gradient of the facility will be constructed in the shallow groundwater as a secondary safeguard for detection of potential facility leaks into the subsurface. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 4 Olsson Associates Golden, Colorado January 2014 The bedrock aquifer underlying the site is composed of the Uinta Formation and the Parachute Creek Member of the Green River Formation. This aquifer has been named the Uinta-Animas Aquifer by the U.S. Geological Survey (Robson and Banta, 1995) and the Piceance Basin Aquifer by the Colorado Geological Survey (Topper and others, 2003). The Colorado Geological Survey subdivides the aquifer into Upper and Lower Piceance Basin aquifers, with the upper zone composed of the siltstones and sandstones in the Uinta Formation and the upper portion of the Parachute Creek Member. Immediately below this portion of the aquifer is the Mahogany confining unit, a 100 feet to 150 feet thick unit of kerogen-rich shale and maristone. Beneath this confining unit is the lower portion of the Parachute Creek Member that is considered the Lower Piceance Basin aquifer. The thickness of the Upper and Lower Piceance Basin aquifers are approximately 500 feet and 600 feet, respectively, in the project area. Robson and Banta (1995) show a potentiometric surface elevation contour of 8,000 feet in the project area, indicating that the saturated zone of the Upper Piceance Basin aquifer is greater than 300 feet below the site but is closer to the land surface in the valley bottoms of Little Creek and House Log Gulch. Underlying the Upper and Lower Piceance Basin aquifers is a confining unit upwards of 4,000 feet in thickness that includes the lower members of the Green River Formation, the Wasatch Formation and the Fort Union Formation. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 5 Olsson Associates Golden, Colorado January 2014 3.0 NATURAL AND GEOLOGIC HAZARD ASSESSMENT The following sections present the assessment of geologic hazards in the vicinity of the proposed Water Impoundment. The Vicinity Map (V-1) shows the Water Impoundment Site in relation to the affected parcel and local roads. 3.1 Utilities Above -ground utility facilities located in Hazard Areas will be protected by barriers or diversion techniques approved by a qualified professional engineer. The determination to locate utility facilities above ground shall be based upon the recommendation and requirements of the utility service provider and approved by the County. Above -ground utilities, such as transformers, are not expected to be affected by geologic or other natural hazards. Trenches for water pipelines, natural gas pipelines, and electrical lines are expected to be associated with the proposed development. The slopes and depth to shallow bedrock pose technical challenges to the installation of these utilities. 3.2 Avalanche Hazard Area Winters are cold in the mountainous areas of Garfield County, and valleys are colder than the lower parts of adjacent mountains due to cold air drainage. Average seasonal snowfall in Garfield County is 50 inches. The greatest snow depth at any one time during the period of record from 1951 to 1974 was 29 inches recorded at Rifle, Colorado approximately 20 miles to the east - northeast of the proposed site. Avalanches are not expected to affect the proposed water impoundment Site since it is located at an elevation of approximately 8,340 feet amsl. Areas in eastern Garfield County are at higher elevation, receive more snow pack, and are therefore more prone to avalanches in certain years. Avalanches are the most dangerous geologic hazard in Colorado resulting in injuries, loss of life, and about $100,000 in direct property damage, and indirect economic losses in the millions of dollars annually. However, the avalanche prone areas include the Park Range and Flat Tops in northeastern Garfield County, Colorado, to the north of Glenwood Springs. Glenwood Springs, near the east edge of the area, averages about one degree cooler than Rifle and receives about five inches more precipitation per year (Harman and Murray, 1985). 3.3 Landslide Areas or Potential Landslide Hazard Areas The Site is not in a landslide area or potential landslide hazard area. Landslides in western Colorado are typically associated with areas of significant slopes covered with unconsolidated sediments. Landslides are natural and ongoing events in these areas. Landslides can be triggered by human activities disrupting the land and periods of precipitation which increase the chances of landslide occurrence. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 6 Olsson Associates Golden, Colorado January 2014 3.4 Rockfall Areas The Site is not located within an area that has been mapped as having rockfall or potential for rockfall. Potential rockfall areas may be present along the steep drainages incised by Little Creek to the northeast and Log Gulch to the southeast. 3.5 Alluvial Fan Hazard Areas The Site is not located within an alluvial fan hazard area. Alluvial fans are present at the mouths of canyons on the Colorado River flood plain. 3.6 Unstable or Potentially Unstable Slopes According to the Garfield County Slope Hazard Study Areas 1, 2, & 3 map, parts of the area north of the Colorado River and the town of Parachute, Colorado, have been mapped as being in an area of major slope hazard. The map does not include the area of the site which is further to the north. The slope hazard map recommends that site specific investigations should be conducted to assess active landslide areas. Geologic studies may include intensive drilling and sophisticated strength testing, stability analyses, and monitoring of soil, rock, and groundwater conditions. Mitigation may be possible, but likely will be expensive, may require special siting, and will involve some risk. Avoidance may be recommended for projects of lower economic value (Garfield County, Slope Hazard Study 2002). The water impoundment was constructed on the cut side of the pad. The water impoundment has been engineered and designed to mitigate the limitations for slopes in the area. 3.7 Corrosive or Expansive Soils and Rock According to the Soil Survey of the Rifle Area the Parachute — Irigul soils are slightly acidic to alkaline and have a pH ranging from 6.6 to 7.8 standard pH units. Sedimentary rock containing high salt content, such as chloride or sulfate, and soils derived from these rock types, may be corrosive to concrete or metal, causing damage to structures built upon them. These conditions are not expected to be present in the vicinity of the water impoundment Site. Some Tertiary and Cretaceous age sedimentary rocks with high clay content are capable of accepting water into their chemical structure and expand many times their volume when dry. These sedimentary rocks, and soils formed from these rock types, may expand or contract as they become wet and then dry out resulting in damage to structures built upon them. The water impoundment was constructed on the cut side of the pad. It has been engineered and designed to mitigate the limitations for slopes in the area. 3.8 Mudflow and Debris Fan Areas The Site is not located in a mudflow or debris fan area. There are areas of mudflows and debris fans to the south along the Colorado River. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 7 Olsson Associates Golden, Colorado January 2014 3.9 Development Over Faults There are no major faults known in the central Roan Plateau area. Three narrow grabens have been mapped along a northwest trending fracture zone to the north in the central part of Township 4 South, Range 97 West, and along a graben in the southwestern part of Township 4 South, Range 96 West, suggesting that these grabens lie along a single fracture zone that extends for approximately 9 miles. Maximum measured stratigraphic displacements along these faults do not exceed 120 feet, and most are considerably less (Hail, 1992). There are no mapped faults shown on the Preliminary Geologic Map of the Circle Dot Gulch Quadrangle in the immediate vicinity of the Site (Hail, 1982). The Piceance Basin and other Tertiary age basins of the Colorado Plateau are by monoclines, at least along one margin. The Grand Hogback to the east near the town of Rifle, is such a monocline which is thought to have formed by reactivation of pre-existing, steeply dipping fault zones in the Precambrian basement rock. Recent seismic data suggests that some of the monoclines, especially in the Rocky Mountain foreland near the boundary with the Colorado Plateau, overlie a west-, southwest-, or south -directed thrust fault system. These blind thrust faults transect older Mesozoic and Paleozoic sedimentary rocks that resulted from two major deformational events associated with the uplift of the ancestral Rocky Mountains. The Grand Hogback monocline formed above the tip of a blind, Precambrian basement rock thrust fault wedge which moved southwest and west-southwest into the Piceance basin (Grout and Verbeek, 1992). Colorado is considered a region of minor earthquake activity; however, there is uncertainty due to the relatively short historic record. According to the USGS Colorado Earthquake History online, newspaper accounts were the primary source of earthquake data in Colorado prior to 1962. Few earthquakes have been reported in this part of Colorado. A very minor earthquake occurred in the northwestern part of Colorado on November 22, 1982 at 3:09 a.m. MST. The magnitude 2.9 earthquake was located about 18 miles northeast of the town of Rifle and was felt at a fish hatchery in the area. The largest quake in the area occurred on April 22, 1984 and had a magnitude of 3.1 on the Richter scale. The quake was felt in Carbondale and in Glenwood Springs. Of the hundreds of quakes that occurred in the Carbondale area during that time period, 12 were reported as felt. 3.10 Flood Prone Areas The facility is not within a FEMA flood hazard zone and there are no surface waters located in the vicinity of the project. The elevation of the adjacent Little Creek drainage is at 8,070 feet amsl. 3.11 Collapsible Soils Collapsible soils are another type of subsidence that occurs in parts of western Colorado where unconsolidated sediments are present. This ground settlement can damage man-made structures such as foundations, pavements, concrete slabs, utilities, and irrigation works. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 8 Olsson Associates Golden, Colorado January 2014 Collapsible soils have not been mapped in the area and are not expected to be encountered in the vicinity of the water impoundment Site. 3.12 Mining Activity A review of the Circle Dot Gulch 7.5 -minute quadrangle did not show any significant mining activities in close proximity to the proposed water impoundment Site. A prospect pit is shown on the boundary between the NW 1/4 of Section 32 and the NE 1/4 of Section 31 to the west. Underground mining for oil shale was conducted in the 1980s and early 1990s north of the town of Parachute. Natural gas wells are shown in the surrounding areas of the proposed water impoundment. 3.13 Radioactivity Naturally occurring radioactive materials are not expected to be an issue at the Site. Olsson reviewed the Colorado Bulletin 40, Radioactive Mineral Occurrences of Colorado which states that nearly all of Garfield County's uranium production came before1954, and most of that came from the Rifle and Garfield mines, located along the same ore body near the town of Rifle. These occurrences were all hosted in the Jurassic Morrison and Entrada Formations, and the Triassic -Jurassic Navajo Sandstone, or the Triassic Chinle Formation which are known to contain uranium and vanadium deposits in the county and in the Colorado Plateau in general (Nelson -Moore, Collins, and Hornbaker, 1978). These formations lie at great depth in the vicinity of the Site and are stratigraphically below the depth of the Williams Fork Formation. Naturally occurring radioactive materials are not known to be abundant in the Williams Fork Formation or the rest of the Mesaverde Group, from which natural gas, and produced water are extracted. According to the USGS Open -File Report 81- 1348, the Geology and Chemical Analyses of Coal and Coal -associated Rock Samples, the Williams Fork Formation, (Upper Cretaceous) Northwestern Colorado (Hildebrand et al, 1981), statistical comparisons of the same means and variance of 35 elements (whole coal basis) for 100 Williams Fork Formation coal samples with 295 coal samples from elsewhere in the Rocky Mountain province show that the Williams Fork Formation samples have a significantly higher potassium content, but that the content for uranium was not significantly different. Uranium and phosphate occurrences in the Tertiary Uinta Formation have been documented in the Uinta Basin in Utah and Wyoming, but are not present in the Piceance Basin. Several weakly radioactive zones are known in the Piceance Basin within beds of the Parachute Creek Member of the Green River Formation; however, none of these contain significant uranium or phosphate (Love, 1964). Since there is no production from the Uinta or Green River Formation, radioactivity is not expected to be a significant hazard. The Colorado Department of Public Health and Environment (CDPHE) has posted a statewide radon potential map on their website based on data collected by the EPA and the U.S. Geological Survey. Garfield County and most of Colorado has been mapped as being within Zone 1 — High Radon Potential, or having a high probability that indoor radon concentrations will exceed the EPA action level of 4 picocuries per liter (pCi/L). Geologic Hazard Report 32C Water Impoundment Garfield County, CO 9 Olsson Associates Golden, Colorado January 2014 Radon is not expected to be a significant problem at the proposed site since the development will not include any permanent structures, personnel will not be onsite for extended periods, and the site will not be developed with structures containing basements or substructures in which radon can accumulate. Colorado oil and gas operations are not known to have a significant problem with naturally occurring radioactive materials (NORM) or technologically enhanced naturally occurring radioactive materials (TENORM); however, there have been some instances where pipe scale has contained radium and associated radon gas. A NORM survey including site specific testing could be performed to further assess the radon potential at the Site to serve as a baseline assessment if used pipe or pipe scale is to be disposed offsite in the future. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 10 Olsson Associates Golden, Colorado January 2014 4.0 Conclusions and Recommendations The following conclusions and recommendations were made following a review of the available site data for natural and geologic hazards in the vicinity of Marathon's 32C Water Impoundment Slte located in Garfield County, Colorado. • Geological hazards are not expected to be associated with the installation of buried utilities. Shallow bedrock and slopes may be a limitation to this construction. • Avalanche areas are present in the northeastern parts of Garfield County in parts of the Park Range and Flat Tops mountain range. Avalanche conditions are not expected to be present in area of the Site. • Landslides, mudflows, earthflow and soil creep are not expected to be a geologic hazard affecting the Site. These conditions are present in areas immediately north of the town of Parachute, but are not present in the immediate vicinity of the Site. • Rockfall areas are not present in the area of the Site. Rockfall areas are present in parts of the steep canyons and narrow drainages incised by area streams, but are not expected to be a hazard in the vicinity of the Site. • The Site is not in an alluvial fan hazard area. Alluvial fans are present along parts of the Colorado River drainage to the south at lower elevations. • Slope is a limitation associated with the Parachute-Irigul complex soils and certain types of development. The water impoundment area is on a ridge between two drainages where the slopes are gentler than in adjacent areas. The water impoundment was constructed on the cut side of the pad. The water impoundment has been engineered and designed to mitigate the limitations for slopes in the area. • Corrosive or expansive soils and rock are not expected to be present in the vicinity of the proposed water impoundment Site. Rocky soils may exist in the vicinity of the site which may impact the proposed development. • Collapsible soils are not present in the vicinity of the proposed water impoundment Site. • No significant faulting is known in the water impoundment Site. • No flood prone areas are mapped in the vicinity of the site. Flash flooding is an issue for lower elevations along Little Creek and House Log Gulch and areas along the Colorado River located to the south are prone to flood risks. • There are no mining activities shown in the vicinity of the site. Natural gas well drilling has been conducted in the area since the 1960s. • There are no significant radioactive mineral deposits known in the immediate area of the site. The presence of NORM may be an issue with exploration and production and could be an issue with used pipe scale or used equipment. Radioactive materials are not expected to pose a significant hazard at the Site. Geologic Hazard Report 32C Water Impoundment Garfield County, CO 11 Olsson Associates Golden, Colorado January 2014 5.0 References • Czyzewski, G., Chapter 12 — The Piceance Creek Basin, Colorado Ground -Water Association, Ground -Water Atlas, 1999 p 63-66. • Grout, M. A. and Verbeek, E.R., 1992, U.S.G.S. Bulletin 1787-Z, Fracture History of the Divide Creek and Wolf Creek Anticlines and Its Relation to Laramide Basin -Margin Tectonism, Southern Piceance Basin, Northwestern Colorado, 32 p. • Fischer, R.P., 1960, Vanadium -Uranium Deposits of the Rifle Creek Area, Garfield County, Colorado, U.S.G.S. Bulletin 1101, 52 p. • Hail, W.J., Jr., 1982, U.S.G.S. Preliminary Geologic Map of the Circle Dot Gulch Quadrangle, Colorado Miscellaneous Field Studies Map, MF -1293 • Hail, W.J., Jr., 1992, U.S.G.S. Bulletin 1787-R, Geology of the Central Roan Plateau Area, Northwestern, Colorado, 26 p., • Harman, J.B. and Murray, D. J., 1985, Soil Survey of Rifle Area, Colorado, Parts of Garfield and Mesa Counties, Colorado: U.S. Department of Agriculture, Soil Conservation Service, in cooperation with the Colorado Agricultural Experiment Station, 149 p. two plates, and 20 map sheets. • Nelson -Moore, J.L., Bishop Collins, D., Hornbaker, A.L., 2005, Colorado Geologic Survey, Bulletin 40, Radioactive Mineral Occurrences of Colorado, pp 154-158 (CD) • Robson, S.G. and Banta, E.R., 1995, U.S.G.S. Hydrologic Investigations Atlas 730-C, Groundwater Atlas of the United States, Segment 2, Arizona, Colorado, New Mexico, Utah, 32 p. • Topper, R., Spray, K. L., Bellis, W.H., Hamilton, J.L., Barkman, P.E., Ground Water Atlas of Colorado, Colorado Geologic Survey, 2003, Special Publication 53, 210 p. Online References • Colorado Oil and Gas Conservation Commission http://cogcc.state.co.us/ • Natural Resources Conservation Service - Soil Survey http://www.nrcs.usda.gov/ • Garfield County • Slope Hazards: http://garfield-county.com/geographic-information- systems/documents/6439291200422slopehaz.pdf • Soil Hazards: http://garfield-county.com/geographic-information- systems/documents/64335291200423soilhaz.pdf • Surficial Geology of Garfield County: http://garfield-county.com/geographic- information-systems/documents/geologic-hazards/24surfgeo.pdf • Colorado Geological Survey website: http://geosurvey.state.co.us/hazards • Colorado Geological Survey website: http://geosurvey.state.us/land/Pages/Professional Geologist • Colorado Oil and Gas Conservation Commission website: http://dnrwebcomapg.state.co.us/mapguide2010/ Geologic Hazard Report 32C Water Impoundment Garfield County, CO 12 Olsson Associates Golden, Colorado January 2014 FIGURES Legend ; 32C Water Impoundment ©Parcel 213532100009 (8 30 Acres) Parcels 11=13-ml:e Radius it 0.5 1 Miles 2 N PROJECT NO 612-1372 DRAWN BY Jenna Muhlhach DATE 7/13/12 VICINITY MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO OLSSON ASSOCIATES 760 HORIZON DRIVE SUITE 102 GRAND JUNCTION. CO 01608 TEL 970.263 .7800. FAX 570.263.7456 cI ,LJRE V-1 Geology Data provided by the USGS Geological Survey Legend 0 32C Water Impoundment Geology TYPE Tu - Unita formation N Feel W � p^ E D 125 250 Sob �f s PROJECT NO 012-1372 DRAWN BY Jenna Muhlbach DATE: 700f12 GEOLOGY MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO O\OLSSO N ASSOCIATES 760 HORIZON DRIVE SUITE 102 GRAND JUNCTION. CO 0.150.6 TEL 970 283 7800 FAX 970.263,7456 FIGURE G-1 eo Soil Data provided by USOA Web Scil Survey m 32C Water Impoundment Location er Legend 0 32C Water Impoundment 9aM Try. 52 - Nome veter-Adel complex, 5-50% slopes 55 - Parechuhe-higul complex, 5-3092 slopes -155 - Parachute-Irigul-Rhone association. 25-50% slopes pei 57 - Parachute -Rhone loans, 5.30% slopes (—I 63 - Silas loam. 1-12% slopes Fee: a 125 250 500 PROJECT NO 012-1372 DRAWN BY' Jenna FAuhlbach DATE: 7/15,12 SOILS MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO O\OLSSON ASSOCIATES 760 HORIZON DRIVE: SUITE 102 GRAND JUNCTION, CD 0150.6 TEL 970.263.7980 FAX 970.2633656 FIGURE S-1 411,1 32C Water Impoundment Water Data provided by the National Hydrography Dataset Legend l 32C Water Impoundment Route to Facility .• • Perennial Creeks Surface Water Feel 0 625 1,250 2.500 N PROJECT NO 012-1372 DRAWN BY: Jenna Muhtbach DATE 6.0712013 SURFACE WATER MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFI ELD COUNTY, COLORADO O\QLSSON A55OCIATE S 7&O HORIZON DRIVE; SUITE 102 GRAND JUNCTION. GP 81500 TEL 97e263.7$00 FA%. gln.78$.7ase FIGURE 32C Water Impoundment s. Floodplain Data provided Garfield County GIS Database Legend i) 320 Water ImpoundmenI FtoodPta in Highway - Local Roads .h, C1 0.5 1 Miles 2 JV N E PROJECT NO 012.1372 DRAWN BY' Jenna Mluhlbach DATE 7!18112 FLOODPLAIN MAP 32C WATER IMPOUNDMENT MARATHON OIL COMPANY GARFIELD COUNTY, COLORADO OLSSO N ASSOCIATES 764] HORIZON DRIVE SUITE 102 GRANO JUNCTION. co a151}a TEL 570.263.7800 FAX 876.263.7450 r-h E- t Wildlife and Vegetation Impact Analysis Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 MARATHON OIL COMPANY 32C PAD WILDLIFE AND SENSITIVE AREAS REPORT Cover Photo: Typical habitat surrounding the project area. Prepared for: Marathon Oil Company Prepared by: WestWater Engineering, Inc. 2516 Foresight Cr. #1 Grand Junction, CO 81505 .. Michael W Khsh Principal Environmental Scientist In Cooperation with: Olsson Associates 826 21 % Rd. Grand Junction, CO 81505 November 2012 INTRODUCTION At the request of Olsson Associates (Olsson), on behalf of Marathon Oil Company (Marathon), WestWater Engineering (WWE) biologists assessed wildlife habitat, wildlife occurrence, and sensitive plant species habitat and occurrence based on reviews of literature and the WWE GIS database for an existing produced water pond (Figure 1). The pond is located on a well pad that has been previously surveyed and inventoried by WWE biologists (WWE 2012 and WWE 2009). No pedestrian surveys were conducted for this project during 2012. The site is located north of Parachute, Colorado on the Roan Plateau in Section 32, Township 5 South, Range 96 West, 6th Principal Meridian. Pond 32C is located on an existing well pad. The pond is currently permitted under a short-term permit and Marathon would like to continue use of the pond and are applying for a long-term permit with Colorado Oil and Gas Conservation Commission (COGCC). The long-term use of the existing pond would reduce the need to construct a new produced water pond on another location. No new ground disturbance is required for the project. The surrounding area is primarily used for oil and gas development, livestock grazing, and wildlife habitat. METHODS Surveys have been conducted in the general area for past projects. Data collected during past projects was reviewed to determine potential presence of wildlife and plant species (including federally threatened, endangered, and candidate species) and habitats that may or are known to occur in the area. EXISTING ENVIRONMENTAL CONDITIONS WATERS OF THE U.S. - Army Corps of Engineers (ACOE) The site is located along a ridgetop on the Roan Plateau. The project is situated on the dividing ridge between House Log Gulch and Little Creek (Figure 1). WWE biologists determined that no wetlands or drainages showing characteristics of Waters of the U.S. (WOUS) were located at the project site. VEGETATION The project site is located on an existing disturbance surrounded by sagebrush dominated shrublands, scattered mountain shrublands, and aspen woodlands on north and east facing slopes (Table 1). Table 1. Common plant species likely to occur within the project area. Antelope bitterbrush (Purshia tridentata) Serviceberry (Amelanchier alnifolia) Aspen (Populus tremuloides) Smooth brome (Bromus inermis) Bluegrass (Poa spp) Snowberry (Symphoricarpos albus) Gambel oak (Quercus gambelii) Various wheatgrass species (Agropyron spp.) Indian ricegrass (Achantherum hymenoides) Vetch (Astragalus spp.) Lupine (Lupinus spp.) Western yarrow (Achillea millefolium) Needlegrass (Stipa spp.) Woods' rose (Rosa woodsii) Rabbitbrush (Ericameria nauseosa) Wyoming big sagebrush (Artemesia tridentata wyomingensis) WestWater Engineering Page 1 of 15 November 2012 Threatened, Endangered, and Sensitive Plant Species A review of the Colorado Natural Heritage Program (CNHP) database, soils and terrain at project site, and previous WWE surveys indicate that there are no threatened, endangered, and sensitive plant species, or their associated suitable habitats known to occur within the project area (Spackman et al 1997 and WWE 2012). Noxious Weeds Noxious weeds listed by Garfield County and the State of Colorado that are known to occur in the general project area include the following: houndstongue, common mullein, musk thistle, Canada thistle (along House Log Gulch), bull thistle, and whitetop. These species are common on the Roan Plateau near disturbed areas, riparian areas and wet depressions, and areas of intense grazing. WILDLIFE Federally and State Listed Candidate, Threatened, Endangered, and Species of Concern Federally and state listed species with potential to occur within the project area vicinity are described in Table 2. Table 2. Federally and State Listed Candidate, Threatened, Endangered, and Species of Concern with potential to occur in the vicinity of the project site. Common Name Scientific Name Status* Occurrence MAMMALS Northern pocket gopher Thomomys talpoides SC Occur in a variety of habitats including the Roan Plateau. Townsend's big- eared bat Corynorhinus townsendii pallescens SC Breeds in mine shafts, caves, rock outcrops, and cliffs. This species roosts and forages within pinyon/juniper woodlands and open montane forests. BIRDS Greater Sage- grouse Centrocercus urophasianus C Likely to occur in project area. FISH Bonytail Gila elegans FE, SE Occurs downstream in the Colorado River. Colorado pikeminnow Ptychocheilus Lucius FE, ST Occurs downstream in the Colorado River. Humpback chub Gila cypha FE, ST Occurs downstream in the Colorado River. Razorback sucker Xyrauchen texanus FE, SE ' Occurs downstream in the Colorado River. AMPHIBIANS WestWater Engineering Page 2 of 15 November 2012 Common Name Scientific Name Status* Occurrence Northern leopard frog Rana pi piens SC Unlikely to occur at project location; however species may occur in nearby House Log Gulch and Little Creek. REPTILES Midget faded rattlesnake Crotalus viridis concolor SC Habitat varies from riparian to semi -desert shrublands and foothills. Unlikely to occur in project area due to elevation. *= FE -Federally Endangered, FT -Federally Threatened, SE -State Endangered, ST -State Threatened, SC -State Special Concern. It is likely that northern pocket gophers occur in the project vicinity. They are known to occur on the Roan Plateau (Kingery 2011). However, it is unlikely that pocket gophers would occur on the project location due to the current use and ongoing operation of the site. There is currently a CPW approved wildlife netting in place to prevent wildlife from entering the pond. Townsend's big -eared bat may forage in the project vicinity; however, it is unlikely that bats would roost within the project area due to current ongoing human activity and lack of suitable roosting habitat at the project location. Bats prefer to roost in mine shafts, rocky outcrops, and caves. The project site is located within the 4 -mile buffer to two active Greater Sage -grouse lek sites and one lek of unknown status (NDIS 2012). Bear Run Lek and Garden Gulch Lek are active lek sites located north of the project area (Figure 2). Breeding occurs in the spring on leks (strutting grounds), where dominant males display to attract females to mate. Once bred, the females disperse to build a nest and lay eggs. Residual grass cover mixed with a quality herbaceous component in the understory of sagebrush shrublands provides quality nesting and brood rearing habitat. Research by the Colorado Parks and Wildlife (CPW) indicates that approximately 80 percent of the females nest in suitable habitats within a 4 -mile radius of the lek on which they were bred (CDOW 2008). It is likely that sage -grouse occupy and nest near the project site. All perennial and intermittent drainages that may potentially be affected by project runoff and sediment transport would eventually drain into the Colorado River which is designated Critical Habitat by US Fish and Wildlife Service (USFWS) for 4 federally listed endangered species of fish (USFWS 2012). The Colorado pikeminnow and razorback sucker both occur in the Colorado River downstream of the project area. Critical habitat for these two species begins at the Colorado River Bridge in Rifle, CO and continues downstream to Lake Powell (USFWS 1994). The northern leopard frog may occur in nearby House Log Gulch and Little Creek. There are no freshwater sources available at the project site to provide suitable habitat for northern leopard frogs. Raptors From previous WWE surveys, raptors species known to inhabit the Roan Plateau include Northern Harrier, Cooper's Hawk, Sharp -shinned Hawk, Northern Goshawk, Red-tailed Hawk, WestWater Engineering Page 3 of 15 November 2012 Swainson's Hawk, Golden Eagle, American Kestrel, Peregrine Falcon, Prairie Falcon, Flammulated Owl, Great Horned Owl, Northern Saw -whet Owl, and Long-eared Owl (Table 3). Table 3. Raptor species that may potentially inhabit the Marathon project area Common Name Scientific Name Habitat & Breeding Records American Kestrel Falco sparverius Coniferous and deciduous forests and open terrain with suitable perches. Nests in cavities in trees, cliffs and buildings. Cooper's Hawk Accipiter cooperii Cottonwood riparian to spruce/fir forests, including pifon/juniper woodlands. Nests most frequently in pines and aspen. Flammulated Owl Otus flammeolus Nest in cavities in open ponderosa pine or aspen to 10,000 feet in elevation. Golden Eagle Aquila chrysaetos Grasslands, shrublands, agricultural areas, pinon- juniper woodlands, and ponderosa forests. Prefers nest sites on cliffs and sometimes in trees in rugged areas. Great Horned Owl Bubo virginianus Occupies diverse habitats including riparian, deciduous and coniferous forests with adjacent open terrain for hunting. Long-eared Owl Asio otus Occupies mixed shrublands. Nests and roost in sites in dense cottonwoods, willows, scrub oak, junipers and dense forest of mixed conifers and aspens. Northern Saw- whet Owl Aegolius acadicus Mid -elevation ponderosa pine, old-growth pifon/juniper woodlands. Nests in tree cavities made by flickers or woodpeckers. Northern Goshawk Accipiter gentilis Nests in open conifer stands with large, older tress and aspen groves up to 10,000 feet. Requires large blocks of forested habitat for nesting and foraging. Northern Harrier Circus cyaneus Grassland, shrubland, agricultural areas, and marshes. Nests in areas with abundant cover (e.g., tall reeds, cattails, grasses) in grasslands and marshes. Also known to nest in high -elevation sagebrush. Peregrine Falcon Falco peregrinus .Nests on ledges in canyon cliffs from 4,500 to 9,000 feet in elevation. Confirmed breeder in Garfield County and the Parachute Creek drainage basin. Prairie Falcon Falco mexicanus Nest on cliffs near open habitats such as grasslands and shrublands. Year-round resident of Colorado. Confirmed breeder in Rio Blanco and Garfield counties. Elevation generally below 10,000 feet, but occasionally above timberline. Red-tailed Hawk Buteo jamaicensis Diverse habitats including grasslands, piton juniper woodlands and deciduous, coniferous and riparian forests. Nests in mature trees (especially cottonwood, aspen, and pines) and on cliffs and utility poles. Sharp -shinned Hawk Accipiter striatus High density young, or even -aged, stands of coniferous forest and deciduous forests of aspen or oak brush with small stands of conifers. Swainson's Hawk Buteo swainsoni Grassland, desert and agricultural areas with scattered trees and shrubs; less woodland than that used by Red-tailed hawks. Nests in everything from tall serviceberry and oakbrush to tall trees; nests are usually conspicuous. Bold= Birds listed by USFWS as Birds of Conservation Concern WestWater Engineering Page 4 of 15 November 2012 One raptor nest is known to occur near the project area. This nest was occupied by a Red-tailed Hawk during the 2012 nesting season (WWE 2012) and is approximately 1500 feet from the project site (Figure 3). No other nests are known to occur near the project area; however, no site specific pedestrian surveys were conducted for this site during 2012. Potential raptor woodland nesting and foraging habitat occurs in the aspen woodlands present near the project area. There are no cliffs within 0.5 miles of the project area to support nesting raptors. Migratory, Non -migratory and Birds of Conservation Concern (other than raptors) WWE biologists reviewed the project area for the presence of Birds of Conservation Concern (BCC) (Table 4) and BCC habitat in the project area, as described in the Colorado Breeding Bird Atlas (Kingery 1998), Colorado Birds (Andrews and Righter 1992), and Birds of Western Colorado Plateau and Mesa Country (Righter et al. 2004). Table 4. BCC species that may be present in the project area Common Name Scientific Name Habitat & Breeding Records Brewer's Sparrow Spizella breweri Sagebrush shrublands. Confirmed breeder in Garfield County. (USFWS 2008) There is potential for Brewer's Sparrows to nest and forage in the sagebrush shrublands near the project area. American Elk and Mule Deer The site is located within CDOW Game Management Unit (GMU) 32 and within mule deer and American elk summer range and near an elk production area (NDIS 2012) (Figure 4). No mule deer production areas are mapped by NDIS, but the entire area is within mule deer fawning habitat. Mule deer were observed during previous surveys, and elk droppings as well as fresh tracks were observed frequently in the project area. There are no mule deer or elk winter ranges in the project area, due to the high elevation and deep snows that cover the area during the winter. Elk and mule deer utilize the summer range extensively on the Roan Plateau, following the snow line up to higher elevations in the spring. Mule deer rely on the existing sagebrush and shrubs for their primary food source, while elk rely primarily on available grasses for food. Adjacent areas of aspen, Douglas -fir, and scattered oak brush/serviceberry copses provide necessary forage and production areas as well as escape, thermal, and loafing cover for deer and elk, particularly during the summer period. Black Bear and Mountain Lion CDOW-NDIS mapping shows the site to be within overall range for black bear and mountain lion (NDIS 2012). Black bear are a common resident mammal on the Roan Plateau. Black bears are omnivorous and the diet depends largely on what kinds of food are seasonally available, although their mainstay is vegetation. In spring, emerging grasses and succulent forbs are favored. In summer and early fall, bears take advantage of a variety of berries and other fruits. In late fall, WestWater Engineering Page 5 of 15 November 2012 preferences are for berries and mast (acorns), where available. When the opportunity is present, black bears eat a diversity of insects, including beetle larvae and social insects (ants, wasps, bees, termites, etc.), and they kill a variety of mammals, including rodents, rabbits, and young or unwary ungulates. The Roan Plateau provides important habitat to black bear during the late spring, summer, and fall months with its abundance of berry and mast producing plants including serviceberry, chokecherry, and Gambel oak. Black bear are in hibernation from mid-November through May. Mountain lion typically follow migrating deer herds in search of deer as the primary food source. They tend to have large territories and are highly mobile as they search for food or new territories. Mountain lions likely inhabit the project area during the summer months. The project area is not mapped by CDOW as a potential mountain lion conflict area. Small Mammals Common small mammal species in the project area include coyote (Canis latrans), golden - mantled ground squirrel (Spermophilus lateralis), and least chipmunk (Tamias minimus) (Fitzgerald 2011). Reptiles Western terrestrial garter snakes (Thamnophis elegans) have previously been observed in the vicinity of the project area. This species is common on the Roan Plateau and is typically observed around perennial creeks and ponds. Smooth green snakes (Liochlorophis vernalis) are known to occur on the Roan Plateau (Hammerson 1999). Short -horned lizards (Phrynosoma hernandesi) have been observed in the upland sagebrush habitats on the Roan Plateau. Adult and young -of -the -year short -horned lizards have been documented nearby. This species appears to be fairly abundant along ridgelines in sagebrush habitats north of Garden Gulch. Amphibians Tiger salamanders (Ambystoma tigrinum) occur sporadically across the Roan Plateau in suitable ponds, perennial streams, and wetlands. There are no freshwater sources available at the project site to provide suitable habitat for amphibian species. AFFECTS TO VEGETATION AND WILDLIFE VEGETATION No vegetation would be removed as a result of the project. WILDLIFE Federally and State Listed Candidate, Threatened, Endangered, and Species of Concern Sage -grouse are highly dependent on sagebrush dominated habitats on the Roan Plateau. The quality and quantity of this habitat type dictates its suitability for sage -grouse. Disturbance to sagebrush shrublands that reduces the availability and suitability of presently occupied habitat would affect this species. Due to previous development on the site it is unlikely that sage -grouse would be adversely affected by the project during the breeding or brood rearing season. WestWater Engineering Page 6 of 15 November 2012 There is the potential for the northern pocket gopher and sensitive species of bats to become trapped in the pond in the absence of adequate mitigation measures; however, Marathon currently has in place a CPW approved wildlife fence to prevent animals from entering the pond. Raptors No nest sites are located where removal of the nest tree is a concern, and no occupied raptor nests have been identified within 0.25 -miles of the site. Should a nest become occupied within 0.25 miles of the project site during the life of the facility, it could be indirectly affected by disturbances associated with operation and maintenance of the site. Indirect disturbances to nest sites are often mitigated when vegetation or terrain features are present to screen the nest from direct line of sight or when development takes place outside of nesting seasons. Migratory, Non -migratory and Birds of Conservation Concern (other than raptors) No additional sagebrush dominated shrublands would be lost that are important for Brewer's Sparrows. There is currently a CPW approved wildlife net covering the produced water pond to prevent birds from entering. American Elk and Mule Deer There is the potential for elk and deer to become trapped in the pond in the absence of adequate mitigation measures; however, Marathon currently has in place a CPW approved wildlife fence to prevent animals from entering the pond. There is also the potential for temporary disturbance associated with human presence and equipment operation. This disturbance may add stress to these species during critical times of the year, such as fawning and calving, and may also cause avoidance of the area. Black Bear and Mountain Lion No additional vegetation will be lost in habitats that are crucial for black bear or mountain lion. Indirect effects from operation and maintenance of the project site should not impact either species. Potential encounters of black bear with personnel could potentially occur if garbage or food is available to resident bears. Incidences with human -black bear interactions sometimes result in the euthanasia of offending bears by the CPW. Small Mammals, Birds (BCC), Amphibians, and Reptiles There is the potential for animals to become trapped in the pond in the absence of adequate mitigation measures; however, Marathon currently has CPW approved fencing and netting in place to prevent wildlife from entering the pond. Effects of habitat loss to these species are expected to be negligible due to previous development of the site and the large amount of habitat available in the surrounding area. Mitigation Recommendations WILDLIFE In order to reduce impacts to wildlife species Marathon has implemented a CPW approved wildlife mitigation plan (C -K Associates, 2010). The wildlife mitigation plan outlines protection measures and Best Management Practices that will be implemented to reduce impacts for each project within the Piceance Basin. WestWater Engineering Page 7 of 15 November 2012 Raptors Operation and maintenance activities associated with the project have minimal potential to impact raptor populations as no nesting was observed 0.25 miles of the site in 2012. If additional disturbance is planned at a future date during a subsequent nesting season, the site should be re - inventoried by qualified biologists. If any raptors are found behaving in a manner consistent with nesting, every effort should be made to apply timing limitation and buffer distance stipulations. WWE recommends temporal and spatial restrictions for activities near active nests (Table 5) based on BLM stipulations (BLM 1997), Colorado Parks and Wildlife (CPW) recommendations (Craig 2002 and Klute 2008) and literature review of nesting season timing for raptors in the Roan Plateau region (Andrews and Righter 1992, and Kingery 1998). Table 5. Timing and buffer recommendations for active rautor nests Species Buffer Zone Seasonal Restriction American Kestrel * * Bald Eagle 0.50 mile 15 October — 31 July Burrowing Owl 150 feet 15 March — 31 October Cooper's Hawk 0.25 mile 1 April — 15 August Ferruginous Hawk 0.50 mile 1 Feb — 15 July Flammulated Owl 0.25 mile 1 April —1 August Golden Eagle 0.50 mile 15 December — 15 July Great Horned Owl * * Long-eared Owl 0.25 mile 1 March - 15 July Northern Goshawk 0.50 mile 1 March —15 September Northern Harrier 0.25 mile 1 April — 15 August Northern Saw -whet Owl 0.25 mile 1 March —15 July Osprey 0.25 mile 1 April — 31 August Peregrine Falcon 0.5 mile 15 March — 31 July Prairie Falcon 0.5 mile 15 March —15 July Red-tailed Hawk 0.33 mile 15 February - 15 July Sharp -shinned Hawk 0.25 mile 1 April — 15 August Swainson's Hawk 0.25 mile 1 April - 15 July * Great Horned Owls and Kestrels are relatively tolerant of human activity. Keep activity to a minimum during breeding season. Greater Sage -grouse In order to reduce the likelihood that sage -grouse populations decline near the project area, effective pre -development planning and post -development practices offer the best prospect for mitigating adverse effects to sage -grouse populations. Planning development with projects engineered to avoid, minimize, and mitigate effects of development results in the most favorable mitigation outcome. Marathon has prepared a CPW approved wildlife mitigation plan which specifies protection measures for sage -grouse (C -K Associates, 2010). Due to protection measures outlined in the wildlife mitigation plan and previous development on the site it is unlikely that sage -grouse would be adversely affected by the project during the breeding or brood rearing season. WestWater Engineering Page 8 of 15 November 2012 American Elk and Mule Deer The eight -foot woven wire fence surrounding the facility excludes virtually all large mammals from entering the site, and should be inspected and maintained regularly to ensure serviceability. The site is located near an elk production area (NDIS 2012). Disturbance effects to mule deer and elk are expected to be minimal because of previous and current development and the amount of human activity that has been occurring in the vicinity for the past several years. Black Bear Black bear are unlikely to be found on the site unless there is some food -related attraction (trash). All garbage and any food items should be removed from the site on a daily basis. Personnel should not feed bears at any time. Bears should not be approached if encountered in the project area. BCC and Other Migratory Birds There is currently Colorado Parks and Wildlife approved bird netting in place at the pond site to prevent birds from entering the pond. Nesting season is generally considered to occur between May 1 and July 31 for most species in this area. June 1 to July 15 is the peak period when most incubation and brood rearing takes place. Small Mammals, Reptiles, and Aquatic Wildlife There is currently CPW approved wildlife net across the pond to prevent wildlife from entering. There are no seasonal restrictions or special requirements for development related to these species. PRESERVATION OF NATIVE VEGETATION The best method to mitigate loss of wildlife habitat is to increase the availability of native forage in the form of grasses and shrubs. The development and application of an integrated vegetation and noxious weed management plan and implementation of a reclamation plan in areas of disturbance would provide the basis for appropriate mitigation. Treatment and Control of Noxious Weed Infestations Noxious weeds aggressively compete with native vegetation. Most have come from Europe or Asia, either accidentally or as ornamentals that have escaped. Once established they tend to spread quickly because the insects, diseases, and animals that normally control them are absent. Prevention is especially valuable in the case of noxious weed management. Noxious weeds are spread by man, animals, water, and wind. Prime locations for the establishment of noxious weeds include roadsides, construction sites, wetlands, riparian corridors, and areas that are overused by animals or humans. Subsequent to soil disturbances, vegetation communities can be susceptible to infestations of invasive or exotic weed species. Vegetation removal and soil disturbance during construction can create optimal conditions for WestWater Engineering Page 9 of 15 November 2012 the establishment of invasive, non-native species. Construction equipment traveling from weed - infested areas into weed -free areas could disperse noxious or invasive weed seeds and propagates, resulting in the establishment of these weeds in previously weed -free areas. Several simple practices should be employed to prevent most weed infestations. The following practices should be adopted for any activity to reduce the costs of noxious weed control through prevention. The practices include: Prior to delivery to the site, equipment should be thoroughly cleaned of soils remaining from previous construction sites which may be contaminated with noxious weeds. If working in sites with weed -seed contaminated soil, equipment should be cleaned of potentially seed -bearing soils and vegetative debris at the infested area prior to moving to uncontaminated terrain. All maintenance vehicles should be regularly cleaned of soil. Avoid driving vehicles through areas where weed infestations exist. REFERENCES Andrews, R., and R. Righter. 1992. Colorado Birds: A Reference to Their Distribution and Habitat. Denver Museum of Natural History, Colorado. BLM. 1997. Record of Decision and Approved White River Resource Area, Resource Management Plan. United States Bureau of Land Management, Meeker, CO. CDOW. 2008. Colorado Greater Sage -grouse Steering Committee: Colorado Greater Sage - grouse Conservation Plan. Colorado Division of Wildlife. Denver. C -K Associates. 2010. Marathon Oil Company, Wildlife Mitigation Plan. C -K Associates LLC. Craig, Gerald R. 2002. Recommended Buffer Zones and Seasonal Restrictions for Colorado Raptors. Colorado Division of Wildlife, Denver. Fitzgerald, James P., C. A. Meaney, D. M. Armstrong, 2011. Mammals of Colorado. Univ. Press of Colorado, Niwot. Hammerson, G. A. 1999. Amphibians and Reptiles in Colorado, Second Edition. Colorado Division of Wildlife, Denver. Kingery, H. E. 1998. Colorado Breeding Bird Atlas. Colorado Bird Atlas Partnership, Colorado Division of Wildlife, Denver. Klute, D. 2008. Recommended Buffer Zones and Seasonal Restrictions for Colorado Raptors. Colorado Division of Wildlife, Denver. NDIS. 2012. Natural Diversity Information Source—Colorado Division of Wildlife. http://ndis.nrel.colostate.edu/wildlife.asp. Accessed October 31, 2012. Righter, R., R. Levad, C. Dexter, and K. Potter. 2004. Birds of Western Colorado Plateau and Mesa Country. Grand Valley Audubon Society, Grand Junction, Colorado. Spackman, S , B. Jennings, J. Coles, C. Dawson, M. Minton, A. Kratz, and C. Spurrier. 1997. Colorado Rare Plant Field Guide. Prepared for the U.S. Bureau of Land Management, the U.S. Forest Service and the U.S. Fish and Wildlife Service by the Colorado Natural Heritage Program. USFWS. 1994. Endangered and Threatened Wildlife and Plants; Determination of Critical Habitat for the Colorado River Endangered Fishes; Razorback Sucker, Colorado Squawfish, WestWater Engineering Page 10 of 15 November 2012 Humpback Chub, and Bonytail Chub. Federal Register Rules and Regulations, Vol. 59, No. 54, March 21, 1994. USFWS. 2008. Birds of Conservation Concern 2008. U.S. Fish and Wildlife Service, Division of Migratory Bird Management, Arlington, Virginia. USDI, USFWS. 2012. Endangered, Threatened, Proposed and Candidate Species, Colorado Counties. U.S. Fish and Wildlife Service. Denver, Colorado, available online at: http://www. fws. gov/mountain-prairie/endspp/CountyLists/Colorado.pdf WWE. 2009. Marathon Oil Company & Berry Petroleum, House Log Gulch Water Impoundment Facility, Wildlife Assessment and Mitigation. WestWater Engineering, Grand Junction, CO. WWE. 2012. Marathon Oil Company, Raptor and Greater Sage -grouse Survey, Piceance Basin Leases, Colorado 2012. WestWater Engineering, Grand Junction, CO. WestWater Engineering Page 11 of 15 November 2012 ` 1 Project Location GARFIELD COUNTY PAR4CHUTE, Legend / _ MI 32 C Pond 1 BLM �^�, WestWater Engineering Page 12 of 15 I s Figure 1 Marathon 32 C Pad Biological Survey Location \NestWater Engineering Consulting Engineers & Scientists Q 250 503 refers Nlove u ber 2012 Map Source .2 P.C ortIleran Compliance @NCB ME GARFIELD r? COUNTY - 32 C Pond Greater Sage -grouse Production Area Greater Sage -grouse 0.6 Mile Lek Buffer Greater Sage -grouse 4 Mile Nest Buffer BLM WestWater Legend o •e eran Figure 2 Marathon 32 C Pad Biological Survey Sage -grouse Activities , WestWater Engineering Consulting Engineers & Scientists 2 Boo 1,200 Meters "ember 20vember 2012 h om pliance Service (Olsson Assoc rAilararhonl32c Pad.GIS'•Figure 2 rroca 11113.76T2 r65 Project Location PARACHUTE Legend ® 32 C Pond Occupied Raptor Nest I BLM Figure 3 Marathon 32 C Pad Biological Survey Raptors In` WestWater Engineering Consulting Engineers & Scientists 250 500 ap DU r£ rd i gran p lance ru w.el�. ssor. Assoc l\ Aral on•. gure .ma. 11.: - 1 ma Legend Fie 32 C Pond 1 EIk ProductionBLM Area Figure 4 Marathon 32 C Pad Biological Survey Big Game Activities eta\NestWater Engineering -Tr; Consulting Engineers & Scientists GOO 1,200 AID puree. 1 ordilleran 0m0Itance erelc@fe ssors Assocr. 1 .1 11.i2012 rbk. M"C/WMP MiT1GATDO1I ASSESSMENT BY CDOW NW REGION (March 16, 2010) Introduction Since late 2008, Marathon 00 Company (MOC) and The Colorado Division of Wildlife (CDOWl have met numerous times with the intent to prepare a Wildlife Mitigation Plan Me purpose of th. WMP Mitigation Assessment is to document agreements for compensatory mitigation of wildlife resources associated with the MOC WMP. This project area within this WMP is located within Garfield County, Colorado. A GIS analysis was performed using shape files provided by MOC to CDOW. The MOC WMP boundary was agreed upon between CROW andl MOC and includes 20,261 acres of land (fee surface and minerals) that lies north of the Colorado River and Interstate 70 near Parachute, Colorado. Marathon leases cover 8,366 acres within the WMP boundary. MOC also applied a GIS analysis to assess compensatory mitigation acres. The MOC GIS process represented modifications to the CDOW process. Each GIS process used different input variables, which resulted in similar compensatory mitigation acres. Based an the marginal difference between the compensatory mitigation acres both MOC and CDOW were able to agree to the figures presented below. During the initial discussions on this WMP, the CROW Regional Team suggested several potential mitigation projects to mitigate wildlife impacts within MOC WMP project area, including: • Contribution to CDOW's Piceance Project Research. • Grazing management on ir9O( grid other private land,. • Conservation easement on the MOC private lands. • Habitat improvements on MOC, l3LM and other private property. • Riparian improvements on private lands. Background on MOC Piceanc+e Basin 0ll and Gas Development Within the MOC WMP boundary there are 36 proposed well pads, and 18 existing well pads that will be reoccupied and are planned to have additional drilling associated with them. The WMP boundary includes a greater sage -grouse leks, golden eagle active nest site, and peregrine falcon active nest site Restricted Surface Occupancy (RSO) areas, and greaser _s ge-groused production area, mule deer critical winter range, elk winter concentration area, and elk production area Sensitive Wildlife Habitat (SWH) areas (collectively Sensitive Wildlife (Habitat Areas (SWHAs)), as described by the COGCC 1200 Series Rules. The prospective life of this WIMP is 6 years. CDOW Position for Compensatory Mitigatiorn in order to equitably assess mitigation associated with WMP, CDOW entered into discussions with MOC to assess compensatory mitigation acreage as well as compensatory mitigation credits. The density of well pads in this area exceeds 10 well pads per 10 -square mile area, (i.e., one well pad per section), throughout the WMP area. CDOW, supported by the peer reviewed literature, concludes that as the density of oil and gas facilities increase beyond this one pad/section threshold, the resulting direct and indirect impacts adversely affect wildlife species to a greater extent than can be offset with avoidance and minimization measures (i.e. traditional BMPs) alone. Therefore, compensatory mitigation acreage is assessed to account for the habitat loss and disturbance associated with construction, drilling, completion, and production of oil rod gas development. Compensatory iViltlgation Acreage The acreage of compensatory mitie _ tion is equal to the amount of I3 , is surface that will be directly affected by proposed future disturbance in SWHAs plus the additional indirectly affected acreage surrounding existing well pads planned for reoccupation and future proposed infrastructure on which habitat functions are impaired by noise, actrvities and other disturbance effects. Compensatory mitigation is calculated from the development scenario proposed by MOC. Surface disturbances include well pads that are not hilly drilled or interim reclaimed where additional development will occur during the life of the WMP were all included when calculating compensatory mitigation acreage. MOC-Specific GIS Analysis for the WMP CDOW applied the following impact analysis to the MOC WMP: The direct impacts from future proposed Infrastructure is calculated within the SWHAs and RSOs and equals a total of 347 acres. The indirect impact compensatory mitigation acreage from proposed infrastructure equaled a total of 4,020 acres. The indirect irnpacts from existing infrastructure include a total of 2,798 acres. The total compensatory mitigation acreage for the MOC WMP k 7,165 acres. MOC also developed and applied a process using GIS to assess compensatory mitigation acreage. The MOC GIS methodology represented modifications to our process. Each GIS process resulted in similar results using different input variables_ Asa resuh, MOC and CDOW agreed upon the compensatory mitigation acreage. Compensatory Mitigation and Credit ,Application Specific to MOC's WMP MOC Best Management Practices (8MPs) Certain BMPs are particularly effective at avoiding and/or minimizing the indirect impacts from oil and gas development on a landscape scale. These mitigative i9MPs are a limited subset of the normal list considered the list of BMPs that are often reflected within permit conditions of approval. MOC indicated to the CDOW WMP team that six of these mitigative BMPs are currently Implemented in the field. Specifically for this MOC WMP, these BMPs include SCADA (or remote well monitoring), closed loopjpit less drilling, liquids distribL,tion pipelines, and use of high efficiency rigs. The following reductions in overall compensatory mitigation acreage were applied as credits toward offsetting indirect impacts by CDOW across the MOC WMP area: ▪ SCADA - 12% • Voluntary timing - 3% • Man Camps - 3% e Liquids Distrit te n - 40% • High Efficiency Rigs - 25% 4 Closed Loop Drilling - 2% The total reduction in compensatory mitigation acreage from indirect impacts through mitigative BIVIPs amounts to 85% or a reduction in the total indirect impact acreage= from 6,818 acres to 1,370 acres (a credit of 5,795 acres resulting from mitigative 8MP implementation). MOC Historical Servkeberry Treatments MOC provided shape files to CDOW of historical servir;- r ra treatments that were performed to improve boat. r Trie total acreage of these treatments was 22 acres. CDOW values this work at a 1 multiplier therefore the credit for this project is 22 acres. This reduces the compensatory mitigation acreage to 1,348 acres, CDOW Piceance Project Research Contribution On February 18, 2010, MOC agreed to contribute $300,000 towards the CDOW Piceance Project Research. CDOW assesses the acre equivalent for this project contribution at 5500 per acre, and then applies a multiplier of 3 to obtain the compensatory mitigation acreage credit, This project would help contribute to the understanding of mule deer and greater sage -grouse species and habitats within the Piceance Basin of Western Colorado. The end result is 1,800 acres of compensatory mitigation credit that could be applied toward the compensatory mitigation acreage. The combination of the implementation of the mitigative BMPs, the serviceberry treatments, and the contribution to CDOW would reduce the compensatory mitigation acreage to -452 acres MOC Raptor Monitoring MOC will conduct diurnal raptor surveys to focus on (1) existing and proposed pads within and in proximity relative to established leks, (2) to confirm raptor nest locations within the project area, and (3) other identified priority areas. The objective would be to establish species, counts and location within set boundaries. The surveys would be conducted annually. The approximate cost for six years is 5150,000. CDOW assesses the acre equivalent for this project at $500 per acre, and then applies a 2 multiplier to obtain the compensatory mitigation acreage credit. The end result is 600 acres of compensatory mitigation credit that could be applied toward the compensatory mitigation acreage. This would reduce the compensatory mitigation acreage to -1,052 acres. Land Cover Analysis IVIOC will conduct land cover analysis. The analysis was initiated in 2008 and included infrared/true color 1 meter satellite image. The surveys and analysis will include: Satellite imagery to detect surface changes (2010, 2012, and 2014). Includes established vegetation pleats (spreadsheet w/ grasses, fobs, shrubs) for indicator species. Includes vegetation plot photos for initial visual indicators. Includes indicator polygons -G15 tools. Establish modified land cover classification (aspen, oak, sage, other) Land cover change detection analysis (analysis only to he conducted on Marathon lease). - GIS data sets to be shared with CDOW. CDOW will be provided a copy of imagery with shape files. The approximate cost for five years is $115,000. CDOW assesses the acre equivalent for this project at $500 per acre, and then applies a multiplier of 1 to obtain the compensatory mitigation acreage credit. The end result is 230 acres of compensatory mitigation credit that could be applied toward the compensatory mitigation acreage. This would reduce the compensatory mitigation acreage to -1,282 acres. Final Compensatory Mitigation Acreage and Credit Assessment If compensatory mitigation actions were applied as described above, this would allow MOC to have 1,282 acres of compensatory mitigation acre credits that could be applied toward future development projects. Therefore, the balance due to CDOW from MOC would be zero, assuming the compensatory BMPs were implemented as indicated by MOC in accordance with this agreement arranged between CDOW and MOC through the WMP negotiations. Conclusion and Annual WMP Project IReview The MOC mitigation commitment is conditional and assumes MOC will continue to operate (drilling. completion, construction, etc.) within the WMP boundary. However, all parties agree to maintain adaptability to future project schedules and modifications if parties are all in agreement. CDOW assumes that any mitigation credit given for BMPs that are not implemented by MOC as described above will be reevaluated and reassigned to other compensatory mitigation projects within the context of this WMP. Any future development that is proposed and that is not described within this WMP at the time of acceptance, as well as the application of the 1,282 acres of mitigation credits remaining will be annually evaluated with the CDOW during a MOC/CDOW WMP review meeting (or sooner if necessary) for the duration of the WMP. The first annual WMP Review meeting with the CDOW will be held within six (F) months of the WMP approval date. The protect schedule, development status, and implementation of compensatory mitigation projects will be discussed during these meetings. MOC will be responsible for providing contractors to perform the raptor monitoring and the land cover analysis and will be responsible for their r.ompensation. Subsequent to the initial meeting that follows the WMP approval, all annual meetings will include a review of the BMPs implemented, cornpensatury mitigation measures undertaken, status of oil and gas development, and an assessment of the compensatory mitigation acreage incurred and the credit balance remaining. Updates to the operations maps and shape files will be provided by MOC to CDOW at the annual meetings to maintain currency of the GIS analysis. Modifications or reprioritizations of the mitigation opportunities/ projects as outlined in this mitigation assessment will be performed and evaluated during these reviews. if MOC and the CDOW collectively determine necessary, amendment(s) to the WMP document will be made to reflect mitigation agreement modifications. Attachments to this Mitigation Assessment include the WMP settlement proposal and PAPS provided by MOC. Nothing in this agreement shall preclude the operator from voluntarily undertaking enhanced mitigation measures and receiving appropriate credit for such enhanced measures. The principles in this agreement are based on final acceptance of the WMP by all parties. This agreement waives CDOW consultation for Form 2A permits within this WMP proposed by MOC and CDOW agrees to process permits in an expedient manner (e.g., 72 -hour turnaround time). Conditions of Api.r.wal attached to this agreement shall be applied to all Form 2As associated with this WMP which are submitted by MOC to the Colorado Oil and Gas Conservation Commission, This agreement is transferrable to another operator upon agreement with CDOW. By: M..1.Suek Plceance Operations Manager Marathon Oil Company 7-2 A dy. , Date: OS— I6 — /O Date: r '— f> Ron D. Velarde CDOW NW Regional Manager Air Quality Permit Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 STATE OF COLORADO COLORADO DEPARTMENT OF PUBLIC HEALTH AND ENVIRONMENT AIR POLLUTION CONTROL DIVISION TELEPHONE: (303) 692-3150 CONSTRUCTION PERMIT PERMIT NO DATE ISSUED: ISSUED TO: 09GA0337 SEP 1 1 7012 Marathon 011 Company Issuance 1 THE SOURCE TO WHICH THIS PERMIT APPLIES IS DESCRIBED AND LOCATED AS FOLLOWS A wastewater management facility designed to accept produced water and flowback water located in Section 32, Township 5 South. Range 96 West, in Garfield County. Colorado THE SPECIFIC EQUIPMENT OR ACTIVITY SUBJECT TO THIS PERMIT INCLUDES THE FOLLOWING: Facility AIRS Equipment ID Point Description Wastewater Ponds Wastewater evaporation/storage ponds The wastewater passes 001 through an enclosed gun barrel separator tank prior to dLscharge into the ponds. THIS PERMIT IS GRANTED SUBJECT TO ALL RULES AND REGULATIONS OF THE COLORADO AIR QUALITY CONTROL COMMISSION AND THE COLORADO AIR POLLUTION PREVENTION AND CONTROL ACT C.R.S. (25-7-101 et seg), TO THOSE GENERAL TERMS AND CONDITIONS INCLUDED IN THIS DOCUMENT AND THE FOLLOWING SPECIFIC TERMS AND CONDITIONS. REQUIREMENTS TO SELF -CERTIFY FOR FINAL AUTHORIZATION YOU MUST notify the APCD no later than fifteen days after commencement of the permitted operation or activity by submitting a Notice of Startup (NC'S) form to the APCD. The Notice cf Startup (NOS) form may be downloaded online at cdche state co lunar, Jownloadforms.ntro!, Failure to notify the APCD of startup of the permitted source is a violation of AQCC Regulation No. 3, Part B, Section III.G.1 and can result in the revocation of the permit. 2 Within one hundred and eighty days (180) after issuance of this permit, compliance with the conditions contained on this permit shall be demonstrated to the Division It is the permittee's responsibility to self -certify compliance with the conditions. Failure to demonstrate compliance within 180 days may result in revocation of the permit (Reference Regulation No. 3, Part B, III G 2) ? This permit shall expire if the owner or operator of the source for which this permit was issued. (i) does not commence construction/modification or operation of this source within 18 months after either, the date of issuance of this construction pel-mit or the date on which such construction or activity was scheduled to commence as set forth in the permit application associated with this permit; (ii) discontinues construction for a period AIRS la 045/1741/001 Page 1 of 9 Marathon Oil Company Permit No, 090A0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution. Control Division of eighteen months or more; (iii) does not complete construction within a reasonable time of the estimated completion date. The Division may grant extensions of the deadline per Regulation No. 3, Part B, IPI.F.4.b. (Reference: Regulation No. 3, Part 8, III.F.4.) 4. The operator shall complete all initial compliance testing and sampling as required in this permit and submit the results to the Division as part of the self -certification process. (Reference: Regulation No. 3, Part B, Section I11.E.) 5 Within one hundred and eighty days (180) after issuance of this permit, the operator shall submit to the Division for approval an operating and maintenance plan for the evaporation ponds, RACT control equipment and control practices, and a proposed record keeping format that will outline how the applicant will maintain compliance on an ongoing basis with the requirements of this permit. Compliance with the operating and maintenance plan shall be implemented upon issuance of this permit. Additionally, the O&M Plan ultimately approved by the Division shall be implemented by the operator upon receipt of approval. (Reference: Regulation No. 3, Part B, Section III G.T.) The operator shall retain the permit final authorization letter issued by the Division after completion of self -certification, with the most current construction permit. This construction permit alone does not provide final authority for the operation of this source. EMISSION LIMITATIONS AND RECORDS 7 Emissions of air pollutants shall not exceed the following limitations (as calculated in the Division's preliminary analysis) (Reference: Regulation No. 3, Part B, Section H A.4) Quarterly Limits'': Facility Equipment ID AIRS Point VOC Limit Pounds per Quarter Emission Type Wastewater Ponds 001 30,801 Fugitive 1. Quarterly limits will be established beg'nning with the calendar month of permit issuance. 2: Note that quarterly limits are based on a 92 -day quarter Facility -wide emissions of each individual hazardous air pollutant shall be less than 4,644 Ib./quarter. Facility -wide emissions of total hazardous air pollutants shall be less than 10,082 Ib/quarter Annual Limits: Facility Equipment ID AIRS Point VOC Limit Tons per Year Emission Type Wastewater Ponds 001 61.1 Fugitive See "Notes to Permit Holder #4 for Information on emission factors and methods used to calculate limits. Facility -wide emissions of each individual hazardous air pollutant shall be less than 9.2 tpy. Facility -wide emissions of total hazardous air pollutants shall be less than 20.0 tpy. AIRS ID 045/1741/001 Page 2 of 9 Marathon Oil Company Permit No. 09GA0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division During the first twelve (12) months of operation, compliance with both the quarterly and annual emission limitations shall be required. After the first twelve (12) months of operation, compliance with only the annual limitation shall be required. Compliance with the annual limits shall be determined by recording the facility's annual criteria pollutant emissions, (including all HAPs above the de-minimis reporting level) from each emission unit, on a rolling twelve (12) month total. By the end of each month a new twelve-month total shall be calculated based on the previous twelve months' data. The permit holder shall calculate emissions each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. This rolling twelve-month total shall apply to all permitted emission units, requiring an APEN, at this facility_ The owner or operator shall track emissions from all insignificant activities at the facility on an annual basis to demonstrate compliance with the facility emission limitations as seen below. An inventory of each insignificant activity and associated emission calculations shall be made available to the Division for inspection upon request. For the purposes of this condition, insignificant activities shall be defined as any activity or equipment, which emits any amount but does not require an Air Pollutant Emission Notice (APEN). Total emissions from the facility, including permitted emissions and insignificant activities, shall not exceed: • 10 tons per year of a single hazardous air pollutant and/or • 25 tons per year of total hazardous air pollutants (HAP). PROCESS LIMITATIONS AND RECORDS 9 This source shall be limited to the following maximum throughput rates as listed below. Monthly records of the actual processing rates shall be maintained by the owner or operator and made available to the Division for inspection upon request. (Reference: Regulation 3, Part B, II.A.4) Process/Consumption Limits: Facility Equipment ID AIRS Point Process Parameter Annual LimitL'rrnit''2 Quarterly Wastewater Ponds 001 Throughput of wastewater 50(},000 BBL/yr 126,027 BBL/quarter 1 Quarterly limits will be established beginning with the calendar month of permit issuance. 2. Note that quarterly limits are based on a 92 -day quarter. During the first twelve (12) months of operation, compliance with both the quarterly and annual throughput limitations shall be required. After the first twelve (12) months of operation, compliance with only the annual limitation shall be required. Compliance with the annual throughput limits shall be determined on a rolling twelve (12) month total. By the end of each month a new twelve-month total is calculated based on the previous twelve months' data. The permit holder shall record monthly throughput rates each month and keep a compliance record on site or at a local field office with site responsibility, for Division review. AIRS ID 045/1741/001 Page 3 of 9 Marathon 011 Company Permit No. 09GA0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division STATE REGULATORY REQUIREMENTS The permit number and AIRS ID number shall be marked on the subject equipment for ease of identification. (Reference: Regulation Number 3, Part B, III.E ) (State only enforceable). 11 This source is subject to the odor requirements of Regulation No. 2. (State only enforceable) 12 The operator shall calculate emissions for AIRS Point 001 on a monthly basis using a mass balance approach based on the most recent monthly wastewater pollutant concentration data and volume of wastewater as required by Conditions 13 and 18. For the first twelve (12) months of operation, monthly emissions from the three calendar months of a quarter shall be summed to demonstrate compliance with the quarterly emission limits in Condition 7 for AIRS Point 001 as well as the annual limitations. After the first twelve (12) months of operation, the operator shall calculate monthly emissions to demonstrate compliance with the annual limits in Condition 7 and to maintain the 12 - month roiling total. Compliance with the VOC emission limit shall be determined by summing total hydrocarbons (including gasoline range plus diesel range) plus methanol. 13 The operator shall continuously monitor and record the volumetric flow of wastewater discharged into the pond system by using a flowmeter. The flowmeter shall continuously measure flow and record total volumetric flow discharged to the pond system. For the first twelve (12) months of operation, monthly wastewater flow from the three calendar months of a quarter shall be summed to demonstrate compliance with the quarterly limits in Condition 9 for AIRS Point 001. After the first twelve (12) months of operation, the operator shall use monthly throughput records to demonstrate compliance with the annual limits in Condition 9 and to maintain the 12 -month rolling total. This monthly flow volume shall also be used to calculate emissions as described above in Condition 12. 14 This source is subject to the Reasonably Available Control Technology (RACT) requirements of Regulation No. 7, Section V_ RACT for this source includes installation and operation of an enclosed gun barrel separator tank. All wastewater shall be routed through the enclosed gun barrel separator tank prior to discharge into the pond(s). 15. The operator shall maintain the ponds such that neither an oil film layer ror an oil sheen exist on the surface. The methods utilized to maintain the pond surfaces such that an oil film layer/oil sheen does not exist shall be included in the operating and maintenance plan. OPERATING & MAINTENANCE PLAN REQUIREMENTS 16 The applicant shall follow the most current operating and maintenance plan and record keeping format approved by the Division in order to demonstrate compliance on an ongoing basis with the requirements of this permit. Revisions to your O&M plan are subject to Division approval prior to implementation. (Reference: Regulation No. 3, Part B, Section III G.7. ) COMPLIANCE TESTING AND SAMPLING Initial Compliance Testing and Sampling Requirements AIRS Point 001: The operator shall complete the initial wastewater sampling as required by this permit in Condition 18 and submit the results to the Division as part of AIRS ID 045/1741/001 Page 4 of 9 Marathon 011 Company Permit No O9CA0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division the self -certification process to demonstrate compliance with emission limits. (Reference Regulation No. 3; Part B, Section til E ) Periodic Testing Requirements 18 AIRS Point 001: The operator shall sample the wastewater inlet to the pond system for the gun barrel separator tank wastewater outlet) to determine volatile organic compounds (VOC) and hazardous air pollutant (HAPi concentrations, including total hydrocarbons (including gasoline range and diesel range) benzene, toluene, ethylbenzene xylene and methanol These samples shall be analyzed using EPA Method 8260 for benzene, toluene, ethylbenzene, and xylene, and EPA Method 8015 for methanol, gasoline range organics (total volatile hydrocarbons), and diesel range organics (total extractable hydrocarbons) A sample of the wastewater inlet to the pond system (or the gun barrel separator tank wastewater outlet) shall be collected and analyzed at a minimum frequency of once per calendar month. Sample results shall be used to calculate emissions as required by Condition 12. 1f more frequent sampling is conducted, then all samptes of the wastewater inlet to the pond collected during the calendar month will be averaged and then used to calculate emissions as specified in Condition 12. Samples shall be collected no less than at least seven (7) days apart. The operator shall maintain records of all sampling events and the records shall be made available to the Division for inspection upon request. The operator shall flag monthly records if any sampling results are noted by the laboratory as beyond QA/QC criteria limits. ADDITIONAL REQUIREMENTS 9 A revised Air Pollutant Emission Notice (APEN) shall be Bled. (Referen:e. Regulation No 3. Part A, it C) a Annually whenever a significant increase in emissions occurs as follows - For any criteria pollutant: For sources emitting Bess than 100 tons per year, a change in actual emissions of five (5) tons per year or more, above the level reported on the last APEN, or For any non -criteria reportable pollutant: if the emissions increase by 50% or five (5) tons per year whichever is less above the level reported on the last APEN submitted to the Division o Whenever there is a change in the owner or operator of any face:ity, process. or activity', or c Whenever new control equipment is installed, or whenever a different type of control equipment replaces an existing type of control equipment; or d Whenever a permit limitation must be modified: or e. No later than 30 days before the existing APEN expires Federal regulatory program requirements (i.e. PSD, NANSR or Title V Operating Permit) shall apply to this source at any such time that this source becomes major solely by virtue of a relaxation in any permit condition Any relaxation that increases the potential to emit above the applicable Federal program threshold will require a full review of the AIRS ID: 045/17411001 Page 5 of 9 Marathon Oil Company Permit No. 09GA0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division source as though construction had not yet commenced on the source. The source shall not exceed the Federal program threshold until a permit is granted. (Regulation No. 3 Part D). GENERAL TERMS AND CONDITIONS: '1 This permit and any attachments must be retained and made available for inspection upon request. The permit may be reissued to a new owner by the APCD as provided in AQCC Regulation No. 3, Part B, Section II,B upon a request for transfer of ownership and the submittal of a revised APEN and the required fee 22 if this permit specifically states that final authorization has been granted, then the remainder of this condition is not applicable. Otherwise. the issuance of this construction permit does not provide "final" authority for this activity or operation of this source. Final authorization of the permit must be secured from the APCD in writing in accordance with the provisions of 25-7-114.5(12)(a) C.R.S. and AQCC Regulation No. 3, Part B, Section lII G. Final authorization cannot be granted until the operation or activity commences and has been verified by the APCD as conforming in all respects with the conditions of the permit. Once self -certification of all points has been reviewed and approved by the Division, it will provide written documentation of such final authorization Details for obtaining final authorization to operate are located in the Requirements to Self - Certify for Final Authorization section of this permit. 23. This permit is issued in reliance upon the accuracy and completeness of information supplied by the applicant and is conditioned upon conduct of the activity, or construction, installation and operation of the source, in accordance with this information and with representations made by the applicant or applicant's agents. It is valid only for the equipment and operations or activity specifically identified on the permit. Unless specifically stated otherwise, the general and specific conditions contained in this permit have been determined by the APCD to be necessary to assure compliance with the provisions of Section 25-7-114.5(7)(a), C.R.S. 25 Each and every condition of this permit is a material part hereof and is not severable Any challenge to or appeal of a condition hereof shall constitute a rejection of the entire permit and upon such occurrence, this permit shall be deemed denied ab initio. This permit may be revoked at any time prior to self -certification and final authorization by the Air Pollution Control Division (APCD) on grounds set forth in the Colorado Air Quality Control Act and regulations of the Air Quality Control Commission (AQCC), including failure to meet any express terra or condition of the permit. If the Division denies a permit, conditions imposed upon a permit are contested by the applicant, or the Division revokes a permit, the applicant or owner or operator of a source may request a hearing before the AQCC for review of the Division's action. 26 Section 25-7-114.7(2)(a), C.R.S. requires that all sources required to file an Air Pollution Emission Notice (APEN) must pay an annual fee to cover the costs of inspections and administration. if a source or activity is to be discontinued, the owner must notify the Division in writing requesting a cancellation of the permit. Upon notification, annual fee billing will terminate 27 Violation of the terms of a permit or of the provisions of the Colorado Air Pollution Prevention and Control Act or the regulations of the AQCC may result in administrative, .-A AIRS ID: 045/1741/001 Page 6 of 9 Marathon Oil Company Permit No, 09GA0337 issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division civil or criminal enforcement actions under Sections 25-7-115 (enforcement), -121 (injunctions), -122 (civil penalties), -122.1 (criminal penalties), C.R.S. By: Carissa Money Permit Engineer Permit History Issuance I Date Issuance 1 Description This issuance Issued to Marathon Oil Company AIRS ID: 045/1741/001 Page 7 of 9 Marathon Oil Company Permit No. 090A0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division Notes to Permit Holder- 1) The production or raw material processing limits and emission limits contained in this permit are based on the consumption rates requested in the permit application, These limits may be revised upon request of the permittee providing there is no exceedance of any specific emission control regulation or any ambient air quality standard. A revised air pollution emission notice (APEN) and application form must be submitted with a request for a permit revision. 2) This source is subject to the Common Provisions Regulation Part II, Subpart E, Affirmative Defense Provision for Excess Emissions During Malfunctions. The permittee shall notify the Division of any malfunction condition which causes a violation of any emission limit or limits stated in this permit as soon as possible. but no later than noon of the next working day, followed by written notice to the Division addressing all of the criteria set forth in Part 1I.E.1, of the Common Provisions Regulation, See: http://www.cdohe.state co. us/regulations/a i rregsl100102agcccom mon Prov is ionsreq, pdf. 3) The following emissions of non -criteria reportable air pollutants are estimated based upon the process limits as indicated in this permit. This information is listed to inform the operator of the Division's analysis of the specific compounds emitted if the source(s) operate at the permitted limitations. AIRS Point Pollutant CAS # BIN Uncontrolled Emission Rate (Ib/yr) Are the emissions reportable? Controlled Emission Rate (Ib/yr) 001 Benzene 71432 A 3,076 YES 2,461 Toluene 108883 C 6,004 YES 4,803 Ethylbenzene 100414 C 298 No 238 Xylene 1330207 C 5,090 YES 4,072 Methanol 67561 C 23,032 YES 18,425 4) The emission levels contained in this permit are based on the following emission factors Point 001: The emission levels contained an this permit are based on information provided in the application and a mass balance approach. For the wastewater ponds, actual emissions shall be calculated using mass balance and the most recent operational parameters, including wastewater throughput and contaminant concentrations at the inlet to the ponds (wastewater outlet of the Gun Barrel Separator Tank). VOC emissions are based on the sum of total hydrocarbons (gasoline range organics plus diesel range organics) plus methanol. 5) In accordance with C.R.S. 25-7-114.1, the Air Pollutant Emission Notice (APEN) associated with this permit is valid for a term of five years. The five-year term for this APEN expires on May 3, 2016. A revised APEN shall be submitted no later than 30 days before the five-year term expires. 6) This facility is classified as follows: Applicable Requirement Status Operating Permit True Minor Source: VOC Synthetic Minor Source: HAPs PSD True Minor for VOC AIRS ID: 045/17411001 Page 8 of 9 Marathon Gil Company Permit No. 09GA0337 Issuance 1 Colorado Department of Public Health and Environment Air Pollution Control Division 7) Full text of the Title 40, Protection of Environment Electronic Code of Federal Regulations can be found at the website fisted below: h ttp' IJecfr. g p oaccess. g ovi Part 60: Standards of Performance for New Stationary Sources NSPS 60.1 -End Subpart A — Subpart KKKK NSPS Part 60, Appendixes Appendix A — Appendix I Part 63: National Emission Standards for Hazardous Air Pollutants for Source Categories MACT 63.1-63.599 Subpart A — Subpart Z MACT 63.600-63.1199 Subpart AA —Subpart DDD MACT 63.1200-63.1439 Subpart EEE — Subpart PPP MACT 63.1440.63.6175 Subpart QQQ — Subpart YYYY MACT 63.6580-63.8830 Subpart 777Z — Subpart MMMMM MACT 63.8980 -End Subpart NNNNN — Subpart XXXXXX 8) An 0ii and Gas Industry Construction Permit Seff-Certification Form is included with this permit packet. Please use this form to complete the self -certification requirements as specified in the permit conditions Further guidance on self -certification can be found on our website at: http:Nwww cdphe state co usfaptoilgaspermitting.html AIRS ID: 045/1741/001 Page 9 of 9 Access and Roadways Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 O 32C Water Impoundment - CountyRoads022509 - Garden Gulch Road = Highways Garden Gulch Extension Road - Marathon 32C Access Road 0 0.5 1 2 Miles N 0 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 OkOLSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 FIGURE RA -1 Policy 04-01 Waivers for Roads and Demonstration of Compliance March 3, 2014 / Section 7-107, Access and Roadways, of the Garfield County Land Use and Development Code (LUDC) requires all roads to be designed to provide for "adequate and safe access" and reviewed by the designated County Engineer, The LUDC defines "road" as "a County road, State highway, public road, street or alley, or private thoroughfare which affords primary access to abutting property, excluding a driveway accessing a single property." The LUDC defines "private road" as "a right-of-way constructed, established, owned, and maintained by a private party for access exclusively to private property." Many of the roads in Garfield County are private roads in that they are gated and do not serve the general public and they pre-existed the design currently required by the County's Road Standards as defined in Table 7-107. The LDDC allows for the waiver of specific standards provided that the following criteria have been met: 1) an alternative design achieves the intent of the subject standard to the same or better degree and 2) the proposed alternative will impose no greater impacts on adjacent properties than would occur through compliance with the specific standard (Section 4-118). In applications that include roads that do not meet current County road standards as outlined in Table 7- 107, the County has asked that Applicants request a waiver of Section 7-107.F, Design Standards, and include in the Application submittal sufficient information, prepared by a professional qualified in the specific discipline, to demonstrate that they meet the criteria outlined in Section 4-118 for granting a waiver. In doing so, the application must include: A Statement of Adequacy - The evaluation of the existing roadway and waiver will need to include a clear statement that finds that the road will be adequate for the proposed use. This statement must be signed by a professional engineer qualified in traffic engineering and licensed by the State of Colorado. To support this evaluation, the following information will be required to be provided: o Geometry of the road — A description of how the private road does/does not meet the design standards in Table 7-107. This should include a chart that compares the private road design to those standards in Table 7-107, as well as a map that shows the existing road design and highlights those areas that deviate from the standards. A narrative may also be helpful in describing the characteristics of the road as they compare to Table 7- 107 design standards. Unless available, this is not intended to imply construction -level drawings. 1 i P a g e a Safety/Structural Issues — A description of obvious safety and/or structural issues observed and a statement about how these issues will be addressed. Maintenance — A description of how the road is and/or will be maintained. This should be supported with the submittal of any existing or proposed maintenance agreements for the road sections. o Travel Demand — An accurate count of the existing peak travel demand as well as the Average Daily Traffic on the road. This should also include the types of vehicles that currently use the road as well as the additional amount and type of traffic that the proposed use will generate through all phases of its development. Other Evidence of Compliance. In addition, Sections 7-107.A, 8, C, D, and E are required to be addressed, which includes documentation about legal access. Sufficient evidence will be required to be submitted to demonstrate compliance with these sections of the Code. 71Pag O\O LSSO N ASSOCIATES MARATHON OIL COMPANY 32C CENTRALIZED E & P WASTE FACILITY MARATHON LEASE ROAD ASSESSMENT Marathon Lease Road The Marathon Lease Road begins at the turn-off from the Garden Gulch Road Extension in the NW 1/4 of the NW 1/4 of Section 33, Township 5 South, Range 96 West of the 6th P.M. and terminates at the Marathon 32C facility in the E '/2 of the SW 1/4 of Section 32, Township 5 South, Range 96 West of the 6th P.M. This roadway is approximately 4,700 feet long and is typical of roads providing access to natural gas production facilities and Centralized E & P Waste facilities in Garfield County. The first approximately 3,500 feet of roadway is maintained by Berry Petroleum Company. The final approximately 1,200 feet of roadway is maintained by Marathon. This final road section is gated. Statement of Adequacy This lease road is typical of roadways providing access to natural gas production facilities in Garfield County. The road is adequate for the intended use. Geometry of Road The following table compares this access lease road to the Garfield County Roadway Standards found in Table 7-107 of the Land Use and Development Code for Primitive Roadways and Driveways. The actual driving surface is greater than 12 feet in width. This road does not have shoulders as described in the standards. Ditches are not located on both sides for the entire length of the 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Table 7-107: Roadway Standards Design Standards Design Capacity (ADT) Primitive/ Driveway Marathon Lease Road 0-20 <20 ADT Minimum ROW Width (Feet) 15 to 30 0 Lane Width (Feet) Single Lane 12 18- to 24.5' Shoulder Width (Feet) 0 0 Ditch Width (Feet) 3 0-3 Cross Slope 2% 0 to >2% Shoulder Slope n/a n/a Design Speed n/a n/a Minimum Radius (Feet) 40 >95' to 664' Maximum % Grade 12% 14.3% Surface Native Material Native Material The actual driving surface is greater than 12 feet in width. This road does not have shoulders as described in the standards. Ditches are not located on both sides for the entire length of the 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com Marathon 32C roadway. Berms are used in lieu of ditches in some locations. Cross slope varies from less than 2 percent to more than 2 percent. Shoulder slope and design speed is not a consideration for this type of road. Horizontal curve radii on this road exceed the 40 foot minimum and range between 95 feet and 664 feet. Maximum grade is approximately 14.3 +/- percent. The road is constructed of native material. Safety/Structural Issues Minor structural issues observed on the date of the field observation, April 9, 2014. Ruts due to spring weather conditions were present. Safety concerns were minimal as access to the site was available for the intended use. Maintenance The lease road is maintained by a subcontractor using equipment such as graders, backhoes and trucks. The road is inspected for compliance to each operator's SWMP on a monthly basis but can be limited by seasonal restrictions during the winter when the ground is frozen and covered by snow. Additional inspections can occur after major precipitation events. Inspection issues are corrected as needed. Travel Demand Average Daily Traffic (ADT) is expected to be less than twenty (20) as demonstrated in the Basic Traffic Analysis included with this submittal. This lease road is being assessed according to the standards for a Primitive Roadway/Driveway. The site is currently in operation as a water impoundment. There will be no additional construction associated with the facility. Other Evidence of Compliance Section 7-107 A. Access to Public Right -of -Way Access is granted from County Road 215 to the project site as part of the Road Construction and Maintenance Agreement between Marathon and Chevron and the other members of the road group and the Garden Gulch Road Extension Agreement. The lease road is not located within a right-of-way because it is on private land and is not a public road. General access is granted via the Garden Gulch Road Extension Agreement. Section 7-107 B. Safe Access Access to the site is consistent with industry standards for private roads for remote facilities that generate little traffic. The general public is restricted from travel on these roads by the guard shack near CR215 and posted signage. Section 7-107 C. Adequate Capacity Traffic congestion is not anticipated as a result of the proposed impoundment. The facility will generate only 2 trips a day. Section 7-107 D. Road Dedications The lease road is for private purposes. The road is not open to the public. No rights-of-way will be dedicated to the public. Marathon Lease Road Assessment Page 2 Marathon 32C Section 7-107 E. Impacts Mitigated The proposed facility reduces the need to transport water by trucks. Based on the expected trip generation rates discussed in the Basic Traffic Analysis, the increase in average daily traffic is not expected to increase on County roads. Conclusion The Lease Road deviates from the Design Standards in Table 7-107 for right-of-way, ditch width, cross -slope and grade. These deficiencies do not compromise the access to the site. The intent of the Right -of -Way width is to provide adequate legal public access for use and maintenance of the road. Marathon is extended access to the road through the Garden Gulch Extension Road Agreement. A recorded easement is not necessary as this is a private road with access granted via the mentioned agreement. This lease road is accessed via the Garden Gulch Road (GGR) and the Garden Gulch Road Extension (GGXR). These two roads are also private roads that are owned and operated by a group of natural gas operators which Marathon is a member in good standing. Access to these roads is restricted to authorized personnel. The bottom of the GGR has a guard shack and is posted to prohibit public use of the road. Consequently the public does not have access to the Marathon lease road. The intent of the ditch width is to facilitate proper drainage off the lease road while allowing vehicles to access the site. A ditch is typically located on the up-slope side of the lease road and a small berm is typically located on the down-slope side of the lease road. In some locations ditches are located on both sides of the road and no ditches are located in some locations along the road. The lease road does not meet the cross slope standard due to maintenance practices and the natural topography of the area. In some locations the cross exceeds 2 percent and in other locations the cross is less than 2 percent. Full compliance with the cross slope standard would require that the road be reconstructed; causing additional disturbance to the lease road, rebuilding of the stormwater BMPs, and requiring additional cut or fill to fix those sections that are out of compliance. Access is not compromised to the site due to the portions of the road that are out of compliance. The lease road exceeds the maximum grade of 12 percent at two locations. Full compliance with the cross slope standard would require that the road be reconstructed; causing additional disturbance to the lease road and requiring additional cut or fill to fix those sections that are out of compliance. Access is not compromised to the site due to the portions of the road that are out of compliance The road is currently driven approximately 5 days a week by Marathon personnel monitoring facilities in the area using standard four-wheel drive pick-up trucks. The Marathon portion of the road is incorporated in their Stormwater Management Plan (SWMP). The Berry portion of the road is covered by their SWMP. Marathon Lease Road Assessment Page 3 Marathon 32C The lease road functions adequately for its intended use and is typical of existing roads providing access to natural gas production in Garfield County. Wyatt E. Popp P.E. Attachment Marathon Lease Road Field Observation Christopher M. Rolling P.E. Marathon Lease Road Assessment Page 4 ON OLSSON ASSOCIATES MARATHON OIL COMPANY 32C CENTRALIZED E & P WASTE FACILITY MARATHON LEASE ROAD ASSESSMENT FIELD OBSERVATION A field observation was performed on the Marathon Lease Road located between the Garden Gulch Road Extension and the 32C facility. This observation occurred on April 9, 2014. Weather conditions were sunny with temperatures in the 50 degree range. Snow had melted from the road surface creating rutted conditions in some locations. This site was accessed using a standard four-wheel drive pick-up truck. Observations were made at the following 8 locations beginning west of the Garden Gulch Road Extension and moving west to the 32C facility. Key to Lease Road Assessment Map Location Observation 1 Roadway Width 18 feet 2 Three-foot wide ditches located on both sides of roadway 3 No ditch located on north side of roadway. Four -foot wide ditch located on south side of roadway. Cross slope range from 0 to more than 2 -percent. Road grade greater than 12 -percent. 4 No ditches on either side of road 5 No ditch on north side of roadway. Cross slope greater than 2 -percent 6 Roadway 24.5 feet wide. Ditches 1.5 to 3 -feet wide 7 Road grade 14.3 -percent per Marathon SWMP document 8 Road grade 10 -percent per site plan and Marathon SWMP document Attachment Lease Road Assessment Map 760 Horizon Drive, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com 250 500 Feet Project Number: 12-1372 Drawn By: JWH Revision Date: 4/14/2014 Lease Road Assessment Marathon Oil and Gas 32C Access Road Garfield County, CO i V `Y O• 1 7Grand P: unction, CO 8760 ASSOCIATES F: 970.263.7456 DISCO/GOER Go ana Figure 1 O\OLSSON ASSOCIATES ACCESS ANALYSIS MARATHON OIL COMPANY 32C PRODUCED WATER POND Access to Marathon's property and the 32C project area is established by the following documents contained in this application and provided here: • Garden Gulch Road Agreement (Road Construction and Maintenance Agreement) • Garden Gulch Road Upgrade Agreement • Garden Gulch Road Extension Agreement • Letter from Caerus Oil and Gas LLC (successor of PDC, demonstrating that Marathon is current on its payment of annual maintenance costs) The roadway from CR215 to the 32C project area crosses the following properties: Ownership Roadway Parcel Number Chevron Garden Gulch Road 217118200008 Chevron Garden Gulch Road & Extension 216912200012 PDC (Caerus) et al. Garden Gulch Road Extension 216911400011 Marathon et al. Garden Gulch Road Extension 216901100027 Chevron Garden Gulch Road Extension & Lease Road 213533400010 Marathon et al. Garden Gulch Road Extension & Lease Road 213532100009 Attachment P-1 Parcel Map 760 Horizon Road, Suite 102 TEL 970.263.7800 Grand Junction, CO 81506 FAX 970.263.7456 www.olssonassociates.com 213532100009' BERRY PETROLEUM COMPANY & 216901100027 BERRY PETROLEUM COMPANY & 216901200001 LATHAM, THOMAS F & GINGER L 216912200012 y` CHEVRON USA INC 217117200953 BLM . O32C 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\OLSSON ASSOCIATES 760 HORIZON DRIVE; SUITE 102 GRAND JUNCTION, CO 81506 TEL 970.263.7800 FAX 970.263.7456 Milesw FIGURE P-1 N FIRST AMENDMENT TO SURFACE USE AGREEMENT Marathon 596-32A Pad This FIRST AMENDMENT TO SURFACE USE AGREEMENT ("Amendment") dated as of May 1, 2009 (the "Effective Date") is made by and between CHEVRON U.S.A. INC„ a Pennsylvania corporation, with offices at 11 1 I1 S. Wilcrest Dr., Houston, Texas 77099, ("Surface Owner") and MARATHON OIL COMPANY, an Ohio corporation, having an address of 5555 San Felipe Road, Houston, TX 77056, ("Operator"). RECITALS A. Surface Owner and Operator entered into a Surface Use Agreement, ("Surface Use Agreement") dated October 2, 2008 for the 596-32A well pad ("Pad"), being drilled pursuant to the Oil and Gas Lease by and between Chevron U.S.A. Inc and Petroleum Development Corporation, predecessor in interest to Marathon Oil Company, dated November 15, 2002 and recorded in Book 1447, Page 579, Garfield County, Colorado. ("Lease"). 13. Operator requested Surface Owner to grant Enterprise Production, LLC ("Enterprise") a Pipeline Easement, dated. effective May 1, 2009 executed by and between Chevron U.S.A. Inc. as Grantor and Enterprise as Grantee ("Easement") to lay the lateral gas line from the Pad to the tie in point at the main pipeline. In addition to setting out additional requirements for the Pad outlined in the Surface Use Agreement, this Amendment specifies the rights Operator will retain, forfeit, and. further be bound by upon execution of the Easement or Amendment, whichever comes first. C. In consideration of the mutual promises set out in the Amendment and the Surface Use Agreement,. and other good and valuable consideration, the receipt and sufficiency of which is acknowledged, Operator and Surface Owner agree to be bound by the terms of the Amendment, AGREEMENT Section 3.1(B) — Permitted Purposes. Section 3.1(B) is deleted in its entirety and replaced with the following: "(13) Building a pad location for the wells, installing a water line from the Pad to the tie-in point or building new roads on the Land to the specifications detailed on Exhibits C-1-6. Operator shall have no right to lay, install, operate, or maintain any natural gas pipeline from the Pad to the tic -in point further detailed on Exhibit C5 to the Agreement, such right having been granted to Enterprise under the Easement at Operator's request" Exhibit C5 to the Agreement is attached and incorporated by reference to this Amendment. 2, Section 4.7 — Pipeline Depth. Section 4.7 is deleted in its entirety and replaced with the following: 4.7 Pipeline Depth and Construction Coordination. Operator agrees to install the water line in the same trench as the Enterprise natural gas line that Enterprise is constructing under its Easement. Operator agrees to coordinate construction of the water line with Enterprise's installation of the parallel natural gas pipeline in the same corridor as the Easement, as shown on Exhibit C5, so that construction on the water line and natural gas pipeline occurs contemporaneously, First Amendment to Surface Use Agreement — Marathon 596-32A Pad, QLS No. 158350 Execution Version May 1, 2009 3. Section 4 - MAINTENANCE, USE, ANI) RESTORATION OF THE LAND. The following provisions shall be added to the end of Section 4: 4.20 No Unauthorized Access. Operator is not authorized to grant access across or to Surface Owner's Land to any third party or regulatory authorities without prior written consent of Surface Owner, except as expressly required by local, state or federal law, permit conditions, duly authorized warrant, or emergency pursuit. Surface Owner must approve any and alt access to the Land that is not legally required, and Surface Owner may withhold its approval for any reason or no reason. If a duly authorized regulatory authority does access Surface Owner's Land pursuant to local, state, or federal law, Surface Owner must be notified in writing in advance of the access if possible but no later than twenty-four hours after the access occurs, including in the notice the name of the authority and representatives present, and the date, time, and purpose of the access. 4.21 Field Studies. Operator must provide a copy of all proposals for biological or other field studies to Surface Owner, and Surface Owner must give written approval for any proposals prior to the studies being performed on Surface Owner's Land. Surface Owner's approval may be withheld for any reason or no reason. If Surface Owner's approval is given for a study, Operator must provide Surface Owner a copy of all data and resulting reports via overnight delivery within one day of Operator's receipt. 4.23 Consultations. Before beginning consultation with any local, state, or federal agency or authority under the Colorado Oil and Gas Commission ("COGCC") Rules ("Consultation") related to the Surface Owner's lands, Surface Owner must review and approve a copy of any draft plans or presentations at least thirty days in advance of any Consultation. Operator must invite and schedule all Consultations to include Surface Owner at Surface Owner's discretion and all required governmental agencies, including the COGCC. Consultation should be scheduled at least thirty days in advance and at reasonable dates and times that will ensure the highest likelihood of all critical parties attending the meeting. At a minimum, Operator should make every etTort to ensure that a COGCC representative is present at all Consultations. Operator must record minutes of all Consultations and send a copy of same to Surface Owner at the address set out for notices under this Agreement. 4.;24 Proposals. All proposals involving use or designation of use of any portion of Surface Owner's lands require advance review and written approval of Surface Owner, including but not limited to any proposal to use any portion of Surface Owner's lands for: (A) creating refuge areas as a mitigation for surface disturbances to a possible sensitive wildlife area; and (13) mitigation activities that may lead to road access or other surface use limitations. Surface Owner must receive a copy of any draft land use proposal at least thirty days in advance of any Consultation or submittal prior to Consultation. Surface Owner must approve all final proposals, and may withhold its approval for any reason or no reason. 4. Section 11 -- PUBLIC ANNOUNCEMENTS/CONFIDENTIALITY. The following text shall be added to the end of Section I I: All terms and conditions of this Amendment are strictly confidential between Operator and. Surface Owner. Operator may not disclose or divulge any provision of this Amendment without the prior written approval of Surface Owner, which may be withheld for any reason or no reason. First Amendment to Surface Use Agreement—Marathon 596-32A Pad, QLS No. 158350 Execution Version May I, 2009 2 5. The provisions of the Surface Use Agreement remain unchanged and in full force, except as amended by this Amendment. The Surface Use Agreement and this Amendment shall be binding upon and inure to the benefit of each Party and their respective successors and assigns. The Parties have executed this Amendment in duplicate as evidenced by the following signatures of authorized representatives of the Parties: SURFACE OWNER: CHEVRON U.S.A. INC. Signature: OPERATOR: MARATHON OIL COMPANY Signature: Name: e " /-i : 5 Title: At#or-ney-in-Fact ADDRESS FOR NOTICES: 1 1 1 11 S. Wilcrest Ilouston, Texas 77099 Attention: Land Manager Ranch Manager: Craig Tysse, (970) 285-9722 Name: Title: ADDRESS FOR NOTICES: 5555 San Felipe Road Houston, TX 77056 Attention: Manager, Marathon Oil Development Facsimile: (303) 999-4401 First Amendment to Surface Use Agreement — Marathon 5%-32A Pad, QLS No. 158350 Execution Version May 1, 2009 3 EXHIBIT "C5" P. OPOSED A E8S�ROAO WILLIAM H. SMITH & ASSOCIATES P.C. SURVEYING CONSULTANTS aaJ zABT Man NORTH PROM 507.8Th- 3 OREM Mira 111' $O7-B?5--3838 www wxiamIfhhpC COM DRAWN BY: CEO JOB Na 26099 DATE; 10/2112008 PAD NO. 596-32A NE/4 SEC.32 T5S R96W EXISTING ROADS PROPOSED ACCESS ROADS - PROPOSED PIPELINES T PROPOSED PIPELINE "T" PAD NUMBER 596-32A LOCATED IN THE NE/4, SECTION 32, TOWNSHIP 5 SOUTH, RANGE 96 WEST. SCALE: r 500' VICINITY MAP FOR MARATHON OIL COMPANY P.O. BOX 3128 HOUSTON, TX 77253 5555 SAN FELIPE HOlI$IQN. TX 77056 SHEET 5 OF 12 OM MY RN 11th Receptionft: 726196 96125/2007 01!15:41 P!1 6: 1941 P: 0187 Jean Alberti° 1 of 38 Rao Fee:$191 00 Goc Fea:0.00 GARFIEL0 COUNTY CO ROAD CONSTRUCTION AND MAINTENANCE AGREEMENT This Road Construction and Maintenance Agreement (this "Agreement") is entered into effective as of the 1st day of November, 2005 (the "Effective Dale") by and among Petroleum Development Corporation ("PDC"), Berry Petroleum Company ("Berry"), PGR Partners, LLC ("PGR Partners"), Teton Piccance LLC ("Teton Piceance"), Marathon Oil Company ("Marathon") and Williams Production RMT Company ("Williams," and collectively with PDC, Berry, POR Partners, Teton Piceance, and Marathon, the "Participants"), Chevron Shale Oil Company (f/kla ChevronTexaco Shale Oil Company), a division of Chevron USA Inc. ("Chevron") and Garden Gulch, LLC ("Operator"). Participants and Operator are herein referred to individually as a "Party" and collectively as the "Parties." RECITALS A. The Parties wish to set forth in this Agreement the rights and obligations of the Participants and Operator with regard to the construction and maintenance of Garden Gulch Road (as more specifically described on Exhibit "A" attached hereto, the "Road"). The Road is to be a private road, owned by Chevron and licensed to each Participant, that will provide the Participants with access to and egress from certain wells, gas pipelines and gathering systems, water pipelines, tanks, compressors and other similar oil and gas exploration, production, gathering and transportation equipment and facilities on the lands located in Garfield County, Colorado and more specifically described on Exhibit "B" attached hereto. B. Chevron is a party to this Agreement solely for the purpose of providing its written consent to, among other matters, the construction and maintenance of the Road by Operator, to each Participant's contribution toward the cost of the Road, and to each Participant's License to and use of the Road, in each case pursuant to Sections 2(d), (f) and (h) of the letter agreement by and between Chevron and PDC dated January 17, 2005, attached hereto as Exhibit "C" (the "Chevron/PDC Agreement"). AGREEMENT 1. Construction and Services. Subject to the terms and conditions hereof, Participants hereby engage Operator to perform the construction and maintenance of the Road (the "Services") as described on Exhibit "D" attached hereto, 2. Term. This Agreement shall commence as of the Effective Date and shall continue for the duration of the life of the Road; provided, however, that, any Party which elects either to not pay, or fails to timely pay, its Sharing Percentage of the Road Expenses (as both of such terms are defined in Exhibit "E" attached hereto) shall not be a Party to this Agreement, and .? 6ft- 1111 NM IC lid NW 11111 Recept Iced* . 726196 06125/2007 01.15:41 PR B. 1341 P 0168 Jean R1b.ripe 2 or 36 Res Final$181 06 Doc Feo 0 06 GRRF16L0 COUNTY CO such Party's license and right to use the Road shall be deemed terminated, from and after the date of such election or breach. In such event, the remaining Parties agree to renegotiate the Sharing Percentages of the Parties, taking into account such termination. 3. Payment for Services. Participants shall. pay Operator to perform the Services in accordance with the schedule set forth in Exhibit "E". 4. Manner of Performance. Operator shall perform the Services with diligence, in a workmanlike manner, and in accordance with industry standards, applicable laws and contracts. Selection of Contractors. The number of employees or contractors used by Operator in performing. Services hereunder, their selection. and the hours of labor and the compensation for the Services performed shall be determined in the sole discretion of the Operator. 6. Insurance. During the term of this Agreement, Operator agrees to maintain on behalf of itself and the Participants the insurance coverage described in "Exhibit "F" attached hereto. Each Participant shall be an additional named insured on each such insurance policy. Operator shall furnish proof of such insurance to Participants upon request. The policies for such insurance shall not be cancelled without Participants' prior written approval. Such insurance shall be primary to any of Participants' insurance for purposes of this Agreement. 7. Entire Agreement/Amendments. This Agreement and any Exhibits hereto constitute the entire agreement among the Parties concerning the Services and supersede all prior agreements, understandings or representations among the Parties in respect of such Services. No modification of or amendment to this Agreement will be effective unless it is in writing and signed by all of the Parties hereto. 8. Independent Contractor. In the performance of the Services, Operator shall be an independent contractor, with the authority and right to direct and control all of the details of the Services, Participants being interested only in the results obtained; provided, however, that all of the Participants shall have a right to inspect and comment on such Services. Participants shall have no right or authority to supervise or give instructions to Operator's employers or contractors, which shall at all times be under the sole supervision and control of Operator. 9. Relations of the Parties. It is not the intention of any of the Parties hereto to create a partnership or joint venture, and neither this Agreement nor the operations hereunder shall be construed as creating such a relationship. 10. Taxes. Operator shall be responsible for payment of all federal, state, and local taxes relating to the compensation it receives for the Services hereunder. Participants shall not withhold any taxes from such compensation, nor remit such amounts to any governmental authorities on behalf of Operator. Further, Participants shall not make any payments as an employer to any federal or state government or other governmental taxing authority on behalf of Operator for purposes of unemployment compensation. 2 1111K 1:1 110 I I1PC1 1, 11 URIAIINIi 11111 1Rec*ptian4: 726396 041751200' 01.15:41 PM 9: 1941 P• 0169 Jean Altaericc 3 al 35 Rec Fes 5191 00 Doc Fom:C.00 GARFIELD COUNTY CO 11. Indemnification. Operator shall be liable for, and shall indemnify and hold harmless each Participant, its parent, subsidiaries and affiliates, and their respective directors, officers and employees (collectively, "Inderxtuaitees"), Brom and against any and all losses, costs and expenses, claims or damages suffered or incurred by any Indemnitee based upon or arising out of Operator's breach of this Agreement or gross negligence or willful misconduct in the performance of the Services hereunder by Operator or any third party, Without affecting the foregoing indemnification obligation, and subject to the terms and conditions of the applicable construction and other agreements entered into by Operator with third parties for the performance of the Services, Operator agrees to transfer and assign, to the extent assignable, to each Participant the benefit of and the right to enforce any indemnification provisions benefiting Operator under such third party agreements in proportion to the Sharing Percentages set forth on Exhibit "E". 12. Notices. Any notice (including any invoice or statement) to a Party under this Agreement shall be deemed to he given upon receipt by electronic mail, facsimile, by personal delivery or courier or by prepaid mail addressed as follows: Operator: Garden Gulch, LLC 3801 Carson Avenue Evans, Color -ado 80620 Attention: Dewey Gerdom Phone: (970) 506-9272 Fax: (970) 506-9276 E-mail: dewey7a,pdc-rockymtn.com Participants: Petroleum Development Corporation 3801 Carson Avenue PAWLS, Colorado 806211 Attention: Dewey Gerdom Phone: (970) 506-9272 Fax: (970) 506-9276 E-mail: dewey@pdc-rockymtn.com nor. F'S71RAP11, X14!, I1, Lr1/21.11111ii.liii 11111 R.c ptian#: 72619B 0&125124707 61,15:41 PM B: 1941 P: 0170 Joan Alborico 4 of 36 Rec F 0,$161 00 Qac Fae:0.00 GARFIELD COUNTY CO Berry Petroleum Company 950 Seventeenth Street, Suite 2400 Denver, Colorado 80202 Attention: Joseph D. Stewart Phone: (303) 633-1819 Fax: (303) 633-1827 E-mail: idsiabry.com PGR Partners, LLC 370 Seventeenth Street, Suite 4300 Denver, Colorado 80202 Attention: Randy Arnold Phone: (303) 575-0329 Fax: (303) 575-0429 E-mail: randy!(deltapetro.com Teton Piceance LLC 410 Seventeenth Street, Suite 1850 Denver, Colorado 80202 Attention: Tobey Schultz Phone: (303) 565-4600 Fax: (303) 565-4606 E-mail: amschultz@teton-energy.coin Marathon Oil Company 5555 San Felipe [louston, Texas 77056 Attention: Kenneth W. Tatarzyn Phone: (713) 296-2423 Fax: (713) 296-3397 E-mail: kwtatarzyn@marathonoil_com Williams Production RMT Company 1515 Arapahoe Street Tower 3, Suite 1000 Denver, CO 80202 Attention: Jim Schaff Phone: (303) 606-4283 Fax: (303) 629-8281 E-mail: iim.schaff@williams.com Notice shall be deemed effective on the date of actual receipt. 4 1111101.11W0111.16.161!.141.1Weiriiria Inn Reception4: 726196 06/26/2007 01,16.41 PR 9 1941 P: 0t71 Jean Albertcc 5 of 36 Rao Fee:5181 00 Doc Fecal 00 GARFIELD COUNTY CO 13. Assignment, This Agreement is not assignable by any of the Parties without the prior *,written consent of the other Parties, which consent shall not be unreasonably withheld. 14. Governing Law. This Agreement shall be governed by and construed according to the laws of the State of Colorado, excluding conflicts of laws principles_ Each Party expressly consents to the personal jurisdiction of the state and federal courts located in Denver. Colorado, for any lawsuit filed against it arising under this Agreement. 15. Attorney Fees. in the event of a dispute hereunder, each Party shall be responsible for its own attorney's fees and costs. 16. Severability and Substitution of Terms. If one or more of the provisions in this Agreement are deemed unenforceable by law, then the remaining provisions will continue in full force and effect. With respect to any such unenforceable provision, an enforceable provision,. which most closely meets the intent of the Parties will be deemed to be substituted. 17. Binding Effect. This Agreement shall be deemed a covenant running with the land upon which the Road is located, shall be binding upon, and shall inure to the benefit of, the Parties hereto and, subject to Section 13, to their respective successors and assigns. 18. Waiver. No waiver of any breach of this Agreement shall be a waiver of any preceding or succeeding breach. No waiver of any right under this Agreement shall be construed as a waiver of any other rights. 19. No Third Party Beneficiaries. Except as expressly set forth herein, this Agreement shall not provide any benefit 10 any third party or entitle any third party to any claim, cause of action, remedy or right of any kind, it being the intent of the Parties that this Agreement shall otherwise not be construed as a third party beneficiary contract. 20. Counterparts and Electronic Media, This Agreement may be executed in counterparts, each of which shall be deemed an original instrument, but which together shall constitute but one and the same instrument. Any counterpart may be delivered by facsimile, e- mail or other electronic media. Any electronic signature shall be replaced with an original signature as promptly as practical. 21. Action by Participants. All action referred to herein by Participants shall be taken by majority vote, with each Participant having one (1) vote, 22. Consents of and Other Actions by Chevron. Pursuant to Section 2(d) of the Chevron/PDC Agreement, Chevron hereby approves the fact of the contribution to the cost of the Road by each Participant (other than PDC). Pursuant to Sections 2(0 and (h) of the Chevron/PDC Agreement, Chevron hereby grants each Participant (and to each Participant's agents, contractors, subcontractors, subsidiaries and other affiliates) a separate, nonexclusive right and license to use the Road in accordance with the terms hereof for so long as each such Participant continues to pay its proportionate share of the annual maintenance costs of the Road and, to the extent Piceance Gas Resources, LLC (the predecessor -in -interest to Berry, PGR 5 1111 in 1 ii i Reeepptilon#: 72Gt96 86/2512057 81 15:41 PM B: 1941 P 0172 Jean Alber1on 5 of 36 Roc Fee:S181.08 Doc Fes:0.00 GARFIELD COUNTY CO Partners and Teton Piceance) had the right to use the road under PDC's license, consents to the transfer of such use right to Berry, PGR Partners and Teton Piceance, and their respective agents, contractors, subcontractors, subsidiaries and other affiliates. Chevron hereby consents to the transfer by PDC to Operator of the right and obligation to construct and maintain the Road. Chevron hereby waives the requirement set forth in Section 2(h) of the Chevron/PDC Agreement that PDC shall have completed all agreements with additional contributors and commenced actual construction of the Road prior to May 31, 2005, and hereby confirms and agrees that PDC shall be deemed to have complied with such requirement. 23. Performance of Chevron/PDC Agreement, PDC hereby represents and warrants to each other Participant that, except as set forth in Section 22 of this Agreement, it is and has been in full compliance with every term and condition of the Chevron/PDC Agreement, and covenants to notify each other Participant in writing promptly upon becoming aware of any breach, or threatened or claimed breach, by PDC or any other party to the Chevron/PDC Agreement OPERATOR: GARDEN GULCH. LLC tion, Member Manager By: Name: Eric R. Stearns Title: Executive Vice President Date: J ,E 71 Z 001"7 STATE OF WEST VIRGINIA B��� COUNTY OF A7U ) ) The foregoing instrument was acknowledged before me this 7,64 day of 2007, by Eric R. Stearns , as Executive Vice President of Petroleum Development Corporati a Nevada Corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires:/?M) / ' cJ1)/2 Notary Public: Name: GFFICIAL SIAL NOTARY PUBLIC STATE OF WEST VIRGINIA JOANN LAMBERT ROUTE 2, BOX 14Q JANE LEW, WV 21378 My ccmmismorr awira Itowmber 17.202 6 111111.KVIANIIililliieklififiliiiI I SIN 11111 Recept ionic : 726196 08125/2007 01:15:41 PM 9: 1941 P! 0173 Jean Fltberico 7 of SG Roc Feal$191.00 Doc Fee:0.06 GARFIELD COUNTY CO PARTICIPANTS: PETROLE ORATION By: Name: Title: \l a., �1efb.a Date: STATE OF COLORADO ) COUNTY OF[]�.., f } The forcgoin instrument was acknowledged before me this L-3 day of , 2006, by as�y =i�„nf Petroleum Development Corporation, a Nevada corporation. on behal of such company. Witness my band and official seal, My Coom�an Expires: My Cmm�iSS O l E% 1t4 _ Notary Publ. iXrd, 05113122006 Name: BERRY PETROLEUM COMPANY By: Name: Title Date: STATE OF COLORADO COUNTY OF ) The foregoing instrument was acknowledged before me this day of , 2006, by as of Berry Petroleum Company, a corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires: Notary Public: Name: [seal] 7 . rI1 nT110+1/4411.141. .VI N'L1!AN X1111 Reception«: 72E196 O 41 9 of 36 Roc F SSI81POR Con Fan-8.8887GARFIELD COUNTY CO PARTICIPANTS: PETROLEUM DEVELOPMENT CORPORATION By: Name: Title: Date: STATE OF COLORADO ) ) COUNTY OF ) The foregoing instrument was acknowledged before Inc this day of _, 2006, by , as of Petroleum Development Corporation, a Nevada corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires.. Notary Public: Name: [seal] BERRY PETROLEUM COMPANY By: --- /- 1' - Name: Bruce S. Kelso Title: Vice President Exploration Date: August 25, 2006 STATE OF COLORADO ) CITY AND ) COUNTY OF Denver ) The fou oing instrument was acknowledged before me this 25th day of Augst . 2006, by Bruce S. Ke so aR Vice President — EXplcffBe Petroleum Company, a el aware corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires: 3/(V ap ! 0 Notary Public: _- Name: 1 t Gt t+ -MQrrr t) ✓) [seal] • ■kkk 11�' ��k�� tGl'f,V����, WI W k>A N 111111 !scspt*onM. 726196 06/25/2007 0116.41 P4'1 0. 1941 P: 0175 Jean FS..6erlen 9 of 36 Rea Fee4181 00 Doe Fee:0 00 GARFIELD COUNTY co By: Name: Title: Date: STATE OF COLORADO COUNTY OF DEIttigl ) I re ging instruren-t`was acknowledged before me this Itp*day v , 2006, by 31 004 as ,11-1.1 M 'P' of PGR Partners, LLC, a corporation, on behalf o such company. Witness my hand and official seal. � �f My Commission Expires: ' ' Dbttc Notary. PyW t Name: bot. - LDE4� RUTH L. ELDER NOTARY PUBLIC STATE OF COLORADO My Commission Expires 04107/2009 TETON PICEANCE LLC By: Name: Title: Date: STATE OF COLORADO COUNTY OF ) ) The foregoing instrument was acknowledged before me this _ _ day of , 2006, by , as of Teton Piceance, LLC, a corporation, on behalf of such company. Wimess my hand and official seal. My Commission Expires: Notary Public: - Name: Iseall 1111 l'AFIMION:i11Lc1A101 Cf4r1# 'I10iii 11 111 Reception#: 726196 06425/2007 01.15,4/ PFl B: 1841 P 0176 Jean Aiberico 10 o1 86 Roc Fee:$181 00 Doc Fee 0 00 GARFIELD COUNTY CO PGR PARTNERS, LLC By: Name: Title: Date: STATE OF COLORADO ) ) COUNTY OF ) The foregoing instrument was acknowledged before me this day of , 2006, by as of PGR Partners, LLC, a corporation, an behalf of such company. Witness my hand and official se My Commission Expires: Notary Public- Name: [seal] TETON PICEANCE LLC By: Name: Title: Date: Ir jrletLt fr CS icon' STATE OF COLORADO COUNTY OF r nv 149/°‘ ) ) ) The foregoing instrument was acknowledged before me this ,29 day ofvor, , 2006, by t`� kCoa 1 . Ac 14 p. , as s. c1e.e".1 of Teton Piceance, LLC, a Cittkac o. Lo .aefreration, on behalf of such company. LliservAt d and official seal. My Commission Spires 1/30i2007 3n lapel Notary Pub]i • Name: 111111 tF4I1414iLV,141l1V l,I41'Mfil4 6;Ilfii*N1i 11111 Racepptionti: 726196 05125/2007 01:16:41 PM 0: 1841 P; 0177 Jean Rtberleo 11 of 35 Roo Fee:3151,00 Doc Fee:0.00 OnRF1ELO COUNTY CO MARATHON OIL C )MPAN Y By: Name: Title: Date: STATE OF Text/5 Mistarif-irt.Facs 9- 7/-e74 ) COUNTY OF H* rr S ) 1'he foregoing instrument was acknowledged before me this ,r'1 S day of 17 2006, by 141- t ).-21±1rz y n , as /4}tof 5(-0- &xt of Marathon Oil Company, a e14,lblir<re. corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires: _ L flUOr Il a�0 tO Notary Public: Name: ']wr clr� c ' _` aa3c-`7 elaorek I I 6\61 vt .ni 7HD.KUHLMAN NOVNY public, State of Taxes MY Commissi n Expirel JCnuart 17. 9nln WILLIAMS PRODUCTION RMT COMPANY By: Name: Title: Date: STATE OF COLORADO COUNTY OF ) ) ) The foregoing instrument was acknowledged before me this day of , 2006, by as of Wil Fauns Production RMT Company, a corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires: Notary Public: Name: Lseal} 9 1111 IY'iF11111:4'1E1:C1r1wr 1,14,NVI '14i111411u1 Reeeptierai: 726195 Q0/20/2007 01 15 41 PM $ 1941 P. 0178 Joan A1ber1co 12 of 38 Rec Fee $101 00 Dec Fee!0.00 GARFIELD COUNTY CO MARATHON OIL COMPANY By: Name: Title: Date: STATE OF ) COUNTY OF ) The foregoing instrument was acknowledged before me this day of , 2006, by as of Marathon Oil Company, a corporation, on behalf of such company. Witness my hand and official seal. My Commission Expires; Notary Public: Narne: [sea]] WILLIAMS PRODUCTION RMT COMPANY By: Name: Alan Harrison Title: Vice President Date: g/f. i9�A STATE OF COLORADO COUNTY OF DENVER ) The foregoing instrument was acknowledged before me this 5th day of September, 2006, by Alan Harrison , as Vice President of Williams. Production RMT Company, a Delaware corporation, on behalf of such company. Witness my hand and official seal- 6ftiExpires: duly 31. mu) Notary Public: a ► .... Name: Cynthia Allison % ,1 •r lr.rrr.rl,.'. 9 111114FZtwreg;n111411'1r 1,14411 11Atiiil11111 Reccepptlonp, 725186 06025!2007 01:15:41 PP a 1941 P: 0179 Joan Albert= 13 of 36 Roc Fee:S101 00 Doo Fog:0.00 GARFIELD COUNTY CO STATE OF For purposes of Section 22 hereof only: CHEVRON SI -TALE OIL COMPANY, a division of CHEVRON U.S.A. INC. By: Name: Title: Date: COUNTY OF The foregoing instrument was acknowledged before me this day of , 2006, by as of Chevron Shade oil Company, a corporation, on behalf of such company, Witness my hand and official seal. My Commission Expires: [seal] Notary Public: Name: 10 1111 MiCAl'1p'1:14 :14111.Vil 391/1:IfeliCHilli 11111 Reception#: 726196 06125/2007 01'15:41 PM B. 1941 P. 01$0 Jean A111er1o0 14 of 36 Rec Fee•Zt61 00 Doe Fee!O 06 GARFIEL❑ COUNTY CO EXHIBIT "A" To Road Construction and Maintenance Agreement Description of Road Operator shall construct, operate and .maintain the Road on the following lands located in Garfield County, Colorado: Township 6 South, Ranee 97 West, 6th P.M. Section 12: SESE Section 13: NENE Township 6 South, Ranee 96 West, 6`b P.M. Section 7: 5252 Section 18: N2 11 1111cn 117,111,TEIC #111 ,1411',141i ,10411710:11411114 11111 Rereptian1: 726198 05/25/2007 01.15 41 PSI B: 1941 P: 0181 Jean flbarico t5 of 38 Rae Pam $181.00 Doc Fac,0.00 GARFIELD COUNTY GO EXHIBIT "B" Description of Lands Garden Gulch Road will provide Participants with access to well, gas pipeline and gathering system, water pipeline, tanks, compressors and other similar oil and gas exploration, production, gathering and transportation facilities located on the following lands: Township 4 South, Ranges 95-98 West, 6th P.M. Township 5 South, Ranges 95-98 West, 6tb P.M. Township 6 South, Ranges 95-98 West, 6th P.M. Township 7 South, Ranges 96-97 West, 6th P.M. 12 Chcrrn:T..r. A .It 011 Company Null. Am.r Ir. Uranium. 11111 1. W1'r, U, MD.11cq, TX 77099 A.G. Re. SGw. Ilumme. TA 7T2ki Januaty 17, 2005 P en-oi eum Development Corpcxncirx: Attention: Dewey Gcrdhm 3801 Cepa Avenue Evans, CO 80620 CTSOC to i'oC Leases Cousent to Assign and Amendment of l..eases Garden Gulch. Road Agreement Glerfeld Connty, Colorado Dear Dewey, EXHIBIT "C" 1111K l+1IMAX,W I AIII' i 1 l' I rl 1lli . 'i 1101 Reospttonal 726t86 06125/2007 01.15 41 P11 B 1941 0 0102 Jean ktberica 16 of 36 Roc Fee:3101.04 poo Fee 0 CO GARFIELD COUNTY CO Chevro nTexaco Per your letter dated November 15, 2004, delivered at our rneetmg with Orval Baldwin and Erie Stearns in Orval'a office on November 17, 2004, Petroleum Development Corporation (PDC) has squealed f;helronTcxaoo Shale Oil Company. n division of Chevron U.S.A. Ina. (CTSOC), which is suctessor in interest to Chevron Shale Oil Company, consent to PDC's assignment lo Pi ceance t an Reaourcee, LLC (POR) of an approximate 50% iniercat in CTSOC's teases to PDC to Garfield County, Colorado (defined on Exhibit "A") as same cover the mesa top. PDC lose further requestrd that Article 16. of each of the Exhibit "A" leases be amended to extend the well and tic iiitier relocation dale (relocation date) pant the currant dente of January 1. 2018. The relocation date if the date at which the rrspcno btlity for paying the costs 45.10C ted with moving existing wells and facilities so than CFSOC may puesua shale operations shifts from CTSOC to PDC. CTSOC is willing to convent to the requested assiuurnest of intereat to PGR (attached hereto as Exhibit"1i') and to amending Article 16. of each of the Exhibit `A" learns as penvidccl in Paragraph 4 below for each and every well spudded radar said !casco after the date of the amendment (attached hereto as Exhibit "C"), if PDC axes to the following: 1. PDC shall execute the Consent to Altai gp leiter agrearncr1t (aUaclwl hereto as Exhdlit "P") and dell also obtain I'GR's cxecmlivn of said thibit "D'. Bout executed copies of said Fathibit shill thea be returned to CTSOC; only upon CTSOC's receipt of such copies of Exhibit "D" rammed by PDC and POR shall CCSOC'a comert to dm az.laynmr:nt referenced herein betotno effective. 2. roc shall proceed with the coustruotion of the Carden Uuleh Road ((1OR) txt tttc tamer.' of this item number 2. I3 Tarurary 17, 2005 rage 2 1111 FF371111..1a1#1,1411114il'141 r1i110i14: 1M1aN1ri 11111 Rpt r1$ 726196 0512512007 01 15.41 PM B 194$ p 019} Jean Aiberico 17 of 36 Rec Fee:S1d1 00 Doc Fee (5 00 GRRFIFLd COUNTY CO Chev►ronTexaco tL The mute oCeaid GGR shall be the high]iglrted mute on the attached map (attached thereto es Exhibit " b"'), ceid map being dated May 12, 2003 and having born drawn by Construction Surveys, Inc., or an alternative route. Prior to commencement of construction, PDC end CTSOC a1ta11 atteunpt to retch agreement on the final route for the GGR; if PDC end ('FSQC do not egret. on final route for the OUR by March I, 2005, CTSOC atone shat] chrtoec the route. PDC shall act as project manager for the GOR building project. b. On or before March 1, 2095 PDC wt1I submit to CTSOC a good faith estimate of the cunt of canatruction of the GGR. Said estimate anal! be ftoin an Independent third party who is in the construction business with experience in making such road eslitnatea. 1f said estimate exceeds Four Million Five Fltrrudtod Thousand Dollars ($4,500,000), PDC aball have the choice of preceeding with the GOR ccrostnwtion, bearing the arkliuonal cos show ;4, .00,000 list! f, or it may deoline to proceed with the GGR construction by paying Cf SOC Ono Million Dollars (11,000,000). This payment to CTSOC must bo made no later than March 1, 2005. If this payment is made to CTSOC no later than Mnre11 1, 2005, ?DC shell be under no further obligation to CTSOC undrr this agreement. If however, PDC etecls topruexd forward, then PDG shall not; nue forwin d under the temp of 20. below. L. PDC shall determine if the (3GR coarstruction requires any permit or approval frvrn any agency, organization, group, governmental xrnrnittea or other entity Craving jurisdiction over such eorisbuction. If any permit or approval ie rcgturccl, PDC may delay the start of constru ire until same is acquired. however, if said permits ur approval" are not acquired by PDC and construction on the GGR et rred by May 31, 2005, PDC shall deposit into an escrow account the sum of One Million bulla.- (Sl, 00.0 0) y :.:,::r,.i to tic :amiss of an twrvw ugrremai t agreeable to both parties Aster making said deposit PDC may cease to pronotti with the pumitring and constuction of tho (iGR or it may ptr coal with same. If it does proceed with same and completes the permitting and Continences eotesiuustinn of the GLTR by Dxcrrbcr 31, 2005, PDC shell be entitled to s refund of the escrow account, otherwise the esnr w account lirrtl will he disbursed to Chevron. d. CTSOC she] contdbtile its errrfnte fen for right-of-way for the road and T300,000 to the total actual cost for building the GGR. PDC Shall tlrnd the remainder ofthe coat itself or by socking additional companies or persons as contributors, approval of which must be requested by PDC and obtained horn CTSOC prior to their being allowed to contribute toward the cost of the road. CTSOC may withhold approval of any such prospeethc coati ibutor for any rcaecrn cr no rcaaoru. PDC. egress to include arty Party as 1 uurtrfbD 0r to rho GGR that CTSOC wishes to have included, said party(s) bearing their 1>ro{wtiimale allure of the costa to build and maintain the GGR based on Ihrir 14 January 17, 20 Page 1111111.WIRM INArNJOR 4TIONth 111111 Receptiantt: 7261€43 tral 51 PM Da1 P: RFbTe or33aRocFe:144.0OocFec,p a!CAIfLOCOJNY CO ChevronTexaco anticipated usage of the GGR and an terms similar to other third pities who have been allowed to join in the budding of tete GOR, if any have been so aliowad. If tits total cost to but d the GGR axeeada 54,000,000, then CTSOC shall insrram its monetary contribution for same by 550,000 for each 5100.000 of increased commotion costs up to a maximum total monetary contribution by CTSOC of 3500,000. a. If atter starting construction of the GOR, PDC or PDC and its contributors,13111 spent 54,500,000 without complotMg the GGR, It may choose to stop construction and abandon the proioet without further penalty, except that it will not leave any dangerous or hazardous condition created by tho GGR construction, but will at its own cost mako aura the entire oanstrttcti0n arcs is safe before eboltdonmg the project. f. Tato GOR, shall be owned by CTSGC, and CTSOC shall grant PD1; a license to tiro some. PDC will be responsible, al its solo cost and expense, for maintenance of rho GGR, and shall perform sum an on all/Wal basis in order to retain us livens to us, the GGR. PDC shall not be able to transfer its license to use tltc GDR nor its duty to maintain the GGR without CTSOC's prior written consent, which consent may be withheld by CTSOC far any reason or no reason. Any other pa, ty which has contributed ted to the building of the GGR pursuant to the terra of dila agreement Aisne granted a'license to use said road far I. long as they pay a proportionate sham of the r-0ntinuing annual mnitttenauce cosie, said straps to be determined by a written agreement to join in the building of tlr. i3GR executed by said ooutribulor, by CTSOC aril by PDC. g. CTSOC tha$ not be obligstad to pay any maintenance costs on the GOR antes[ and until it bogus using raid road to actually mine its minerals or drs`1i is own ail tndJor pa wells or buns using acme to otherwise actively extract its ;J immie At that time. CTSOC shell pay its proportionate share of the maintenance costs for alta GGR based ors its percentage ace of said road versus the other users thereof h, No party may assign any portion of its license to use the GGR without the prior written consent of t...:10C. which consent may bo withheld for any reason er no reason. Cl OC hereby agrees that PGR may use the GGR under PDC', license; PGR'a right to use tho GGR under PDC lionise shall not bo tranafornhto without CTSOC's prior written consent, which consent may be wittttteld by CTSOC for Any reason or no raison. Upgrades of the ©G1t alta!' be agreed to by CTSCC and PDC. No third patty shall be allowed to uao the GFR without paying a fix to be detramined by PDC and CTSOC (if PI )C: and CTSOC are unable to agree as to a fee, CTSOC shall act thea fa). All tees !waived from third partici, excluding maintenance tees and fees paid as original contributors under the tenths of this Item number 2 shall be divided evenly between PDC rind 15 January 17, 2005 Page 4 Recent lone 726196 06125/2007 el 15 4t On 6 1941 P OrPS Jean 4lber lee 19 of 36 Ren Faa.518+ 00 De Fee 0 ill CAPPIE40 C0tabs CO Chevr©nTexaco CTS©C. Subject io the other provisions of this item nusnhcr 2, PDC must have all preliminary aludics and wty'uoeetasay agreements between additional contributors completed and start actual construction on the CCM nn later than May 31, 2005 and proceed diligently with the work until completed. PDC may, at its tote discretion, forma Limited Liability Ceo,pasty (LLC) for the men= of construction of the GGR, mike' inn arsd alisbasrsemntt of Rada for the oonstnacliun of the[ICIR and outer administration, skillet vision Rnd accounting for the proieet as necessary. The parties hereto shall attempt in goad faith to re3.olve any di sonic wising oust of or minting to this Letter Agreement p:srmptly by mediation under the Ctnlu fat Public Resources Mediation Proceds ere [het currently in effect before resurti Pg to litigation. J. Artleie r. of each lease listed on Exhibit It" shall bo amended to include the following language at the beginning of said article: "Lessee agrees that on surface lends owned by Lessor it will not commence any surface activities which are allowed under this agreement without Fust giving Lessor and Lessors sur(aue lessee ihitty (30) days poor write -n so'riee of sand activities Additionally, prior to seurnnrarcing any surface asxivity (other that surveying) on [..0 30r'a surface lands, M.r._tsee will enter into a written aur face damage settlement agrcemgit with lessor's surface lessee covering the Janda to be disturbed and will provide a copy of carne to Lessor. In the event that Lessor's surface 1 es me requires a damage settlement that Lessor and PDC Arena sarressonable,, ttxm Lessor will waive the req.; r- hent fora written danmt{c settlement." 4. Artiela 16 of each lease listed on Exhibit "A" cixa,'1 iso amended to replace the last tarrtarrco of amid Article 16 whir the hallowing language: " llIsciivo January 1, 2.01 S if Lessor requires Lessee to change, cease or rttooate any of Lessee's f4e:1ities, the costs of sane and the lost production therefrom m chill be halts as follows: Year 2018: Lessor I7/17lhs, Lessee 0/1711, Year 2019: Lessor 16117tha, Lessee 1/171.11 Year 2020; Lessor 15117ths, Lessee7/17ths Year 2021: Lessor l4/17tha, Lessee 3/17th% Year 2022: lesser 13/171M, Lessee 4/I7ths Year 2023: ] for 17J17ths, Lessee 5117ths Year 2024: Lessor 11/17ths, Lessee 6/17tha Year 2025: Lemur 10/17ths, Lessee 7/17ths Year 2025; Lessor 9/1'7tlrs, Lessee 8117ths Year 2027: Lcasor S/l7tht, Lessee 9/17ths Year 2028: Lessor 711'/ths, Leasee 10/i Rhe Year 2029: Lesser 6f17rhs, Leasee 11/17tl Year 2030: lessor 5/17th4, !.taste 12/17rha Year 2031: Lessor 4117th , Leaaco 11117ths Year 2032: Lessor 3/ 17ths, Lessee 141 i 7tba Year 2033: Lessor 2/171h1, Lessee 15117tha Year 2034: i.rs of 1/1711; Lessee 16/17ths Year 2033: Lessor 011711s, Leasee 171171hs January 17, 2005 Page 5 ■III141F'i1511:1,'e}21i4 ,141APIAThf'{1'i1T161i 1041101 Recoptiar : 725196 06/2B/2007 01:16:41 PM B• 1941 P. 0186 Juan R16erizn 20 or 36 Ren Fee 5181 00 Deo Fee 0 De GARFIELD COUNTY CO ChevronTexaco Effective January I, 2035 and thereafter, Lessee agrees to change, cease or relocate ils operations ak its solo risk and coat, in order to eliminate an interference and Lessor shall have no obligation to compensate Lessee for lost production resulting from suoh elimination of an interference." If Pt3o agrees with the above, please so indicate by executing in the space provided below and returning a fully executed copy of this letter to my attention at the above address. Thls agreement shall be effective as of the date PDC agrees to and accepts this agreement. If you have queatims regarding this agreement, please direct thorn to Lee Parker at 28t-561-4725. Sincerely, CHEVROK"'6XACO SHALE 011. COMPANY, a division of Chevron U.S, A. Inc, Hy: 05. Baldwin 11 Assistant Sec.rotary AGREED TO AND ACCEPTED this -2 day of Tie. LL e rt t 2(105. PETROLEUM DEVE.,OPMENTCa"ORATION sy, .Erie R. Stearns Executive VP Exploration and Development EXHIBIT "A" attached 1.o and made a part ©1 that certain Letter Agreement dated January 17, 2005, by and between Petroleum C1eve1epment Corporation and ChevronTexaco Shale Oil Company CTSOC leases to PDC in Garfield County, Colorado Ls Date Lessor Lassoo Re-sorellno 1 150498 07/31101 Chevron Sheds 011 Company Petroleum Development Oorporation BK 1312. Pg 1884 2 155563 08128!01 Ch:ivrori U.S.A. los., 8UCCussor In Petroleum Development Cotporalion 9k 1380, Pg 278 Interest to Chevron Shale 011 Company 3 158554 10/24101 Chevron U S.A Inc., succussor in Petrcieum Development Cdrporatldn Bk 1380, Pg 273 Interesttn Chevron Shale 011 Company 4 1E5555 05117102 Chevron U.S.A. inc., euccussor In Petroleum Development Corporation Bk 1405, Pg 498 inle.resl to Chevron Shale 011 Company - 5 155014 11102!02 Chevron U.S.A. Inc., succussdf in PeIroteum Development Corporation $k 1447, P9 568 inleresi to Chevron Shale Oil Company 5 168345 09/20/01 Crrevron U.S.A. inc., suCcusser in Petroleum Development Corporation Sk 1447, Pg 553 inleresl to Chevron Shale 011 Company 7 1.8349 11/15/02 Chevron U.S.A. Inc., succussor In Petroleum Development Corporation Bk 1447, Fg .573 interest to Chevron Shale Oil Company 8 158350 11/15/02 Chevron U.SA Ina, sucrussor in Petroleum Development Corporation Elk 144,17, Pg 579 [ntereslto Chevron Shale 011 Company 1583.51 11/10/02 Cnevren U.S.A. 11C., auCeu35Or in Petroleum Development Corporation Bk 1447, PU 585 Interest to Chevtan Shale Oil Company 1111 2IZITLT,11,NIfi1111ki 11I11 Reeeptiann; 726196 06125/2997 0;T5:41 PIR 8: 1041 P: 0188 Jean Alberico L_..ibit"II", 22 of 36 Rea Fee: 3161.00 Doc Fee:0.00 GARFIELD COUNTY CO iattached to and made R pari of that certain Leltrr Agreement alolcd January 17, 2005, by and between Petroleum Developincnt Corporation and ChevronTerraco Shale Oil Company 8xbl6ti E: To Purcb a ata' Bide Agreement DRted Effective Novern er.11,20O4'By rind Between Petroleum D:evelopidvnt- Corporat3sm,.al'S herr, end Monaca .04a Desaureek LLC, ne Sura ASSIGNIIP OF OXO AND GAS LEASES TfUs ABSTEIT OF OST. AND 17,411 LEASES (lite "Arsigmoo t•')x dated &wive November 1, 2034 at 7:40 ern, Moeu $p Sum*. Ti>r4e (tbo "EffacliYa Titan #s from Petroleums Development Corporation,; a Novadis oor3writian, 103 East. man %let, Bridgeport W,ret 'Virginia 2633D (" Assigi ot'i to $•laeonca Oas 3$,esaraaes, LLC, R Colcaado limited liability attmpway, 730 176 Street; Suite 410,13 envoi, Colorado 8.0202 ("Assignee). For 5100.80 and other good sad valuably canaiderntiee, the receipt sold sufficiencyof which are heresy nclmvwle.4e✓!, Asaiator hereby salla, asaigna, tandem, grunts, bargaizta, rstd conveys an Asalgn** sit of Assignors right, title sad interest in and to the oil and gas leases dmxtihed on RAM A (the "Lessee) insofar and may insofar' az the Lenses covet tic IESDA i dense sibied on Exhibit A (thy "i lade%lorstotl in GarEsid Conran .Colorado. TO HAVE AND TO ROW rho Leases as to •the Lands with all and singular the rights, privileges, and appurtenances rltercto belonging on Mom/Lae appertaining unto Assignee, -i#s• =tenon and asalgas, forever. This Assignment is iisfido and 2eccpLed eailirrssSy subja i to the following terms and conditions• L. 'lois Assigmaeat is subject to a Purchase and Sale Agre :Moot dated December , 2004, effective November 1, 2004, betWoet. Assignor' and Assigacn (Litt= "Purchase Agteemeaf l.:undudhng eternal' drilling obligsliona whiiah 111U3I be satisfied in order far AssigaaaTa retain all orportvina of the Lea/tea •i Lands assigned ttera,mlier, t gediar with omnipotent obfigstivata which mriw• in Viz eYcat that tha•dril mg obligation; sed fntifi,in Ihd Purelnuea Agreement are not satisfied. ALI reassignments of the Luso try Mimeo to Aisigtatr shall be firs attd clear of all lime and esieu obrancsa and aaybuidens on production:bitter than the lessor's royally. provided for in the Leasee end ogle burdens on production oxistipg of sewed as of the affective Time. In addirioll5 the Purtsbase Agroentait contains cettainoonaent to assign provisions, 2. THIS AMON:KEN ' IS ld,4UB WLTROUT ! BM U O itrY 'END EJ4'RES3, 1MPLIED OR STATUTORY; EXCEPT 1TIAT ASSIONOR WARRANTS. TITLE TO TR LRASEg AS xO .E LANDS R.OM AND AUDIS/ ALL PERSOA CLAIMING BY, "THRUM }I AND U3W E ASSIONOis, BUT NOT L T ERWtSF. mar,ri4A tISIR Aa 7:35 PM 19 IllAnnnivirt114114111iiiiilefOriihilititI ON 11111 Reception#; 726196 052310 13dec7 0Rl15:41 Pr B 1941 P 01B9 Jean Biberico Fee 51011 00 Coe Fa. 0 04 0t73FICLD COUNTY CO 3. To the caned .prroatted by lard, Astigore AA ba ttttbrggstcd tta As+igeor's lights in and to Te reseenstiens, waxrl9ttles and Cove hats given with respect to The Leases. Assignor hereby mate and trensiere to Asainaet its cucce;dors anti 439igmto lit axlent so 1170.8'fer 1e sand permitted by taw, the benefit of IMAM Tight 10 r for -e i th4o3var'1u115, ttigirestniatiuns and w arosedns, if may, which A¢sigaor is entitled to &afore., with respect Who, Lows, , but 9uiy io thaea[terttnot cnffOrrod by Assigner Assignee assumes and agrees to pay, per&rras, fit}frltand discharge all claittts, &nate, exponecs, tiabaincr and obligations arming, oe relit5Dg to the awrang, ac-lrtdcpdpg. exploring, upeta.titi{ .or tiltisitaMing dobe I4esea en to toe Tan !g or tlue.produoiag, stastsporting • tattrkating of oil, gas and' other hydro ratio TJ• nom .the tank Wades iP,per1.[Nia 4ft8 ttla Eflcofivo Time, iacindiag; ertih, out limitation, the obligation to plug and obs idoq fill *Us and rsclst 1 all well aites,(untess.proviotedy rmuigaed to Assignor in secortiante with Section Lb of this Asti ett;); and aU obarising ander agreements covering or relating to the tunsria 5510 the Lands, anta,olerepar-ieelrsiy set forth La the ?Limbs!: A mattes t< Ifthere:is n coniiict betvveen the testae of this .Assignment and t:14dr Pathan A$rcentent, the tams or the 8uitthase Agmement shell control and not be destncdta have messed into the tams of tbdi Aisigorgen1 5 The references ttpretn to Ileets, euctw,btaaces, bu dens,.•defeeta and otlter.asgrra shall aol be deemed -lo taffy Or create any dghid in'tltltcl-panics or rndcgc "Mk asadif brlimit oho tiglate of Assignor ur Assispeee, u hctwotatthemselves, u set fordo` in tho Lhasa Apostate= or other documents ace uLed in camnation therewith, 6. Unless provided otheruriae, sU teogrdidig 1aferoaen fat r1w hereto arc: ua lhs nmend . real property tm etdc ©f tiro GerSetd County, Co'orrdo. Cltgk andfEeccutcr. 7, Asst or shall execute, setnowlydge toad dally., or causeto Fre accUtod, notttowlcdged and deliver such it'aattumonts'nod take 803h other ration ns may be restsenahIy necessary or edviseliic.le early oul the pwpoeei acd it11cto of chis esciVeneni. 8. This Ataigomtent binds and inurce to the bsm£t of Aaergeer end Apivee' And their feSinttiY011.14LY5sera and assigns.. G2 •III f��7r�'� I��'a�a1'�,G � �'U il� i '1 til � a 1111 Recept i errq : 726126 013/2E/2007 01AS 41 PM 6, 104/ P 0/90 Seam Alberrcc 24 or 36 Rao PQM ;191 00 Doc F✓tDe•C 00 GARFIELD CQUNTY CO EXECUTD en lata dates contained in tiro ooknowledernent3 of Chir instrument, to bo for all purpooes as of the Effective,'Rmo„ STATE OP COUNTY OF ASSIGNOR: PE/TtOLF Um DE.iIELOPMANT CORPORATION Eric R, Steatrrts, Executive Viee Preejtrgol, Exploration card Development PIC OCE GASR SO1 R.c , X I,C Gregory R. Vigil, Makagrr ACKNOWLEDGEMENTS } } The t'oregeing 1ascrutmEd WaL9 4411vew1043ad before .me•thia day of Deeember,. 2004, by Eric R Steams, as I+icecysiWe Vico President, I pieratiou and 11waiepmwy of Pettoleutp.Developinerst Corporation., A Nevada corporation. Witness my hand sad offioiul seal ;,y cotnmiasien expires: NotaryPutic C-3 •ri.FITIVICA1,14171k1101161041AVIiiiiih 11 IU Receptianti: 725196 0612572007 01:15:41 PM 5 19411 P: 0191 Jean PIBeraco 25 of 36 flee Fee $151 00 Doe Fee 0 00 GPRFIELD COUNTY CO STATE a(JF COLORADO ern- diaND Giy71NrykOE DENVER ) The fa:roping insirumant wai acIMowledgc-LI barons me this _ day of iiecemltee; 200d, by Gregory R. Vigil, ad Dfrmager of Nolan= Gaa Itcanniaca, LLC, 0. Coloradd iiiniled 1iu37ility company, Winmss my haul and of5eial ceol. My ocmrnission expires: Notary Public 11111411tI i INC14111; 1J1EG CICKAL ltd 11111 Recap i ontt: 726196 0612512007 81;15x,41 PM 13! 1949 P- 0192 .lean Albarica 26 of 36 Ram Ftu,f181.00 Doc Fee:0.00 GRRFIFLD COUNTY CO EXHIBIT "C" attached to and made a part of that certain Letter Agreement dined January 17, 2005, by and between Petroleum Development Corporadort and ChevroriTexaco Shale 011 Coirpan.yd LEASE AMENDMENT STATE OF COLORADO C0UI+IT'Y 01? GARPIELD WHEREAS, CHEVRON U.S.A. INC., successor in interest to Chevron Shale Oil Company, hereinafter referred to as "Lessor'', whose address is 11111 S. Wilcrest, Houston, Texas 77099, has entered into the Oil and Cas Leases in Garfield County Colorado with Petroloum Development Corporation, whose address is 103 East Main Street, P.O. Box 26, Bridgepoot, West Virginia 26330, hetcinaticr referred to as "Lessee", described on the attached Exhibit "A", W ERl3AS, rho undersigned parties hereto desire that said leases described oil Exhibit "A„ be amended in the manucr hereinafter set forth/ HOW, THEREFORE, in consideration of the premises and of the bonus and rather rental payments Ilereto fore paid pursuant to said leases and for the additional consideration of Tea Dollars and other good and valuable consideration, receipt of all of which is hereby acknowledged by Lessor, the potties hereby agree to supplement and amend said lease by amending the leases on Exhibit "A" as follows, to -wit: The following language shall ha added to the beginning of Article 6. in each lease on Exhibit "Leasee agrees that on aurface lands owned by Lessor it will not commence any surface activities which are allowed under this agreement without flrgt giving Lessor and Lessor's surface lessee thirty (30) days prior written notice of said activities. Additionally, prior to comer -wing any surface activity (other than surveying) on Lessor's surface lands, Lessee will enter into a written surface damage settlement agreement with Lessor's surface lessee covering the lands to be disturbed and will provide a copy ammo lo Lessor." In all other respects, said leases are unelhanged and remain in full force and effect_ IN W1INF.S,S WHEREOF, the undersigned parties have executed this Amendment on the dare indicated aeiow, LESSOR: LESSEE: CHEVRON (LS.A,11+'0. PETROLEUM DEVELOPMENT CORPORATION By By 0,1, Baldwin II Erie R. Steams Attorney -in -Enact Executive VP Exploration and Development Date I7ato 7'� 1111 l PZ TINr1111 r141 rL i slrit"C' 4161 iL 11111 Receptioni4 7261913 06J2572p07 p1 15 41 PM 9, 1941 P 0193 Jean Alberico 27 or 36 Ree ree 5181.00 Doc Fee -0.00 GARFIELD COUNTY CO STAIR OF TEXAS COUNTY OP HARRIS The foregoing instrument was acknowledged before me this _ day of 2005 by O.F. Baldwin fi as Attorney -in -Fact for Chevron USA. Inc. My Commission E'x?ires: Notary Public STATE C'�P COUNTY OF The foregoing but tnunent was acknowledged before me this day of 2005 by Eric R. Stearns as Executive VP Exploration and Production of Petroleum Development Corporation, My Commission Expires• Notary Public 1111F'= ti%.1'X1101;iG11111.i411'1.%1,149rilMliell r hili 11111 Reeeptiont4: 72e196 06f2612007 01:#5:45 PM 9 1941 P: 0754 Jean Aibarieo 26 of 36 Roc Fee:$11 00 Dao Fee,0.00 OARFIELD COUNTY CO XRT" A" ExhihitA for this lease arncsidme. it is the same spreadsheet that is used as Exhibit Afar the latter agreement. 11111i11.11!11aaltiie4111.141!1+iiili 11111411 41, Mtn 11111 Reception#: 726196 06!2512007 01.15.41 PM B. 1941 P 0155 Jean ALbertco 29 of 36 Rec Fee $161 00 Doc Fee,0.00 GARFIELD COUNTY CO Exhibit "11", attached to and made a part of that r;,eitain Letter Agreement dated January 17, 2005, by and between Petroleum Development Corporation and ChevronTexaco Shale Oil Company (pate) Pet alarm Development Corporation Attention: Dewey Gerdam 3801 Carson Avenue Evans, CO 80620 Consent to Assign CTSOC to PDC Losses Garfield County, Colorado Gentlemen: Reference is made to those =lain Oil and Gas Leases described on Ex/Oil "A" attached hereto, said leases being made a part hereof by reference for all purposes and being hereinafter referred to a "said Gil and Gas Leases " Ns/amen is further made to that certain Iotter dated November 15, 2004, from PDC requesting CllevronTexaeo Shale Oil Company's (CTSOC) consent to an assignment from Petroleum Development Corporation (PDC) to Piceancc Gas Resousees, LLC (POR), whose address is 730 171h Street, Suite 410, Denver, CO 80202, of approximately fifty per cent (50%) ofPDC's interest in said Cil and Gaa Losses. CTSOC rejects PDC'a request for such consent as outlined in its November t5u` letter, however, subject to the following terms and conditions, CTSOC hereby consents to the requested assignment: 1. PDC and POR shall be jointly and severally responsible to CTSOC for all obligations under said Oil and Gas leases, as to the ammo assdgnod by PDC to PGI. 2 Tho transfers of interest shall bo made subject to all site terms and conditions of said Oil and Gas Leases and this agreement. No transfers of such interests traesfcrred to PGR shall be made by PGR to third parties without prior written approval of CTSOC.. 26 1111 VI niroiNgi III Recap tion: : 726196 05f2512007 01:15-41 PM 8 1941 P 0196 .lean Alberica 30 of 36 Roo Fee $181 0O One Fee:0 00 CARFIELD COUNTY CO 4. C.TSOC's consent shall not constitute: a. a novation, :nor b, n weivor of tiro rights and tcencdica available to CTSOC under applicable law, nor c. a waiver of any provision in said Oil and Gas Leases. POR shall iiimish CTSOC a copy of any inatnunenI of assignment made pursuant Hereto with the recording data shown thereon, CTSOC's consent shall not become effective undl a copy of this letter is returned to C i sOC signed by PDC, thus indicating PDC's acceptance of the above terms and conditions, and signed by PGR. thereby recognizing that any agreement between PDC and PGR shall be subject to the above tames and conditions. Very truly, C ievronTexarto Shale OR Company, e division of Chevron U.S.A. Inc, By: ks; ACCEPTED AND AGREED this day of 2005. Petroleum Development Corporation By: ACCEPTED AND AGREED this day of 2005. p seance Gas Resources, LLC By TitIe: �'U •a •-^-in•vfAA�+1MM9o1r1�?fit Ea laiitii'"E' Altadl,cri to and made a pail of Cali cutain Leiter Agreement luted January !7, 2003, by uuJ between Petrolcun i Development Corparatiori sad alma frraco Sim le Oil Courpany X111 hFI7ihi6T,l1:l4iii,{4Kii{iEt:1fi11.6111111 Recepiianti: 726196 06g5l2.007 0+ $5 41 Pin 6 ?oat P 0197 Jean ti:extt +aci al 01 36 Rec Fee $1B1 DO Ooc dee a l0 e:01Or:ELO caUNIv CO CrULC vtCIl.J[TY MAP Ca.sxau t+av,PZ,O M . MC•Ili-a ISA Tnz•trn re, mina sr*. tt OJ Y -�1��av r Fr, s+r 28 ti ■111Ilya =nviciUifilir1 1.14/ClifilleiIIitki 11111 Reception#: 726136 0612512007 01.16.41 PM B. 19n1 P, OPER Jean AJberico 32 of 36 Rec Fee:$1e1 00 Doc Fee,,0.00 GARFIELD COUNTY CO EXHIBIT "D" Construction and Maintenance 1. Construction. The Road shall be constructed in accordance with industry customs and standards, applicable laws and contracts, and in accordance with the following specifications: Phasing Summary of the Garden Gulch Road ProjeetAccess The scope of work necessary to complete the Garden Gulch Road project will utilize a variety of resources including but not limited to geologists, soils engineers, civil engineers, hydrologists, surveying, drillers, blasters, excavators, dozers, etc... Included in these resources would be the anticipated requirement of roadway slope stabilization, mechanically reinforced soil wall construction, drainage appurtenant construction, revegitation and erosion protection. The roadway is separated into three distinct geological features or "phases". These are the Lower Roadway, Clift Face and Upper Roadway. As of January 1, 2006, significant portions of the Upper Roadway have been constructed. The pioneer road for the Lower Roadway has been completed to Sia 57+50 +1-. The benching of the Cliff Face has started and significant progress has been made towards obtaining bench widths that will move the blasting from "pre -split" work to "production" work. Lower Roadway (Sta 0+00 to Sts 90+M) Slope staking and pioneer of the roadway has been completed from Sta 0+00 to the existing rock outcrops located at approx. Sta 57+50. This will provide access for drilling & blasting operations that are anticipated to be required from Station 57+50 to Station 62+00. Not that additional access will be constructed from Station 90+35 back to Station 62+00 to provide benching access for blasting operations. 2. Roadway excavation can occur from Sta 0+00 to 57+50 during the construction of the Cliff Face section of roadway (90+35 to 135+00). Once Cliff Face section of roadway has provided access down to Sta 90+35, contractor mil begin pioneer of roadway down station to 83+50 +1 - At 83+50, it is anticipated that drilling and blasting operations will he necessary to be conducted from 83+50 down station to 80+00+1-. During drilling and blasting of 83+50 to 80+00, roadway excavation can be completed from 90+35 down to 83+50. 4. Once drilling and blasting is completed from 83+50 to 80+00, pioneer of roadway can again be achieved from 80+00 to 70+50. At 70+50, it is anticipated Ihai drilling and blasting operations will be necessary to be conducted from 70+50 down station to 68+54. During drilling and blasting of 70+50 to 68+50, madway excavation can be completed from 80+00 to 70+50. 5. Once drilling and blasting is completed from 70+50 to 68+50, contractor will begin pioneer from 68+50 to 62+00. At 62+00, it is anticipated that the final area of production drilling and blasting will be required. From 62+00 down station to 57+50, it is anticipated that drilling and blasting is required. During drilling and blasting of 62+00 to 57+50, roadway excavation can be completed from 68+50 to 62+00. 6. During roadway excavation, installation of drainage facilities, erosion control and revegetation of disturbed slopes will be conducted. The installation of 24" diameter F-ll]PE culvert pipes will be neecasary on approximately 500' centers. 7. Also during roadway excavation, installation of slope reinforcement will be performed. The amount and locations of slope reinforcement will be dependent upon conditions encountered in the field. 29 11111ArrittickiliNir.hilirocouNif NW 1111 Recaptianti 728196 Q5i?512007 01.15.41 PM B 1941 P 01'It9 Jean RlberIco 33 of 36 Roc Fee 1081 00 Doc Fae.0 00 QPRFIEL0 COUNrr CO CliIT Ince Roadway (Sea 90-5010 Ste 125+001 1. Begin construction of pioneer road at the 7960 contour to establish a bench for drilling and blasting operations. Start pioneer road at 125+00 and proceed northward to 91+00 +!-. This work has been completed. 2. Continue drilling and blasting of 15' wide x 50' deep road cuts from 7960 down to 7$10 contour. At 7810 contour adjust width of bench to optimize cut down to roadway elevation. 3. Begin construction of pioneer road at the 7960 contour fat station 125+00) to the south, down station to the 119+00 contour +/-. This bench will facilitate drilling and blasting operations to for the roadway south of and downhill of 125+00. 4. During blasting operations on the north side of the Cliff Face (90+50 to 105+00), excavation and removal of blast debris will be performed on the south side (125+00 to 105+00). 5. During blaming operation on the south side ante Cliff Face (125+00 to 105-1.00), excavation and removal of blast debris will be performed an the north side (90+50 to 105+00). 6. As each bench is completed, fine &rade the benches lo accommudate drainage. The use of flexible perforated 4" diameter ADS piping, 4x4x6 tees and 6" solid wall flexible perforated ADS piping will be used to collect drainage water and transport it from one bench down to the next. The flexible ADS piping will be utilized by the contractor to hest direct runoff away from his work areas during construction. 7. Dunng roadway excavation, installation of permanent drainage facilities, erasion control and revegetation of disturbed slopes will be conducted. The installation of 24- diameter 11DPE culvert pipes twill be necessary nn approximately 500' centers. 8. Also during roadway excavation, installation of slope reinforcement will he performed. The amount and locutions of slope reinforcement will be dependent upon conditions encountered in the field. llpper Roadway (Ste 125+00 to— End of Project) During construction of the Cliff Face work (90+50 to 125+00). the earthwork c<tntraetor will he able to construct the remaining roadway. This is from 125+00 to approximately 140+87. Al 140+87. the contractor has substantially completed road work excavation to the end of the job 165+00+1-_ 2 Contractor to cut the drainage intercept ditch across the top of the cliff face work above stations 90+50 back south to 125+00 +1-. Contractor to install a 2 Foot deep ditch with 2:1 side slopes at a minimum grade of 2%. Ditch is to drain from north to south. 3. During roadway excavation, installation of permanent drainage titcilities, erasion control and revegelalion of disturbed slopes will be conducted. The installation of 24" diameter HDPE culvert pipes will be necessary un approximately 500' centers. 4. At the 125-00 and 105+00 stations, the installation of 36" diameter IIDPE culvert pipe is anticipated. Similarly at the 117+00 and 112+00 stations, the installation of a 30" diameter ffDPE culvert pipe is anticipated 5. Above 1244-00, and hack station to 117+00, the contractor to cut the drainage intercept ditch across the top of the roadway to intercept off site flows to the culvert pipes{ to be installed at 117+00 and l 12+00. 6. Construct safety berms, drainage cut-outs, line grade and install Type 4 (jersey) harrier as the roadway sections arc completed to provide safe access to the work areas. 30 1111 NI OWE 4114111V.ICOICV 'li11 IN 11111 Receptkonp: 726195 34 or 366 Rac,Fse,SIBPM00 ttaoaFrr.0 0®OGA0RFiBLD COUNTY CO General Comments and Considerations 1. During construction of the project, on-going survey activities will be required to confirm quantities, as-huilt conditions (relative to design) and to verify the accuracy of the topography. 2. Because of very limited access, the on-going surveying will be coordinated with the contractors nn a daily basis so as to facilitate construction The daylight lines and right of way limits cannot be safely staked from 90+50 down station to 57+50 until roadway construction provides access. 3. During construction of the project, it is anticipated that a variety of areas will he found to have unstable slope and foundation areas. These areas will be field evaluated by Yell and A.saociates and means of stabilization will be directed by Ych. 4. Che roadway cross section being provided for this project is a 26' platform width with a 3 foot high berm un the down hill side and a 1 foot deep ditch on the up hill side. 5. The maximum grade from 90+35 up station is 10%. Through the switch back areas, the maximum grade is 514. 6. Alignment and profile grades remain the same from 0+00 to 88+00 as provided by Construction Surveys in their design of the roadway. This is in Iight of the fact that the roadway has aheady been slope staked and pioneered accordingly. One section of 12% roadway is noted frarn station 38450 to 61+00. 2. Maintenance and Operation. Operator shall operate and maintain the Road on a twenty-four hour basis following the construction of the Road. Such duties shall include: a. Maintenance: Operator shall be solely responsible for maintaining the Road in good working condition at all times. The quantity and quality of maintenance shall be in the sole discretion of the Operator. Maintenance shall include, but not be limited to, grading the Road to alleviate damage caused by wear -and -tear or other use; repairing damage caused by weather conditions, such as rain, flood, excessive mud, snow, etc.; periodically adding gravel or appropriate road base when necessary; clearing the Road of debris and obstacles; plowing the Road of snow when necessary; repairing fence lines when required; and rttaintaining access gates in good operating condition. Security: Operator shall ensure security of the Road. Security shall mean maintaining the Road for its intended use and purpose as a private road. Operator shall have sole discretion to determine the measures necessary to maintain security. Security shall include, but not be limited to, maintaining controlled access points to the Road; installing, maintaining, and operating any locked gates; inquiring as to any individual(s) traversing or otherwise using the Road; inspecting the integrity of any fence lines designed to keep animals and or livestock off of the Road; and, where appropriate. informing local law enforcement authorities of trespassers. c. Additional Services: Operator shall perform such additional services with respectto the operation and maintenance of the Road as may be necessary from time to time. 31 1111 in 11I1I ReceptLQn#: 726196 06/2512007 01.15:41 P1 B. 1941 p, 0201 Jean A14ertoo 35 OF 35 Reo. Fee•$101 00 Doc Fee 0 00 GARFLELD COUNTY CO EXHIBIT "E" Payment Cost Sharing. Participants shall bear in the following percentages (each, a "Sharing Percentage") the costs and expenses necessary to construct, operate, and maintain the Road ("Road Expenses") during the period ending on the second anniversary of the Effective Date: Marathon: 25.000% Williams: 25.000% PDC: 25.000% Berry: 12.500% PGR Partners: 6,250% Teton Piceance: 6.250% iota!: 100.000% Ager said second anniversary, Participants agree to use their commercially reasonable efforts to negotiate a new agreement as to the sharing of such Road Expenses, taking into account then - applicable facts and circumstances. Participants shall continue to hear their respective Sharing Percentage shares of the Road Expenses until a new agreement is executed and delivered by all Participants; provided that if the Participants are not able to enter a new cost sharing agreement by the 90th day following the second anniversary of the Effective Date, the Sharing Percentages set forth above shall apply to Road Expenses incurred during the balance of the term of this Agreement. Each Participant shall be severally liable for its Sharing Percentage share of Road Expenses due to Operator hereunder. 1. Payment and Reimbursement of Road Expenses. Operator will be responsible for paying up -front any and all Road Expenses. Unless such. Road Expenses are subject to Section 3 below, after paying the same, Operator will seek reimbursement from each Participant for its Sharing Percentage thereof. The Operator will invoice each Participant for its Sharing Percentage of such Road Expenses. Participants shall pay such invoice within thirty (30) days of receipt. Z. Authority for Expenditure. Prior to the expenditure of any amount of funds to construct, operate, or maintain the Road in excess of FIFTY THOUSAND DOLLARS AND 00/100 ($50,000.00), Operator shall provide each Participant with an Authority For Expenditure ("AFE") detailing the total anticipated costs or expenditures. The Operator shall have sole discretion in calculating the amount of costs and expenditures and determining which costs and expenditures to include in a single AFE. The Operator will provide each Participant with an invoice of the proportionate share owed by it for each. AFE. Participants shall pay Operator their share of the AFE within thirty (30) days of receipt. 32 1111IiiF 1 IV"�� i +�"1 1�'I �11rw9 i'' l� Nil 1111 Reeeptlon6: 726198 06/25/2097 01:15:41 PM B. 1941 P: 0202 Sean AlbertOO 36 of 36 Rec F. $161.00 Doc Fes•0.00 GARFIELD COUNTY GO EXHIBIT "F" Insurance Operator shall carry and maintain the following insurance for the benefit of itself and the Participants. A. Worker's Compensation Insurance. Worker's Compensation insurance covering employees, in compliance with all applicable State and Federal Worker's Compensation laws, and Employer's Liability insurance with a minimum limit of one million and No/100 Dollars ($1,000,000.00).. B. General Liability. Such General Liability insurance shall be endorsed specifically to include property damage coverage arising from explosion, collapse or underground damage, products/completed operations liability, broad form contractual liability coverage which shall provide coverage for contractual liabilities and indemnities assumed herein, and shall have a limit on one million and No/100 Dollars ($1,000,000.00) per occurrence for all bodily injury, illness, death or property damage. C. Automobile Liability Insurance. Automobile Liability Insurance including passengers, covering automobiles owned, non -owned and/or leased by the owners and producers, shall be covered with a limit of not less than one million and No/100 Dollars ($1,000,000.00) each accident for bodily injury, death or property damage. D. Umbrella Liability Coverage. Umbrella Liability Coverage with limits and serving to increase the limits of said coverages four million and No/100 Dollars ($4,000,000.00) any one occurrence, in excess of the coverage outlined in A and B above. Losses for which no insurance is required to be carried or in excess of the limits set forth above, shall be borne by the Parties in proportion to their respective Sharing Percentages, Participants are granted a waiver of subrogation as respects the Workers' Compensation / Employer's Liability Insurance required herein. Each Participant shall be an additional named insurance on each policy. 3529425_6 DOC When Recorded Please Return To: Petroleum Development Corporation 1775 Sherman Street, Suite. 3000 Denver, CO 80203 Attn: Jerini Muller 33 11111 Pr1Wi1IgAI N 1414114M11.11,41114 11111 Reeeption#: 762453 01/3012009 a4:2635 pM Jean 9lberico I of 45 Rec Fee -$226.06 Ooe Fee;0.CO OARFIELO COUNTY CO GARDEN GULCH ROAD UPGRADE AGREEMENT (Bridge Installment across Parachute Creek) /' 5 ' /*k) This GARDEN GULCH ROAD UPGRADE AGREEMENT ("Agreement") is made effective as of November 1, 2008 ("Effective Date"), by and between CHEVRON SHALE OIL CONfPANY, A DIVISION OF CHEVRON U.S.A. INC., a Pennsylvania corporation, with an address at P.O. Box 36366, Houston, Texas 77236 ("Chevron") and MARATHON OIL COMPANY, an Ohio corporation, whose address is 5555 San Felipe Road, Houston, Texas 77056 ("Marathon"). RECITALS A. Petroleum Development Corporation ("PDC"), Piceance Gas Resources, 1.1.0 t"PGR"). nk' Chevron, successor by name change to ChevronTexaco Shale 011 ("ornpam ,` ; S('r(.'). (collectively referred to as the "Original GOR Parties"), agreed to partici'.te in PEX construction of Garden Gulch Road ("GGR"), by letter agreement dated January t7, 2005 ("GGR Letter Agreement"). Under Section 2 of the GGR Letter Agreement, Chevron granted PDC a license to use the GGR, and PDC assumed the responsibility to maintain the GGR. Chevron also granted PDC the right to upgrade the GGR with Chevron's consent. B. As part of Chevron's grant of consent to assign from PDC to Marathon, Marathon agreed b., tetter, dated July 19, 2006, to become a contributor to the GGR and to be isottnd by ,he CGGrr. Letter Agreement ("Marathon Letter Agreement"). C. By letter agreement, dated March 20, 2008, Chevron granted Marathon p.xntission t + in',t I? .t temporary bridge over Parachute Creek to facilitate Marathon's rig moves at M..rathrm's .ole r:.:& and expense ("Temporary Bridge Agreement"), while the Parties continucd their negotiarinr, ; for this Agreement. C. As required by Section 2(h) of the GGR Letter Agreement, Marathon requests Chevron's approval to upgrade the GGR by installing a new road and bridge across Parachute Creek and removing the existing bridge, as described and depicted in Exhibit C. Chevron approves of Marathon's Parachute road and bridge upgrade, provided Marathon conducts the corm truction and upgrade in accordance with the terms of this Agreement. D. In consideration of the mutual promises set out in this Agreement, and tither p.00ti and v41futihle consideration, the receipt and sufficiency of which is acknowlndgod, ChcvrJn fent! M-x...juin agree to be bound by the terms of this Agreement in an effort to upgrarl,. the 4,(3". and in°,!^ii improved bridge structure across Parachute Creek. AGREEMENT 1, DEFINITIONS, INTERPRETATON, AND EXHIBITS LI Definitions. As used in this Agreement, these words or expressions have the following meanings: "Affiliate" means any legal entity which controls, is controlled by, or is under eornmi,.,, control with, another legal entity. An entity is deemed to "control" another it' it owr directly or indirectly at least fifty percent of either of the following: QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1. 201.13 Esecutinn Version Pi� 4 'fr.q.{-G r 01'1 Co ssss sax Feld `-No }o,, . -n066, 1111 Nu* IC LII Ski 111 Reception#; 782463 01130/2009 04:26 35 PM Iran Atherico 2 or 45 Rec Fee $226 00 00c Fee:0 00 GPRFIELO COUNTY CO (A) The shares entitled to vote at a general election of directors o such other emit} . (R) The voting interest in such other entity if such entity does not h tiv;, either shares or directors. "Claim" means any claim, liability, loss, demand, damages, encumbrances, cause of action of any kind, obligation, costs, fines, proceedings, judgments, interest and award (including recoverable legal counsel fees and costs of litigation of the person or entity asserting the Claim and sums paid by 'way of settlement or compromiscj, hether amine. by law, contract, tort, voluntary settlement or otherwise. "Construction Area' has the meaning given in Section 2.3. "Effective Date" shall have the meaning given in the introductory paragraph. "GGR" means that certain road in which the Original GOR Parties agreed to participate under the GOR Letter Agreement. "GGR Letter Agreement" means that certain letter agreement, dated January 17, 2005, between and among the Original GGR Parties and providing for PDC's construction of GGR. The GGR Letter Agreement is attached as Exhibit A. "Installation Area" means the surface of the lands owned by Chevron located in `[ecru 8, Township 6 South, Range 96 West of the 6"' P.M., in Garfield County, Colorado that are more particularly described and depicted an Exhibit C. Installation .',rea ir:clude, is not limited to the Installment Area, Upgrade, Construction Area, and Staging Ar .i lice identified on Exhibit C. "Installment Area' shall have the meaning given in Section 2.1. "Marathon Letter Agreement"" means that certain letter agreement, dated July 14, 2006. under which Marathon agreed to become a contributor to and be bound by the terms of the GGR Letter Agreement, in exchange for Chevron's consent to assigntnLnt from PDC to Marathon. A copy of the Marathon Letter Agreement is attached as Exhibit II, "Original GOR Parties" means Petroleum Development Corporation (•"I'1)1''} Piecur:r Gas Resources, LLC ("POR") and Chevron, successor by mune dianec r, ChevronTexaco Shale Oil Company ("CSOC"). "Party" means Chevron or Marathon and "Parties" mean both of them. "Petroleum Substances" means any mineral, ore, oil, hydrocarbon or natural gas existing in its natural condition in strata of any kind or character, including but not limited to oil, casinghead gas, gas well gas, and any condensate, coal. bituminous shale or other stratified deposits from which oil or gas can be extracted that are produced and severed from, or allocable, after severance, to the Installation Area or any lands adjacent to or adjoining or used for ingress and egress to the Installation Area. QL,S No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November I, 203 Execution version 1111 KVA 4 1.I XVII, 11111 ReceptLona : 762463 01/30!2009 04:26:36 PM Jean Alberico 3 of 46 Rec Fee:5226 00 Doc Fes -0 00 G€3RFIELO COUNTY CO "Staging Area" has the meaning given in Section 2.3. "Temporary Brie Agreement" means that certain letter agr:cnlent, dice \larch ';?, 2008, under which Chevron granted Marathon permission w in, taU a turn; .eeey hi pk.ti over Parachute Creek to facilitate Marathon's rig moves at Marathon's sol: risk aric{ expense, while the Parties continued their negotiations for this Agreement. "Upgrade" has the meaning given in Section 2.1. 1.2 Interpretation. Unless the context expressly requires otherwise, all of the following, apply to the interpretation of this Agreement: (A) The plural and singular words each include the other. (B) The masculine, feminine and neuter genders each include thc: lath r:a. (C) The word "or" is not exclusive. (D) The word "includes" and "including" are not limiting. (E) References to matters "arising" (or which "arise" or "arises") "out of this Agreement" include matters which arise in connection with this Agreement er have a causal connection with or which flow frarn this Agreement or Woich would not have arisen or occurred but for the entering into this Agreement or Ib,. performance of or failure to perform obligations under this Arts:emen1. (F) The headings in this Agreement are included for convenicr:e nod .IG .! I" _ t the construction or interpretation of any provision of, or the right- or ohliu:awr-. of a Party under, this Agreement. 1.3 Exhibits. (A) All of the Exhibits that are attached to the body of this Agreement are en integral part of the Agreement and are incorporated by reference into this Agreement, including: (1) Exhibit A-- GGR Letter Agreement (2) Exhibit 13— Marathon Letter Agreement (3) Exhibit C — Description and Plat of Installation Area (B) If a conflict exists between the body of this Agreement and the !Exhibits, tlrc rir, ly prevails to the extent of the confli et. 2. UPGRADE OF GGR 2.1 GGR Upgrade. Chevron grants Marathon permission to upgrade the GGR at Marathon's sole risk and expense according to the terms of this Agreement. Marathon will construe! .a new section of road, remove the temporary and existing hridges. and replies' with ;a new QLS No. 699361> Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, Execution Version 111i�IA 1��' #1�4J� NNI t i hrOWI � ! '1h 4� 1111 01/3x/2009 04:26135 PM iean Pl6erico 4 of 45 Rec Fee:$226 00 to Fee 0.00 6RRFIELa COUNTY CO bridge within the boundaries of the Installment Area, and according to the plat shown on Exhibit C for the purposes described in Section 3 ("Upgrade"). As shown in Exhibit C, the Installment Area shall be fifty feet (50') in width, the centerline being situated directly over the line depicting the road within the Installment Area. No surface will be disturbed outside of the Installation Area, and at least two lanes will be left open and made available on GOR for use by truck traffic during construction. The Upgrade to be constructed under this Agreement shall be owned and licensed according to the terms o,' the GGR Letter Agreement, (A) Chevron Reserves Certain Rights. Chevron reserves to itself, hs AM Mimics, agents, successors and assigns, the right of ingress to and egress frnrra Installation Area for the purpose of any or all of the following: (1) layrin+, constructing, operating, repairing and removing .1 pipeline or pipeline.,, (2i cutting and removing any and all timber standing, growing and being upon the Installation Area, (3) engaging in a program of reforestation by the planting, seeding and cultivation of additional trees thereon, (4) removing soil and/or dirt from the Installation Mea and (5) testing by seismographic methods or any other method, similar or dissimilar, and of prospecting andfor drilling for Petroleum Substances, with the right to produce, store, treat, process, transport, distill and extract the contents of same on or near the Installation Area. Chevron further reserves the right to erect such structures or buildings and make such excavations as it deems necessary and proper for any and all purposes contained in this reservation, without any liability whatsoever to Marathon for any act- done by Chevron in carrying out such purposes and in performing uny acts incidental t: same. (s) No Warranty. Marathon accepts the Installation Area in its present condition, "AS IS, WHERE IS" and accepts full responsibility therefore, without warranty, express, statutory or implied, as to title, merchantability, condition, quality or fitness for a particular purpose, or any other sort of warranty, without recourse against Chevron. Chevron makes no representations or warranties regarding Marathon's right of ingress and egress from the Installation Area across adjacen' or adjoining lands, (C) Subject to Existing Agreements. This Agreement is made subj t ta, : is existing easements, rights-of-way, licenses, leases and other agrecrricnts a, fee i i the surface or subsurface of the installation Area. Chevron further re crve^ the right to grant other rights-of-way, licenses, leases, easements, and other agreements to third parties to cross over or under the Installation Area to be constructed under in this Agreement. Marathon is responsible for obtaining any necessary third party consents prior to conducting activities on the installation Area pursuant to this Agreement. 2.2 Bridge. Marathon shall remove the existing bridge and temporary bridge and install the new bridge in a safe and prudent manner in compliance with all laws and regulations, and shall properly dispose of all material associated with the existing bridge and its relhoval off of Chevron's property. QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 2038 Execution Version 4 ■ill ilYri KZ'4iair,I*,NAVIN ?ALMA MINN ,IN B M Recept toms( : 162463 01130/2009 04:26:35 PTI Jean R1berlco 5 of 45 Rec Fee:$226,00 Doc Fee:0,00 GRRFIELD COUNTY CO (A) The temporary bridge installed by Marathon under the Tempor,,r isrid 4 Agreement will remain in place until construction of the new to dge plt) i,tt under this Agreement is completed. (B) Marathon shall completely remove the entire existing original bridge and the temporary bridge shown on Exhibit C, including but not limited to, the concrete. base and metal brace on the original existing bridge at the center of Parachute Creek. (C) Marathon shall not operate or conduct any construction in the Installation Are,. between December 1, 2008 and April 1, 2008. Marathon shall also coordinate with Chevron's Ranch Manager before commencing any construction in the Installation Area, as outlined in Section 4 below. Any other opera lot,. stipulations resulting from weather conditions will he given to Marathon h^, Chevron's Ranch Manager at the time of the consultation tmdrr Section 1, Notwithstanding the forgoing, Marathon may request of Chevron in writing an exception to the weather construction restriction set forth in this Section 2,2(C). Chevron may grant or deny the exception in writing at its sole discretion for any reason or no reason. 2.3 Construction and Staging Areas. Marathon may use the "Construction Area" and "Staging Area" identified on Exhibit C to store equipment, materials, and vehicleb associated with construction of the Upgrade. After lie Upgrade is complcte, Marathon shall have no rights to the Construction Area or Staging Area. (A) Marathon may use the Construction Area and Staging Area identified tso 1'_tiou to store equipment, materials, and vehicles associated with the Lpp-ade : lsr: Ilion may also remove trees and conduct earth work in the Construction Area anti. Staging Area, subject to the requirements to coordinate with Chevron's Ranch Manager in Section 4. (B) Marathon shall not disturb any land located outside of the installment Area, Staging Area and Construction Area. Marathon shall not permit Construction Aren or Staging Area to be used for any purposes, including parking, equipment or material storage after the Upgrade is complete. (C) Marathon shall store equipment, materials, and park all vehicles :rssociated with tlaz Upgrade only in the Construction Area and Staging Area identified in Exhit.it C. Any additional storage, parking, or construction surface on Chevron lands .-;hall nt be utilized without prior approval from Chevron. 2.4 As -Built Drawings and Survey. Marathon shall continuously maintain current as -built drawings for the Upgrade and all of its associated facilities located within the Installation Area and will provide Marathon with copies of such drawings within two months of completing any update of drawings for the Upgrade. Marathon shall also provide Chevron with an as built survey prepared by a licensed surveyor of the Upgrade a: constructed within two months of completing the Upgrade. 3. PURPOSE, USE, AND MAINTENANCE OF INSTALLATION AREA QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 2008 Execution Version 111111Ytr' PAii4 t1 LFII 1.14.11.1,44L00>UU1.1,4 111 I18 Receptiantt: 762463 0iJ30J2009 54 25:35 P!1'Jean Alberltzc 6 of 45 Rec Fee:$226.00 Doc Foe 0.00 GARFIELD COUNTY CO 3.1 Purpose. The Installation Area is to be used for the sole purpose of laying, cnnstr t.:611,, operating, inspecting, maintaining, repairing, replacing, and removing a two lane read and bridge for the transportation of equipment associated with Marathon's drilling and development operations, per the terms of the license granted by Chevron under the tOGR Letter Agreement. Marathon and its employees, agents, invitees, contractors, and subcontractors will have rights of ingress and egress to the Installation Area in connection with these purposes. Marathon agrees that no part of the Installation Area shall be used for any purpose except as provided in this Section 3. 3,2 No Interference with Use by Chevron or its Lessees. Marathon shall maintain and operate the Installation Area in such manner that the Marathon's operations witi m rr;, way hinder or prevent the use and enjoyment of Chevron's adjoining prnpet,y, inc: Kling, but not limited to, use of adjoining property for exploration, mining. developrne:tt, anti removal of Petroleum Substances, and farming, ranching and land development operations. In conducting any activities on the Installation Area, Marathon shall minimize disruption and damage to any of the following: (A) the Installation Area and adjacent or adjoining lands or lands used for ingress or egress to the Installation Area; (B) the operations of Chevron's surface lessees; (C) Chevron or any of its lessees' or grantee:-' irrigation systems, crops, grazing livestock, pasture, and other agricultural and grain.• equipment. 3.3 Weeds. In consultation with Chevron's Ranch Manager, Marathon sh:sll eentri l :I invasive weed species in the Installation Area. Marathon shall use such method invasive weed species control as are normal and customary for the arca without po'ir: significant risk to human health or the environment. 3.4 Debris. Marathon will maintain the Installation Area in good repair, clear of debris, refuse and litter. From time to time as necessary, Marathon will clear away any and all refuse and litter and any other debris associated with the Upgrade or maintenance of the Installation Area, and shall ensure same are removed from and properly dispostd in accordance with applicable law off of Chevron's property, If Chevron notifies Marathon of any refuse, litter, or debris on the Installation Area, Marathon shall have thirty Clays from the date of Chevron's notification to clear it away and clean the installation A, ea. Failure to comply with the conditions of this Section 3.4 shall be deemed a breach of the:: Agreement and handled in accordance with Section 15 under this Agreement. 3.5 Improvements. Marathon will maintain at its sole expense all improvements, •. , gates and cattle guards now located on the Installation Area or which may he placed on the Installation Area by Marathon, and will build, maintain and/or erect all nLcessary additional fences, gates and cattle guards as required by Chevron. 3.6 Grass Fires. Marathon shall take all necessary precautions, in conducting its activities under this Agreement, to prevent brush and grass fires. 3.7 Creek Dredging. If Marathon desires to dredge the creek where the bridge is iocatcd, Marathon will be responsible for obtaining all permits and agrees to dispose of any spoil in accordance with all applicable rules and regulations, Marathon shall not Dispose of spoil from dredging on the Installation Area or any other lands owned by Chevron without the prior written consent of Chevron, which may be withheld for any reason or no rt. term. QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November I. 2008 Execution Version b El PailAI Y.IMLILMVI RMI. 1111 Receptiontt: 762463 01!3012009 04:26:35 PM Jean Rlberleo 7 of 45 Red Fee $226 00 Doe Fee:0.00 GARFIELD GOUNrY Gp 3.8 No Petroleum Substances, Agricultural, Hunting, or Fishing Rights, The rigl;ts granted under this Agreement do not include the right to explore for or produce oil, gas ur other minerals, and do not include agricultural, farming, ranching, fishing or hunting tights. Marathon, hs employees, agents, contractors, and subcontractors are prohibited from fishing, hunting or carrying firearms on Chevron lands, including, the Installation Area. 3.9 Trespassers. Marathon will notify trespassers to keep off the installation Area by posting signs at its sole expense unless already posted by Chevron, in which event Marathon agrees to maintain any existing signs during the Tenn, In the event trespasser(s) refuses to vacate or cease trespassing on the Installation Area, Marathon shall promptly notify Chevron. It is understood and agreed that Marathon may exercise any legal right or remedy available to Marathon against any parties not having the express written permission of Chevron to hunt or fish on the Installation Area for the protection of Marathon's rights under this Agreement, whether such right be criminal or civil in nature or available either in equity or at law. 3.10 No public use. All activities permitted pursuant to this Agreement shall be performed by or under the direction of Marathon, and Marathon shall not permit, unless otherwise authorized in writing by Chevron, public easements, public facilities, or public roads over or under the Installation Area. 3.11 Restoration of Installation Area. Marathon shall keep the ln_tatlation Area in taw>ci and safe condition and, after doing any work which disturbs any surface area topside t n' Upgrade, whether inside or outside the boundaries of the Installation Arca, Maratha], shall restore such surface to as good or better than its anginal condition prior b. disturbance. 3.I2 No permanent or temporary structures. Marathon shall have no right to Iocare any additional permanent or temporary surface structures on any part of the Installation Area without the prior written approval of Chevron, which approval is separate from and its addition to any rights granted in this Agreement. Chevron may withhold its approval for any reason or no reason. Marathon shall have no right to use any of Chevron's surface outside of the boundaries of the Installation Area, except rights of ingress find egress u, the Installation Area granted under this Agreement, 3.13 Handling of Top Soil. Marathon shall remove any top -soil from the Installation Art separately from other material removed by Marathon in connection with any activity n, the Installation Area, and shall replace any topsoil removed upon completion of that activity. 3.14 Stones, Brush, and Other Debris. All stones, brush and debris uncovered on, removed from or deposited on Chevron lands as the result of activities permitted under this Agreement shall be disposed of at Chevron's direction and at Marathon's sole cost and expense. 3.15 Drainage and Irrigation Systems and Other Roads, Marathon shall timely replace rebuild, to the satisfaction of Chevron, any and all parts of any road or any drainage QLS No, 699364 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 2008 Execution Version 7 111E 11 111 R4captaon#: 762453 01130/2009 04:25:35 PM Jean Riberio° 0 of 45 Rac Fes $225.00 Don Fee 30 GARFIELD COUNTY CO irrigation system road or other improvement that may be damaged in connection with Marathon's activities conducted pursuant to this Agreement. (A) Marathon shall restore to proper operating condition to Chevron's satisfaction any irrigation systems damaged by the activities permitted under this Agreement. Immediately upon completion of any activity performed under this Agreement, Marathon shall timely repair any damage to open irrigation and drainage ditches by using proper mechanical ditch channel compaction methods and °.y reestablishing pre -disturbance grades and flowlines. All culverts and buried irrigation system pipelines damaged by the Upgrade activities shall h. rep aced by Marathon immediately upon completion of the activity. Marathon shall also permanently restore to field grade any settling or slumping in Chevron's fields and pastures, caused by the activities permitted under this Agreement. (B) (C) Upon completion of the Upgrade, Marathon shall grade all roads on Chevron's lands that were used in connection with Marathon's activities under this Agreement. 3.16 Fences. Marathon shall have the right to cross fences on Chevron property ndjninin, the Installation Area whenever Marathon's crossing shall be reasonably necessar conducting activities permitted under this Agreement. Marathon shall maintain a pr_iG:..r enclosure at all times and shall restore such fences to a condition equal to or bcit_r 6,- 1 their condition prior to Marathon's crossing as soon as crossing is completed. Nothing; in this Section 3.16 shalt be construed to make Marathon responsible for restoration of fencing damaged or removed by any party other than Marathon. its employees, agents, contractors, subcontractors, or invitees. 4. COORDINATION WITH CHEVRON RANCH MANAGER. Marathon shall work in cooperation with Chevron's Ranch Manager to coordinate all activities permitted under this Agreement. At least ten days prior to beginning work on the Installation Area, Marathon .;hal? contact Chevron's Ranch Manager at the phone number listed below with the sipatures to this Agreement, and shall arrange a mutually convenient time to review Marathon's plans fir t„ • installation Area. In addition to verifying that Marathon's plans wilt meet Lila requires onl: Sections 2 and 3, Marathon and Chevron's Ranch Manager will agree upon the tree: +.J ire s„ within the Staging Area and Construction Area. Marathon wilt provide Chevron and road users with a detailed timeline of the Upgrade. 5. COMPLIANCE WITH APPLICABLE LAW. In its exercise of its rights granted under this Agreement, Marathon will comply with all applicable federal, state, and local laws and with all rules, regulations and orders of all regulatory authorities having jurisdiction. 6, NECESSARY PERMITS. Marathon shall obtain and maintain, and ensure shall ensure that its contractors and subcontractors maintain, all licenses, permits, consents, approvals at oth:t authorizations from all governmental or professional or other bodies having jurisdiction which tit necessary for the performance of activities permitted under this Agreement. QLS Nu, 699369 Garden Gulch Road [Upgrade Agreement between Chevron and Marathon, dated Nouember 1, :OOB Execution Version 5 ■SIIIl Bks t r�1'�'lQ+ �6�4,I >rliMIY 11411IIP Receptianti : 762463 01130/2009 04.26 .35 P? Jean A[Aar iao 9 of 45 Rea Fae-$226 00 Doc Fae-0 40 GNRFIELO COUNTY CO 7. LIENS. Marathon will pay all claims for labor and materials that may be Burnished ole its hehalf, and will defend, indemnify and hold Chevron harmless against all liens, encumbrances and Claims that may be filed against Chevron lands as a result of Marathon's activities under this Agreement and all Claims incurred and/or paid in connection with same. 8. TERM. Unless terminated earlier, the term of this Agreement begins on the Effective Date and ends one year from the Effective Date, and shall continue so long as Marathon continues to us and maintain the Upgrade without interruption for more than 180 consecutive days 9. TERMINATION 9.1 Failure to Complete or Cessation of Use. if Marathon fails to cornple Le the l; p. ,u,h:: within one year from the Effective Date, or ceases to use and malint in the Itisl,.tlat.t,r't Area or Upgrade for more than 180 consecutive days at any time alter the Effective Date, this Agreement will automatically terminate. 9.2 Interference with Chevron Operations. (A) If Chevron determines in its sole discretion that Marathon's operations will interfere with Chevron's exercise of its rights to Petroleum Substances, Uhcvron may choose from either of the following options: (1) Terminate the Agreement. (2) Require Marathon to modify or relocate the llpgrads evithi:l t,1: Installation Area or to such other Chevron hinds ..s Chevron direl'ts order to eliminate the interference to Chevron's satisfaction, If Chevron elects to require Marathon to modify or relocate Marathon's operations under this Agreement, all of the following will occur: (a) The Parties shall execute a written amendment to this Agreement reflecting the modification or relocation of the Upgrade under this Agreement, (b) Except as provided in Section 11, if modificative. or re toe ,tr;r:t r,l Marathon's operations occurs prior m i s nuav 13, 2011, shall reimburse Marathon for it+ re;esanabIr. .ami ::.I documented costs of relocating. the Upgrac:c, so'iie•e t I Marathon's obligations to restore under Section 10. (c) Effective January 1, 2018 and thereafter, Marathon agrees to modify or relocate the Upgrade at its sole risk and cost and subject to Marathon's obligations to restore under Section 10, 9.3 Upon termination of this Agreement, Chevron will have the option, in its sole discretion, to either retain the right to use the Upgrade subject to Marathon's obligations Linde: Section 10.1, or require Marathon to abandon and remove the Upgrade and restore_ the Installation Area under Section 10,2. QLS Nu. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 200E Execution Version .t 1111rib lerautotraii,cinehmeliviaRR11111 R.ceptionl: 762463 01130)2009 04:26 35 PM Jean Alberico 10 of 45 Rao Fee $226 00 Doc Fee:0 00 G€3RFIELD COUNTY CO 9.4 Termination of this Agreement under any of its provisions shall not operate to t:xt iguiah any obligations of Marathon which have accrued at the time of termination, nr which accrue upon termination. 10. OBLIGATIONS UPON COMPLETION OF UPGRADE OR TERMINATION 10.1 Restoration. (A) Upon completion of the Upgrade or termination of this Agreement, tviarutl'on shall have one month from completion of the Upgrade or larminalinn of 0.1:. Agreement, as applicable, to restore the Installation Arca and ell areas on Chevron lands areas disturbed by any activity under this Agreement to tht:i, original or better condition. If termination of this Agreement or completion of the Upgrade, as applicable, occurs after October 1, 2008, Marathon shall have until the earlier of June 30, 2009 or one month after Spring 2009 thaw begins to restore the Installation Area and all areas on Chevron lands affected by any activity under this Agreement to their original or better condition. (B) Marathon's restoration obligations under Section 10.1(A) shall include reseeding with seed mixes and planting trees approved by Chevron. Marathon shall continue to reseed and cultivate until successfully reestablishing self sustaining vegetation in the Installation Area. Reseeded areas shall he properly male -ad except in pastures and hay fields. Marathon shall also -pray X11 areas "istrTn, by construction to control noxious weeds for a period of no less than deep growing seasons after completion of the Upgrade or termination of this Agreement, as applicable. 10.2 Chevron's Option to Require Abandonment, Upon termination of this Agreement, Chevron shall have the option in its sole discretion to require abandonment or r..mnval of the Upgrade within the Installation Area. If abandonment is requested by Grantor, Grantee shall leave the Upgrade in a well maintained condition. If a removal of the Upgrade is requested by Grantor, Grantee shall have a period of six months from and after the effective date of termination in which to remove the Upgrade from du Installation Area and comply with its restoration obligations under Section 10 1 10.3 Marathon Release. Upon the termination of this Agreement, in whole or in part, for any reason, Marathon will, within thirty days thereafter, deliver to Chevron an instrument in the county records that reflects that Marathon's rights to the Installation Area under this Agreement have terminated, in whole or in part. If Marathon fails to comply with this obligation within the time required, Marathon authorizes Chevron to file a notice of termination on Marathon's behalf. 11. LIMITATION ON DAMAGES. Under no circumstances shall Chevron have any obligation to compensate Marathon for indirect or consequential loss, including loss of production, petroleum or petroleum products, loss of prospective economic advantage or benefit, or loss of husinerl opportunity, punitive or exemplary damages. 12. MARATHON'S INDEMNITY. Marathon will defend, indemnify and hold Chevron harmless against all Claims (including without limitation attorneys' fees and court costs, costs of investigating Claims, site assessments, testing and remedial actions) incurred and/or paid in QLS ND. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November t, 2008 Execution Version 10 111111 Int 11 11 1 Reception4#. 752463 01130!2003 04:26.35 PM Joan AihariCo 11 of 45 Roc Fee 5226.00 Doc Fee.0.00 GARFIELD COUNTY CO connection with such Claims, arising from or on account of any act or omission by Marathon, its employees, agents, invitees, contractors, and subcontractors, on or relating to this Agreement or the Installation Area. Marathon's defense and indemnity obligation will not apply to Chevron's sole negligence or willful misconduct. If Marathon fails to perform any act required by this Agreement or otherwise comply with any of its obligations under this Agreement, Chevron will have the right but not the obligation to perform the ;act or obligetiou that Marathon failed to perform, and Marathon will fully defend, Indemnify and hold Chevron harmless against all costs and expenses incurred by Chevron in }performing the :arc or obligation that Marathon failed to perform. if Marathon fails to comply fully with dit terms of this Agreement, Marathon will be obligated to reimburse all casts and expers;,s incurred by Chevron in enforcing this Agreement, including but not limited to court costs and attorneys' fees. The provisions of this paragraph will survive termination of this Agreement. 13. INSURANCE 13.1 Neither the minimum policy limits of insurance required of Marathon under this Sectior, 13 nor the actual amounts of insurance maintained by Marathon under its insurance program limit or reduce Marathon's liability and indemnity obligations in thr, Agreement. 13.2 Marathon shall maintain the following insurance and all other insurance reyuitet: by applicable law: (A) Workers' Compensation and Employer's Liability insurance as prescribed by applicable laws. The policy limits of the employer's liability insurance roust not be less than $1,000,000.00 per occurrence. (B) Commercial General Liability (Bodily Injury and Property Damage) insurance, including the following supplemental coverages: Contractual liability to cover the liabilities assumed in this Agreement; Products and Completed Operations; Explosion, Collapse and Underground Hazards; and Sudden and Accidental Pollution. The policy territory coverage must include ail areas where operati.tns are to be performed. The policy limits must not be 1e7s than $10,0UO.( i) combined single limit per occurrence. (C) Automobile Bodily Injury and Property Damage Liability insurance extendi.ili to all vehicles provided by Marathon in the performance of operations. The policy limits for this insurance must be the higher of the amount required by applicable law or $1,000,000 combined single limit per occurrence. 13.3 Policy endorsements. (A) Marathon shall, or shall cause its insurer to, provide Chevron with thirty day..` notice before canceling or making a material change to an insuranc,! policy required by Section 13.1. (8) Waivers of subrogation in favor of Chevron must he included in the worker,' compensation insurance policies required by Section 13.2(A ). QLS "to. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 2008 Execution Version 11 11111411111111DMARTNANIVOrlitlialignilli111111 Receipt. end : 762463 0113012009 04:26 36 PM Joan Albertec 17 of 45 Roc Fse.3226 04 Doc Few 0.0D GARFIEL0 COUNTY CO (C) The insurance required in Sections 13.2(8) and 13.2(C) must include all of the following: (1) Chevron shall be named as additional insureds to the extent of the liabilities assumed by Marathon under this The eoterap•c provided to Chevron as additional insureds must expres.ly inchtrf: liability imposed or sought to be imposed upur: Chevron for el: contributory fault or negligence of Chevron to the extent that M•ir•11he., has assumed such liabilities of Chevron undt:r the a1�?t.erner , (2) A provision that the insurance is primary with respect to all insureds, including additional insureds, and that no other insurance carried by Chevron will be considered as contributory insurance for any loss. (3) A cross liability or severability of interest clause which has the effect of insuring that each insured (including additional insureds) is covered as a separate insured. 13.4 Evidence of insurance. Before performing any operations on the land under this Agreement, Marathon shall provide Chevron with certificates or other docu,iici tt', evidence satisfactory to Chevron of the insurance and endorsements required ender lhir• Section 13. Chevron's acceptance of this certificate does not cons:irate :. waiver, _le ex or modification of any of the insurance coverages and endorsements required under this Section 13. Marathon shall provide copies of insurance policies required under this Agreement if requested by Chevron. Marathon acknowledges that failure to provide a certificate or a copy of a policy or other evidence as required by this Section 13.4 may lead to termination of this Agreement. 115 Deductibles or self-insured retentions. Marathon is solely respunsihle for payment al' all deductibles or self-insured retentions that are applicable to any claims macre �rgsins! Chevron covered by Marathon's insurance policies. The level of these dt'dut:till .s at retentions muse be reasonable and compatible with that expected of i pr: :LI t ;I tl t r:nt7, t1; similar circumstances. 13.6 Waiver of subrogation for Chevron's physical damage insurance. Maramon hall obtain a written waiver of'subrogation in favor of Chevron from its insurers who provide physical damage insurance with respect to property used in the performance of operations. 13.7 Conflict with applicable taw. Marathon will not be required to carry the insurance coverages required in this Agreement to the extent such coverages conflict with, or .,re void or otherwise unenforceable under, applicable laws or regulations. 13.8 Self Insurance. Marathon may satisfy its insurance obligations under this Section l 3 by delivering to Chevron a written commitment to administer a program of self-insurance ;•i a form acceptable to Chevron which satisfies all of the insurance requirements set .carne above. 14. TAXES. Marathon shall promptly pay, before delinquency, all taxes and assessments levied or assessed upon or against the rnstallation Area during the term hereof, by reason of, or resulting QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 2008 Execution Version 12 111 ribs m116111/ ' 11111 Receptionq: 762463 01!30!2009 04,25:35 P11 Joan R1beriao 13 ar 45 Rea Fee:S225,00 doe Feee-0.00 GARFIEI.D COUNTY CO from Marathon's activities under this Agreement in relation to the Upgrade and all associated facilities, and to reimburse Chevron for any increase in taxes paid by Chevron resulting from the value of such Upgrade and associated facilities, whether or not separately assessed_ Marathon shall pay all taxes levied or assessed upon or against the Upgrade and associated faciliiics and operations on the installation Area. l5, BREACH; CHEVRON'S RIGHT TO SUSPEND ACTIVITIES. It' Marathon defaults in t: c performance of any of its obligations under this Agreement, Chevron may ,uspend activnie.. under this Agreement at the sole cost of Marathon effective immediately upon Chevron placing written notice in U.S. Regular mail to Marathon, and may enforce the performance of this Agreement in any manner provided by law. Any attempt by Marathon to interfere with Chevron's exercise of its rights to suspend Marathon's activities for breach shall result in automatic termination of this Agreement. Regardless of whether Chevron suspends Marathon's activities under this Agreement, this Agreement may be terminated at Chevron's discretion if Marathon's default continues for a period of thirty days after Chevron notifies Marathon of such default and Chevron's intention to terminate this Agreement, and Marathon has not cured rite default within such thirty day period or has not undertaken actions reasonably calculated to cure the default within such period and thereafter pursued such actions with reasonable dilieerie . Thereafter, Chevron will have the right, without further notice or demand. to enter the Installs( i Area, remove all of Marathon's personal property that may be located thereon, nal resit: Installation Area to its original condition, without waiving any other remedies io which Chevron may be entitled. If, within ninety days after the date of Agreement terminntiort, Marathon doe: not fully reimburse the costs Chevron incurs in removing and storing Marathon's personal property and restoring the Installation Area to its original condition, then in addition to Chevron's other rights under this agreement, Chevron may dispose of the stored property, retain any proceeds from the sale of such property, and maintain an action against 'Marathon for any deficiency. 16. REMOVAL OF PROPERTY. Buildings, improvements, material, machinery, equipment and other property that may be constructed or placed on the land by Marathon will not became part of the real property but will remain the personal property of Marathon. Marathon will remove ail of its personal property from the land within ninety days following termination of this e green t :. If Marathon fails to remove its personal property from the land within ninety clay; follow* termination of this Agreement, Chevron will have the right but not the obligation to z.sume ownership of same without the necessity of a formal conveyance or bill of sale from Marathon, and/or to dispose of such personal property and retain any proceeds from sale. All machinery and other material, equipment and property associated with the construction of the road and removal of the bridge shall not become part of the real property but shall remain the personal property of grantee. Grantee shall be obligated to remove all personal property placed by grantee within the installation Area within sixty days following the removal of the existing bridge and shall not thereafter be allowed to place personal property within the Installation Area. If -grantee fails to remove its personal property within sixty days following the removal of the existing bridge, grantor shall have the right but not the obligation to assume ownership thereof without rhe necessity of a formal conveyance or bill of sale from grantee, and/or to dispnsc of such persnn•tl property and retain any proceeds from the sale thereof, or should the cosi of disposing oi' personal property exceed the revenue generated by such a sale to recover any shortfall from th . grantee. QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November 1, 211f18 Execution Version 111 nater' #1 Ii+ I I + 1rh'hitliiii 11111 Rseeptlanit: 762453 01130/2069 04:26:35 PM Jean llber,co 14 o[ 45 Rao Fee 5226 00 Dec Fee 0 0O GARFIELD COUNTY CO 17. NOTICES. All notices required or permitted under this agreement must be in writing and delivered by mail (postage prepaid) or by hand delivery to the address of the receiving party set out in the signature page to this agreement, unless otherwise specified in this agreement. Notice may also be delivered by facsimile sent to the facsimile number of the receiving party set nut in the signature page to this agreement provided that the original notice is promptly sent co the recipient by mail (postage prepaid) or by hand delivery. Notices sent by email are ineficeti .. Except as otherwise provided in this Agreement, notices are effective when received t, the recipient during the recipient's regular business hours. Notices which do not wmply 1+i:h requirements of this agreement are ineffective, and do not impart actual or any other kind of notice. 18. CONFLICT OF INTEREST. Conflicts of interest relating to this agreement are strictly prohibited. Except as provided in this agreement, neither Marathon, nor any director, employee. agent of Marathon, shall give to or receive from any director, employee or agent of Chevron any gift, entertainment or other favor of significant value, or any commission, fee or rebate. Likewise, neither Marathon nor any director, employee or agent of Marathon shall, without priu, written notification thereof to Chevron, enter into any business relationship with any director, employee, or agent of Chevron or any Affiliate. unless such person is acting for and on behalf of Chevron. Marathon shall promptly notify Chevron of any violation of this Section. Any representatives authorized by Chevron may audit any and all records of Marathon for the soli• purpose of determining whether there has been compliance with this Section 18. Marathon skull maintain true and correct records in connection with all matters relating to this Agreement and retain such records for at least twenty-four months after termination of this Agreement. 19. PUBLIC ANNOUNCEMENTS. Marathon shall not issue any public announcement or statement concerning the Upgrade or this Agreement without obtaining Chevron's .prior written consent. 211. THIRD PARTY RIGHTS. No Person who is not a party to this Agreement has any rights under this Agreement or may enforce any provision in this Agreement. 21, GOVERNING LAW. This Agreement is governed by and interpreted wider tlhc laws of ria State of Texas, without regard to its choice of law rules, The Panics agree that forum an; • ewe will be exclusively in a court of competent jurisdiction in Houston, /[anis County. Texas. 22. GENERAL PROVISIONS 22.1 Entire Agreement. This Agreement comprises the complete and exclusive agreement between the Parties regarding the Upgrade. and supersedes all oral and written communications, negotiations, representations or agreements in relation to that subject matter made or entered into before the Effective Date. 22.2 Amendment. No amendment to this Agreement is effective unless made in writing; and signed by authorized representatives of both Parties. 22.3 Severability. Each provision of this Agreement is severable. 1f any provision is determined to be invalid, unenforceable or illegal under any existing or future law by a court. arbitrator of competent jurisdiction or by operation of any applicable law, this ()LS No. 59964 Garden Gulch Road Upgrade Agreeme:u between Chevron and Marathon, dated November 1. 2008 Execution Version X111Iffy"e{�4+1'PHAVim14%MIl4+i541111111fMr 11111 Rercept i onl# : 762463 61(30/2009 04:26.35 PI Jean Allnersco 15 o1 46 Roc Fe4,E226.00 Doc Far Q 00 GARFTELD COUNTY CO invalidity, unenforceability or illegality will not impair the operation of or affect those portions of this Agreement that are valid, enforceable and legal. 22.4 Waiver. No waiver by either Party of this Agreement's terms, provisions or conditions shall be effective unless specifically evidenced in writing and signed by or o.n behalf of the Party granting such waiver. A Party's failure to pursue remedies for breach of this Agreement does not constitute a waiver by such Party ofany breach of This Alreenitii o;- raise ,raise any defense against Claims against a Party for breach of this Astreen.,et.. Tie, waiver or failure to require the performance of any covenant or obligation crrultiolLi H this Agreement or to pursue remedies for breach of this Agreement dots not w rive s laler breach of that covenant or obligation, 22.5 Survival. Despite termination of this Agreement for any reason, all provisions in this Agreement containing representations, warranties., releases, defense obligations and indemnities, and all provisions relating to audit, confidentiality, conflicts of interest, insurance, disclaimer of certain remedies, limitations of liability, ownership or use or return of Confidential Information, dispute resolution and governing law, and all enure of action which arose prior to completion or termination, survive indefinitely until, by their respective terms, they are no longer operative or are otta.rwise limited by rs applicable statute of limitations. Each of the obligations and undertakings •:et out in tut,.. Agreement which is not fully performed at termination shall continue in 11: t:e +CIL. termination. 22.6 Counterparts. This Agreement may be executed in any number of counterparts, cavil or which will be deemed an original of this Agreement, and which together will constitute one and the same instrument; provided that neither Party will be bound to this Agreement unless and until both Parties have executed a counterpart, 22.7 Drafting. Preparation of this Agreement has been a joint effort of the Parties and ih, resulting Agreement must not be construed more severely against one of the Parti.:_ than against the other. 22.8 Assignment. This Agreement will be binding upon and inure to the ben_ In of inc f'ina and their respective Affiliates, heirs, legal representatives, succes _ars and ussigm;. Marathon may not assign its rights under this Agreement without Chevron's prior written consent. Such consent may be withheld by Chevron for any reason or no reason. 22.9 Authorized Representatives. Each Party represents and warrants that the Agreement has been duly executed and delivered by its authorized officer or other represenl•ttive and constitutes its legal, valid and binding obligation enforceable in accordnnee with its terms, and no consent or approval of any other person is required in connection with execution, delivery and performance of this Agreement. The remainder of this page left Intentionally blank, QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon. dated November 1, 2008 Execution Version 1111 f °ate'rd1011.1141.114 11111 Recept er1t4: 762463 01)30/2009 0426 35 FT .Yuan Alberseo 16 of 425 Rec Fee $226 00 Doc Fee 0 00 GARF-IELD COUNTY CO IMPORTANT NOTICE: THIS AGREEMENT CONTAINS PROVISIONS RTG,IRDING INDEMNITIES AND WARRANTIES THAT EXPRESS THE AGREEMENT OF THE PARTIES CONCERNING CLAIMS ARISING OUT OF THIS AGREEMENT. The Parties have executed this Agreement authorized representatives of the Parties: CHEVRON U.S.A. INC. Signature: Name: C. e_ in duplicate as Title: Attorney -in -Fact ADDRESS FOR NOTICES: 11111 S. Wilerest Houston, Texas 77099 Attention: Land Manager Facsimile: Ranch Manager Craig Tysse, Ranch Manager — (970)285-9722 evidenced by the rollowing signatures co MARATHON OIL COMPANY Signature: me: inn C. )4.p. ---t' Title: rrl - k�a ADDRESS FOR NOTICES: 5555 San Felipe Road Houston, TX 77056 Attention: Land Manager, Piceance Basin Facsimile: �7 G 3 - - L./ Li QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dated November I, 2009 Execution Version A0 101.-lw1FUR M 1 tri tieroitt Reception : 762463 0113012009 04 26.35 PN Jean Rlberlca 17 of 46 Pec Fee $226 00 ODD Fee 0,00 GARFIELD COUNTY CO EXHIBIT A —GGR LETTER AGREEMENT, DATED JANUARY 17, 2005 SEE ATTACHED. Qt,S No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and :viaralhnn, dated November I, non Execution Version .111 "rt PIV4+I ipokoc# ' I1111 Reception14; 762463 61(36(2095 64 26 35 PM Jean Aiberteo to of a5 Rao Fee S226.DO Doc Fee:0.DO GARFIELD COUNTY Co EXHIBIT B — MARATHON LETTER AGREEMENT, DATED JULY 19, 200,; SEE ATTACHED, QLS No, 699369 Garden GuSch Road Upgrade Agreement between Chevron and Marathon, dated November I, 2008 Execution Version NM 11111111144 11111 ReeeptLcnfl: 762463 0113012009 04.25 35 PM Jean PlberLeo 19 D1 45 Rec Fee $226 Ofl Doc Fee ;0 Pa GPRFIELD COUNTY CO EXHIBIT C — DECRIPTION AND PLAT OF INSTALLATION AREA, INCLUDING UPGRADE, CONSTRUC'T'ION AREA, AND STAGING AREA SEE ATTACHED. QLS No. 699369 Garden Gulch Road Upgrade Agreement between Chevron and Marathon, dared November 1, 2(1(18 Execution Version 1 ChevronTexaeo Shale 011 Company North America Upstream 11111 S. Wilcrest, Houston. TX 77099 P 0 Box 36386. Houston. TX 77236 EXHIBIT "A" ■111Ki41M111 Mil 1 U1 41C14454.1Nrl 1 Reception6: 762483 01/30/2009 04 Z8;35 P11 Se4n A1'nerlco 20 of 45 Rem F■e.1226 00 Doe Feo D 00 ZARFIELO cowry co January 17, 2005 Petroleum Development Corporation Attention: Dewey Gerdom 3801 Carson Avenue Evans, CO 80620 CTSOC to PDC Leases Consent to Assign and Amendment of Leases Garden Gulch Road Agreement Garfield County, Colorado Dear Dewey, ChevronTexaco Per your letter dated November 15, 2004, delivered at our meeting with Orval Baldwin and Enc Steams in Orval's office on November 17, 2004, Petroleum Development Corporation (PDC) has requested ChevronTexaco Shale Oi1 Company, a division of Chevron U.S.A. Inc. (CTSOC), which is successor in interest to Chevron Shale Oil Company, consent to PDC's a_signmtnt to Piceance Gas Resources, LLC (POR) of an approximate 50% interest in CTSOC's leases to f'D in Garfield County, Colorado (defined on Exhibit "A") as same cover the mesa top PDC has further requested that Article 16. of each of the Exhibit "A" leases be atnended to cxt..rnd the well and facilities relocation date (relocation date) past the current date of January 1, 2018. The relocation date is the date at which the responsibility for paying the costs associated with moving existing wells and facilities so that CTSOC may pursue shale operations shifts from CTSOC to PDC. CTSOC is willing to consent to the requested assignment of interest to PGR (attached hereto as Exhibit" B") and to amending Article 16. of each of the Exhibit "A" leases as provided in Paragraph 4 below for each and every well spudded under said leases after the daie ofthr amendment (attached hereto as Exhibit "C"), if PDC agrees to the following: 1. PDC shall execute the Consent to Assign letter agreement (attached hereto l:xhibit `:1") and shall also obtain PGR's execution of said Exhibit "D". Both executed copies of said Exhibit shall then be returned to CTSOC; only upon CTSOC's receipt of such copies of Exhibit "D" executed by PDC and POR shall CTSOC's consent to the assivnmcnt referenced herein become effective. 2. PDC shall proceed with the construction of the Garden Gulch Road (GOR) per the terms of this Item number 2. EXHIBIT "A" January 17, 2005 Page �1f1rii:ittliriaroo ll 4[114.1011:1 1,C1OP liii,111111 Receptiont 762463 C1/3212O09 04.26.35 PM Jean Alberlco 21 of 45 Rec Pee•S226.DO Doc Fee,0 00 GARFIELD COUNTY cO ChevronTexacor a. The route of said GGR shall be the highlighted route on the attached map (attached thereto as Exhibit "E"), said map being dated May 12, 2003 and having been drawn by Construction Surveys, Inc., or an alternative route_ Prior to commencement of construction, PDC and CTSOC shall attempt to reach agreement on the final route for the GGR; if PDC and CTSOC do not agree on e. final route for the GGR by March 1, 2005, CTSOC alone shall chno-e the rout( . PDC shall act as project manager for the GGR building project b. On or before March 1, 2005 PDC will submit to CTSOC a gond la_tli eatinrre of the cost of construction of the GGR_ Said estimate shall he from an independent third party who is in the construction business with experience in making such road estimates. If said estimate exceeds Four Million Five Hundred Thousand Dollars ($4,500,000), PDC shall have the choice of proceeding with the GGR construction, bearing the additional cost above 54,500,000 itself, or it may decline to proceed with the GGR constriction by paying CTSOC One Million Dollars (S1,000,000). This payment to CTSOC must be made no later than March 1, 2005. if this payment is made to CTSOC no later than March 1, 2005, PDC shall be under no further obligation to CTSOC under this agree -ince'. If however, PDC elects to proceed forward, then PDC shill continue fntward under the terms of 2c. below. c. PDC shall determine lithe GGR construction requires any permit or approval from any agency, organization, group, governmental committee or other entity having jurisdiction over such construction. If any perrnit or approval is required, PDC may delay the start of construction until same is acquired. However, if said permits or approvals are not acquired by PDC and construction on the GGR started by May 31, 2005, PDC shall deposit into an escrow account the turn of One Million Dollars (S1,000,000) pursuant to the terms of an escrow a7tcemce.t agreeable to both parties. After making said deposit PDC may cease to pre recd with the permitting and construction of the GOR or it may proceed .r Wi :''ni& if A does proceed with same and completes the permitting and cornrnen: construction of the GGR by December 31, 2005, PDC sh it he crtitr:l-•1 . n refund of the escrow account, otherwise the escrow account funds will he disbursed to Chevron. d. CTSOC shall contribute its surface fee for right-of-way fur the road and $300,000 to the total actual cost for building the GGR. PDC shall fund the remainder of the cost itself or by seeking additional companies or persons as contributors, approval of which must be requested by PDC and obtained from CTSOC prior to their being allowed to contribute toward the cost of the road CTSOC may withhold approval of any such prospective contributor for any reason or no reason. PDC agrees to include any parry as a contributor to the GGR that CTSOC wishes to have included, said party(s) bearing rhei: proportionate share of the costs to build and maintain the CiGR hhsc: ;i t rr,r EXHIBIT "A" January 17. 2095 Page 3 ■ II Wri6 mar'morn*f�� Rev/apt lon4: 782453 01!3012009 04:26:35 PM Jean R1berico 22 of 4G Rec Fea:$226 00 Goo Fee.O 00 GARFIELD COUNTY CO Chevru nTex c anticipated usage of the GGR and on terms similar to other third parties who have been allowed to join in the building of the GGR, if any have been so allowed. lithe total cost to build the GGR exceeds 54,000,000, then CTSOC shall increase its monetary contribution for same by $50,000 for each $100,000 of Increased construction costs up to a maximum total monetary contribution by CTSOC of $500,000. e. If after starting construction of the GGR, PDC or PDC and its contributor h: spent S4,500,000 without completing the GGR, it may choose to stop construction and abandon the project without further penalty, except that it will not leave any dangerous or hazardous condition created by the GGR construction, but will at its own cost make sure the entire construction area is safe before abandoning the project. f. The GGR shall be owned by CTSOC, and CTSOC shall grant PDC a license to use same. PDC will be responsible, at its sole cost and expense, for maintenance of the GGR, and shall perform same on an annual basis in order to retain its license to use the GGR. PDC shall not be able to transfer its license to e• e the GGR nor its duty to maintain the GGR without CTSOC's prior writtcii cons . rit, which consent may be withheld by CTSOC for any reason or no reason. Any other party which has contributed to the building of the GOR pursuant a the terms of this agreement shall be granted a license to use said road for as long as they pay a proportionate share of the continuing annual maintenance costs, said share to be determined by a written agreement to join in the building of the GGR executed by said contributor, by CTSOC and by PDC. g. CTSOC shall not be obligated to pay any maintenance costs on the GGR unless and until it begins using said road to actually mine its minerals or drill its own oil and/or gas wells or begins using same to otherwise actively extract its minerals. At that time, CTSOC shall pay its proportionate share of the maintenence costs for the GGR based on its percentage use of said road versus the other users thereof. h. No party may assign any ponion ot'its license to use the GGR without the prior written consent of CTSOC, which consent may be withheld for any reason or no reason. CTSOC hereby agrees that PGR may use the GGR under PI)C's license; PGR's right to use the GGR under PDC's license shall not be transferable without CTSOC's prior written consent, which consent may be withheld by CTSOC for any reason or no reason. Upgrades of the GGR shall be agreed to by CTSOC and PDC. No third party shall be allowed to use the GOR without paying a fee to be determined by PDC and crsoc (if PDC and CTS()( ^rO unable to agree as to a fee, CTSOC shall set the fee) All fees re:,ei well nay.,= third parties, excluding maintenance fees and fees pard as original contributors under the terms of this Item number 2 shall be divided evenly between PDC' and EXHIBIT "A" January 17, 2005 Page 4 2111 VI 111 11 1 Recept ion's : 762463 01/3012008 04:28.35 PM Jean Alberico 23 or 45 Ree Fae:S226.0 Dna Fee:0.00 GARFIELD COUNTY CO ChevronTexaco CTSOC. Subject to the other provisions of this Item number 2, PDC must have all preliminary studies and any necessary agreements between additional contributors Completed and start actual construction on the GGR no later than May 31, 2005 and proceed diligently with the work until completed_ i. PDC may, at its sole discretion, form a Limited Liability Company (LLC) for tl:r purpose of construction of the GGR, collection and disbursement of hinds for the construction of the GGR and other administration, supervision and accounting for the project as necessary. The parties hereto shall attempt in good faith to resolve any dispute arising out of or relating to this Letter Agreement promptly by mediation under the Center for Public Resources Mediation Procedure then currently in effect before resorting to litigation. 3. Article 6 of each lease listed on Exhibit "A" shall be amended to include the following language at the beginning of said article: "Lessee agrees that on surface lands owned by Lessor it will not commence any .;urlace activities which are allowed under this agreement without first giving Lessor and Lesser' - surface lessee thirty (30) days prior written notice of said activities. Additionally, prior to commencing any surface activity (other than surveying) on Lessor's surface lands, Lessee will enter into a written surface damage settlement agreement with Lessor's surface lessee covering the lands to be disturbed and will provide a copy of same to Lessor. In the event that Lessor's surface Lessee requires a damage settlement that Lessor and PDC deem unreasonable, then Lessor will waive the requirement for a written darnage settlement" 4. Article 16 of each lease listed on Exhibit "A" shall be amended to replace the last sentence of said Article 16 with the following language: "Effective January I, 2018 if Lessor requires Lessee to change, cease or relocate any 1.1:f Lessee's facilities, the costs of same and the lost production therefrom shall be borne as follows: Year 2018: Lessor 17/17ths, Lessee 0/17th Year 2019: Lessor 16/17ths, Lessee 1/17th Year 2020: Lessor 15/17ths, Lessee 2II7ths Year 2021: Lessor 14/17ths, Lessee 3/17ths Year 2022: Lessor 13/17ths, Lessee 4/17ths Year 2023: Lessor 1.2/17ths, Lessee 5/17ths Year2024: Lessor 1l/t7ths, Lessee 6/17ths Year 2025: Lessor 10I17ths, Lessee 7/17ths Year 2026: Lessor 9/l7ths, Lessee 8/ l 7ths Year 2027: Lessor 8/17ths, Lessee 9/l7ths Year 2028: Lessor 7/17ths, Lessee 10/17ths Year 2029: Lessor 6/17ths, Lessee. 11117ths Year 2030: Lessor 5/17ths, Lessee 12/17th: Year 2031: Lessor 4/17ths, Lessee 11. 17th:; Year 2032: Lessor 3/17ths, Lcsser 11/17th Year 2033: Lessor 2/17ths, l.es:.Lc l5/ i; Year2034: Lessor 1/17th, lessee 1E� 17tos Year 2035: Lessor 0/17th, 1.ecsee 17'1"'•h' EXHIBIT "A" January 17, 2005 Page 5 �11� ed.tor ep+ tllf Iva 4 IWr�lr li'f �1��11 11 3 01130/2009 04,26,35 PM Jean Riberico 24 of 45 Rec Fee.3226.02 00c Fse.0.00 GARFIE_D COUNTY CO ChevronTexaco Effective January I, 2035 and thereafter, Lessee agrees to change, cease or relocate inti operations at its sole risk and cost, in order to eliminate an interference and Lessor shall have no obligation to compensate Lessee for lost production restiftinu, from sucl+ el�mi �a ci of an interference" If PDC.agrees with the above, please so indicate by executing in the space provided beto-t and returning a fully executed copy of this letter to my attention at the above addres'-. Thi.: agre;;rnent shall be effective as of the date PDC agrees to and accepts this agreement. Jf you have questions regarding this agreement, please direct them to Lee Parker at 281-551-4725. Sincerely, CHEVRONTEXACO SHALE OIL COMPANY, a division of Chevron U.S.A. Inc. By: O.F. Baldwin II Assistant Secretary AGREED TO AND ACCEPTED this 21 day of u dr, LA- t r -c. 20111 PETROLEUM DEVELOPMENT C RPORATION By: Eric R. Stearns Executive VP Exploration and Development EXHIBIT "A" attached 10 and made a part of that certain Letter Agreement dated January 17, 2005, by and between Petroleum Development Corporation and ChevronTexaco Shale Oil Company CTSOC leases to PDC in Garfield County. Colorado Ls No. Ls Date Lessor Lessee Recording 150498 07/31/01 Chevron Shale Oil Company Petroleum Development Corporation Bk 1312, Pg 166 2 155563 08/26/01 Chevron U.S.A. Inc., succussor in Petroleum Development Corporation Bk 1380, Pg 278 interest to Chevron Shale Oil Company 3 155564 10/24/01 Chevron U.S.A. Inc., succussor in Petroleum Development Corporation Sk 1380, Pg 273 interest to Chevron Shale Oil Company 4 155565 05/12/02 Chevron U.S A. inc., succussor in Petroleum Development Corporation Bk 1405, Pg 498 interest to Chevron Shale Oil Company 5 158014 11/02/02 Chevron U.S.A. Inc., succussor in Petroleum Development Corporation Bk 1447, Pg 568 interest to Chevron Shale Oil Company 6 158348 09/20/01 Chevron U.S.A. Inc., succussor in Petroleum Development Corporation Bk 1447, Pg 563 interest to Chevron Shale Oil Company 55349 11/15/02 Chevron U.S A, Inc., succussor in Petroleum Development Corporation Sk 1447, Pg 573 .nterest to Chevron Shale Oil Company 8 -'75350 11/15/02 Chevron U.S.A. Inc., SUCCLSt- Jr !n Petroleum Development Corporation Sk 1447. `"7 2- in`arest to Chevron Shale Oil Ccmnp. _ny -73351 11/15/02 C'.:•vrrn U 5A ono., suc usscr Petroleum Deveionm—h:Colpoialion Bk 14117. "., ='-r• to Chevron Shalt, ikuf.Agteli1 # i° 4 VP. Receptior,t - a i r50l 2009 21.- - = ree r e'co _5 or 5 ReG C ca Gr FitLi" Exhibit "B", EXHIBIT "A" attached to and made a part of that certain Letter Agrecrnent dated January 17, 2005, by .rid between Petroleum Development Corporation and ChevronTexaco Shale cid Col i poIry Exhibit C To Purchase and Sale Agreement Dated Effective November IS 2004 By and Between Petroleum Development Corporation, as Seller, and Ficeance Gas Resources, LLC, as Buyer ASSIGNMENT OF OIL AND GAS LEASES SIS ASSIGNMENT OF OIL AND GAS LEASES (the "Assignmcat'), dated effective November 1, 2004 at 7:00 a.m., Mountain Standard Time (tile 'Erre-Ave Time"), is from Petroleum Development Corporation, a Nevada corporation, 103 East Mails Stree.., Bridgeport, West Virginia 26330 ("Assignor") to Piceance Gas Resources, LLC, a Colo -ride. limited liability company, 730 110' Street, Suite 410, Denver, Colorado 80202 ('•Assigns ") Tor $100:00 and other good and valuable consideration, the receipt and sufficiency of which =hereby acknowledged, Assignor hereby sells, assigns, transfers, graa.ts, bargains, and conveys o Assignee ell of Assignor's nght, title and interest in and to the oil and gas leases described on ExhibitA (tire "mases) insofar and only insofar as the Leases cover the lands described on Mbit A (the "Lands"), located in Garfield County, Colorado. TO HAVE AND TO HOLD the Leases as to the Lands with all and singol.r the right - privileges, and appurtenances thereto belonging or in anywise appertaining unto Ass47.ioc, its successors and assig s, forever. This Assignment is naade and accepted expressly subject to the following terms and conditions: 1. This Assignment is subject to a Purchase and Sale Agree:merat dated December_, 2004, effective November 1, 2004, between Assignor and Assignee (the 'Purchase Agreement"), including, certain. drilling obligations which must be satisfied in carrier for Assignee to retain all or portions o the Leases and Lands assigned hereunder, together with reassignment obligations which arise in the event that the drilling obligations set forth it the Purchase Agreement are not satisfied. All reassignments. of the Leases by Assignee to Aa:igcor shall be free and clear of all liens and encumbrances and any burdens on producri+dn other tbs.;r the lessor's royalty provided for in the Leases and other burdens on production existing o£ record as of the Effective Time. In addition, the Purchase Agreement contains certain consent to assi a provisions. 2. THIS ASSIGNMENT IS MADE WITHOUT WARRANTY OF ANY KIND EXPRESS, IMPLIED OR STATUTORY, EXCEPT THAT ASSIGNOR WARRANTS TITLE TO THE LEASES AS TO THE LANDS FROM AND AGAINST ALL PERSONS CLAIM' NG BY, THROUGH ANL UNDER ASSIGNOR, BUT NOT OTHERWISE. v6O7834.4 E21DVG4 3-3: FM • u w tro no g. o tee, M:. EXHIBIT "A" 3. To the extent permitted by law, Assignee shalt be subrogated to Asssgtor's rigl.•r:; in. and to representations, warranties and covenants given with respect to the Lea:ff. As-ign hereby gams and transfers to Assignee, its successors and assigns, to the extent .a transferable and permitted by law, the benefit of and the right to enforce the covenants, renreser.tations and warranties, if any, which Assignor is entitled to enforce with respect to the Leases, but only to the extent not cnforccd by Assignor, 4. Assignee assumes and agrees to pay, perform, fulfill and discharge all claims, costs, expenses, liabilities and obligations accruing or relating to the owning, developing, exploring, operating or maintaining of the Leases as to the Lands or the producing, wausportinE. and marketing of oil, gas and other hydrocarbons from the Lands, relating tc periods aiiler th : Effective Time, including, without limitation, the obligation to plug and abandon all wells a,itt reclaim all well sites (unless previously reassigned to Assignor in accordant. . with Se tion ] .b )1 this Assignment), and all obligations arising under agreements covering or relating to tlue l:,j.,srs as to the Lands, all as more particularly set forth in the Purchase Agreement. If there is a conflict between the torus of this Assignment and the Purchase Agreement, the titres of the Purchase Agreement shall control and not be deemed to have merged into the terms of this Assignment. 5. The references herein to liens, encumbrances, burdens, defects and other matters shall not be deemed to ratify or create sny rights in third parties or merge with, modify or limit the rights of Assignor or Assignee, as between themselves, as set forth in the Ptrrchase Agreement or others documents executed in connection therewith. 6. UrliESE, provided otherwise, ail recording iefermcts in the Exhibit: lwerelo the official real prnpartyrecords of the Garfield County, Colorado, Clrik and Re, order. 7. Assignor shall execute, acknowledge and deliver or cause to be exr.cucco, acknowledged and delivered such instnunents and take such other action a$ uiay be reasonably necessary or advisable to carry out the purposes end intents of this assignment. S. This Asngnment binds and inures to the benefit of Assignor and Assignee and their respective successors and assigns. C-2 EXHIBIT "A" EXECUTED on the dates contained in the acknowledgments of this ins trumOM, to he for all purposes as of the Effective Time. STATE OF ASSIGNOR: PETROLEUM DEVELOPMENT CORPORATION Eric R.. Stearns, Executive Vice President, Exploration and Development DANCE GAS RESOURCES, LLC Gregory R. Vigil, Manage: ACKNOWLEDGEMENTS COUNTY OF ) The foregoing instrument was acknowledged before me this flay of December, 2004, by Eric R. Stearns, as Executive Vice President, Exploration and Development, of Petroleum Development Corporation, a Nevada corporation. Witness my band and official seal. My commission exp res: Notary Public C-3 STATE OF COLORADO EXHIBIT "A" } CITY AND COUNTY OF DENVER ) The foregoing instrument wad aektiowledged before me this day of December, 20O4, by Gregory R. Vigil, as ivianager of Picean.ce Gas Resources, LLC, a Colorado 1uritcri liability company. Witness my hand and official seal. My commission expires: Notary Public C-4 1 EXHIBIT "A" EXHIBIT "C" attached to and made a part of that certain Letter Agreement elated },rnuary 3i, 200, ' and between Petroleum Development Corporation and ChevronTexaco whale 0;1 Company LEASE AMENDMENT STATE OF COLORADO COUNTY OF GARFIELD WHEREAS, CHEVRON U.S,A. INC., successor in interest to Chevron Shile 011 Company, hereinafter referred to as "Lessor", whose address is 11111 S. Wileresi, lieu tun, I'cx<a • 77099, has entered into the Oil and Gas Leases in Garfield County Colorado with Petroleum Development Corporation, whose address is 103 East Main Street, P.O, Box 26, Bridgeport, West Virginia 26330, hereinafter referred to as "Lessee". described on the attached Exhibit "A", WHEREAS, the undersigned parties hereto desire that said leases described on Exhibit "A" be amended in the manner hereinafter set forth: NOW, THEREFORE, in consideration of the premises and of the bonus and other rental payments hereto fore paid pursuant to said leases and for the additional consideration o FTcn Dollars and other good and valuable consideration, receipt of all of which is hereby aclrnowiedgcd by Lessor, the parties hereby agree to supplement and amend said lease by amending~ the lease; on Exhibit "A" as follows, to -wit: The following language shal! be added to the beginning of Article 6. in each lease tar t ,flit "A". "Lessee agrees that on surface lands awned by i.essor it will not eommcnve any surface activities which are allowed under this agreement without first giving Lessor and Lessor's surface lessee thirty (36) days prior written notice of said activities. Additionally, prior to commencing any surface activity (other than surveying) an Lessor's surface lands, Lessee will enter into a written surface damage settlement agreement with Lessor's surface lessee covering the lands to be disturbed and will provide a copy ornate to Lessor." In all other respects, said leases are unchanged and remain in full force and efFect- IN WITNESS WHEREOF, the undersigned parties have executed this Amendment nn the date indicated below. LESSOR: LESSEE: CHEVRON U.S.A. NC. By O,F. Baldwin II Attorney -in -Fact Date PETROLEUM DEVELOPMENT CORPORATION By Eric R. Stearns Executive VP Exploration and Development Date CC. EXHIBIT "A" STATE OF TEXAS COUNTY OF HARRIS The foregoing instrument was acknowledged before me this _ day of 2005 by O.F. Baldwin II as Attorney -in -Fact for Chevron U.S.A. Inc. My Commission Expires: Notary Public STATE OF . COUNTY OF ) ) The foregoing instrument was acknowledged before me this day of 2005 by Eric R Stearns as Executive VP Exploration and Production of Petroleum Development Corporation. My Commission Expires: Notary Public ,'#rIRlff 1u 11 ��If1 i 7f11��I i� i EXHIBIT "A" EX3i1BT "A" Exhibit A for this lease amendment is the same spreadsheet that is used as Exhibit A for the letter agreement. EXHIBIT "A" Exhibit "D", attached to and trade a part of that certain Letter Agreement dated January 17, 2005, bre• and between Petroleum Development Corporation and ChevronTexaco Shale Oil Company (Date) Petroleum Development Corporation Attention: Dewey Gerdom 3801 Carson Avenue Evans, CO 80620 Consent to Assign CTSOC to PDC Leases Garfield County, Colorado Gentlemen: Reference is made to those certain Oil and Gas Leases described an Exhibit "A" attached hereto, said leases being made a part hereof by reference for all purposes and being hereinafter referred to as "said Oil and Gas Leases." Reference is further made to that certain letter dated November 15, 2004, from PDC requesting ChevronTexaco Shale Oil Company's (CTSOC) consent to an assignment front Petroleum Development Corporation (PDC) to Piceance Gas Resources, LL (PGR), whose address is 730 17th Street, Suite 410, Denver, CO 80202, of approximately C1 iv pe (50%) of PDC's interest in said Oil and Gas Leases. crsoc rejects PDC's request for such consent as outlined in its November 1591 letter, however, subject to the following terms and conditions, CTSOC hereby consents to the requested assignment: 1. PDC and PGR shall be jointly and severally responsible to CTSOC for PA obligations under said Oil and Gas Leases as to the acreage usii eci by PDC I:1 PGR. The transfers of interest shall be made subject to all the terra:; ..n1 eouul tic Oil and Gas Leases and this agreement. 3. No transfers of such interests transferred to PGR shall be made by PGR to third parties without prior written approval of CTSOC. F,10 GOJN1Y Lrl EXHIBIT "A" 4. CTSOC's consent shall not constitute: a a novation, nor b. a waiver of the rights and remedies available to CTSOC under applicable law, nor c. a waiver of any provision in said Oil and Gas Leases. 5. PGR shall furnish CTSOC a copy of any instrument of assignr,.tit mad+nor: ta: • hereto with the recording data shown thereon. CTSOC's consent shall not become effective until a copy of this letter is returned to CTSOC signed by PDC, thus indicating PDC's acceptance of the above terms and conditions, and signed by PGR, thereby recognizing that any agreement between PDC and PGR shall be subject to the above terms and conditions. Very truly, ChevronTexaco Shale Oil Company, a division of Chevron U.S.A. Inc. By: Its: ACCEPTED AND AGREED this day of , 2005 Petroleum Development Corporation By: Title: ACCEPTED AND AGREED this day of , 2005. Piecanee Gas Resources, TLC; By: Title: VIAVIwrh 4 iMil 1 '1UN1Y CO 29. ge rbM1 ""lb.';74 nF = `r• "- ,e• 5. 0 4 :aty fiTir.. ACK IhitAt;'iir;' s —rorrovir Exhibit "E" Attached in and made a part of that certain Letter Agreement dated January 17, 2005, by and between Petroleum Development Corporation and ChovronTexaco Shale Oil Company EXHIBIT "A " L POFOEN6111...C1-1 ROAD VICINirr MAP CON9MUCT;r71.1 ifurysr* Crdlla S.Airtgal SILT, GO .01442 r0-4116-1011,3 PrigrARE111041 N110.01.41 OCKlThltrt OOP, KU East Nee ie Wrs, IS \ — ' Hret Chevron /IMO 1%.° EXHIBIT "B" Petroleum Development Corporation Attention: Eric R. Stearns, Executive Vice President 3801 Carson Avenue Evans, CO 80620 Consent to Assign CSOC leases PDC to Marathon Garfield County, Colorado Gentlemen cr 141d-Cantiment Businmc• Unit Chevron U.S.A. Inc. 11111 5. Wikrest, Houston, TX 77099 P.O. Bax 36366, Houston, fl 77236 n I rl Reference is made to those certain Oil and Gas Leases described on Exhibit "A" attached hereto, said leases being made a part hereof by reference for all purposes and being hereinafter referred to as "said Oil and Gas Leases." Reference is further made to that certain letter dated June 21, 2006 from (Petroleum Development Corporation (PDC) requesting Chevron Shale Oil Company's (CSOC) consent to an assignment from PDC to Marathon Oil Company (Marathon), whose address is 5555 San Felipe Street, Houston, Texas 77056, of all of PDC's interest in said Oil and Gas Leases CSOC rejects PDC's request for such consent as outlined in PDC's June 21, 2006 letter, However, subject to both PDC and Marathon's acceptance and agreement to the Let.m.:..its conditions which follow, CSOC hereby consents to the requested assignment of the leases and acreage as described on Exhibit "A" hereto: PDC and Marathon shall be jointly and severally responsible to CSOC for all cbligations under said Oil and Gas Leases as to the acreage assigned by PDC to Marathon, 2. The transfers of interest shall be made subject to all the terms and condition- of said Oil and Gas Leases and this agreement. 3. Marathon may not transfer any interest in any of the Oil and Gas lease:. In any shirr+ party without prior written approval of CSOC. Said consent by CSOC may be withheld for any reason or no reason. 4 CSOC's consent as set forth herein does not and shall not constitute: ;17. cOUI CO s EXHIBIT `93" July 19, 2004 Page 2 a. A novation, or b. A waiver of the rights and remedies available to CSOC under applicable law, or c. A waiver of any provision in said Oil and Gas Leases. 5. Marathon shall furnish CSOC a copy of any instrument of assignrnent made pursuant hereto with all recording data shown thereon. 6. On or before December 15, 2007, Marathon shall drill and test the Dakota formation in a well located on the Oil and Gas Leases (Dakota Test Well), or on other leases owned by PDC, with testing methods that have been reviewed and approved by CSOC. if, due to unforeseen circumstances encountered during the drilling of the Dakota Test Well, the Dakota formation is not tested in the Dakota Test Well by December 15, 2007, .then Marathon shall drill or deepen a second well on the Oil and Gas Leases (Second Dakota Test Well), and shall test the Dakota formation with testing methods that have: i>ee. reviewed and approved by CSOC. 1f the Dakota formation is tested in the Dakota Tea: Well, Marathon shall not be required to drill the Second Dakota Test Well. The test of the Dakota formation in the Second Dakota Test Well must be completed by February 15, 2008, unless otherwise agreed by CSOC. In the event the Dakota formation does not appear productive in either the Dakota Test Well or the Second Dakota Test Well, then Marathon shall perform a water injection test using methods approved by CSOC. Tht drilling, completing, and testing of the Dakota Test Well and Second Dakota Test Wel+ shall be at Marathon's sole cost and expense. 7. If unforeseen circumstances encountered during drilling prevent. successful L1:kot formation test by February 15, 2008, in either the Dakota Test Well or the Second Test Well, then Marathon shall not be required to drill or deepen any additional wells tc the Dakota formation, 8. During the drilling of the Dakota Test Well on any portion of the Oil and Gas Leases, or other leases owned by PDC, and at Marathon's sole cost and expense, Marathon shall obtain two (2) sixty (60) foot core from the Mancos Shale for shale gas potential investigation, and shall deliver such cores to the core laboratory of CSOC's choice ror analysis, which shall be conducted at Marathon's sole cost and expense. Marathon sh.aIl obtain CSOC's approval of the precise section to core, and shalt obtain and follow a core protocol and core analysis from CSOC, prior to spudding any well in which cctiing is required or anticipated. Marathon shall obtain both cores from one well. In the: even( that the Second Dakota Test Well is drilled, and two (2) sixty (60) foot core intervals are not recovered from the first Dakota Test Well, then Marathon shall obtain two (2) sixty (60) foot cores from the Second Dakota Test Well. The requirement to obtain two sixty foot cores shall encompass Marathons reasonable effort to acquire same and will not require the drilling of a Second Dakota Test Weil, or substitute well for the purpose of satisfying this requirement Nil V 2 EXHIBIT "B" July 19, 2004 Page 3 9. Within two (2) weeks of the completion of any well on the Oil and Gas Leases, Marathon, or PDC shall deliver to CSOC electronic formats of all information relating to such operations including but not limited to daily drilling reports and logs, well tests, completion data, and pressure tests, cores and samples obtained in connection with such operations. 10. The parties shall execute such documents as are necessary to provide that Item 12 of the leases be modified to reflect that the maximum acreage that can be held by any producing well be limited to the quarter section within which the well is located, or 160 acres, whichever is greater. Further, a well shallbe considered as "capable of producing oil of gas is paying quantities" as used in Item 12 of the base lease for each of the letsc.x outlined on Exhibit A, if the well has been drilled, cased for production dnd fracrur.. stimulated. Notwithstanding the foregoing, in the event that a Dakota 'T'est Well is completed as a well capable of producing in paying quantities then die acreage hold by such Dakota well shall encompass the greater of the spacing unit as per applicable state oil and gas regulations c ' 160 acres. 11. Al! surface use by Marathon or PDC on CSOC surface must be approved by CSOC, and Marathon and PDC must comply with any environmental conditions or constraints imposed by CSOC on CSOC surface. 12. CSOC's consent shall not become effective until a copy of this letter is renamed to CSOC signed by Marathon and PDC, thus indicating Marathon and PDC's acceptance of' the above terms and conditions, and recognizing that the above terms and conditiote2 constitute an agreement by and between CSOC, Marathon and PDC, and an agrcernena that Marathon and PDC's leasehold interest is subject to the above terms and conditions. 13. The Parties agree that PDC may assume certain obligations with regard to satisfaction of the terms of the consent as outlined above, as may be agreed upon by PDC and Marathon Any re -assignment of wellbore rights and interests in said Oil and Gas Leases from MOC to PDC upon PDC's drilling of any well on leases covered by this consent to assign shall not require any additional consent by CSOC. 14, The terms set forth in paragraph 2 of that certain Letter Agreement dsiUti )autuary I 2005 by and between Chevron and PDC (the "GGR Agreement '), includin„ subparagraphs (a) through (i) of that paragraph 2, shall extend to Marathon, such that the agreement between Petroleum Development Corporation (PDC) and CSOC, as set forth in such paragraph 2, shall serve as an agreement between CSOC and Marathon. Marathon shall be considered a contributor to the GGR, as set forth in subparagraph 2(d) of the GGR Agreement, and shall bear its proportionate share of the costs to build and maintain the GG1t, based on Marathon's anticipated usage of the CsGR. Marathon shall enjoy the same rights of usage of the GGR as granted to PDC under paragraph 4(O of th,r GGR Agreement. 4',1,4"PittAk10,1 0 u r. • 3t 11 d1 �a 140 g x1N V; i, — to _!:.‘ EXHIBIT "B" July 19, 2004 Page 4 Very truly yours, Chevron Shale Oil Company, a division ofChcvron U.S.A. Inc. By: 1t8' ATM" Alf P'- id- ltG ACCEP`i'FD and AGREED this t114 day of Jur , 2006_ Petrottr, Development Corpcxati Br. EXE61r tv ✓t }6 eig3,p FFC; ACCED and AGREED this 2-0` - 3ay of J r/ C� Marathon Oil Company • rClOp▪ ol 1..t , 2006 2006. CHEVRON :iii= 150498 660500 155563 686700 155564 685800 158349 691300 EXHIBIT "A" Chevron U,S.A. Inc. Chevron U.S.A. Inc. Chevron U.S.A. Inc. Chevron U.S.A. Inc. Petroleum Development Corporation Petroleum Development Corporation Petroleum Development Corporation Petroleum Development Corporation 1312 166 1380 278 1380 1447 273 573 593765 609462 609481 623086 7/31/2001 8/26/2001 10/24/2001 11/15/2002 6S 6S 6S 63 6S 96W 97W 97W 96W 96W 5 W2NE14 ads Lots 2 (33.79), (42.70), 10 (43.13) 22 14 5 6 NE/4 except wellbore of the CSOC 697-22 N1 SW/4 except wellbore of the CSOC 697-14 #11 100.00% 81.26% 100.00% 100.00% 81 25% 81.25% Eaton Basic Agmt. No. 9 Fee. 65. 100.00% 81.25% 96W G.J.N. #1 Sec. 5: Lots 14 (42.00) and 21 (30.98) G.J.N. #2 Sec. 5: Lots 19 (41.61) and 23 (30.67) R.L. Eaton Agmt. No. 3 Fee, GS, 95W Placer Mining Claim Sec. 6: 11 and 2Unocal Trade Fee, 6S, 96W Consolidated No. 5 Claim Sec. 6: SI2SW14 Cor.3oiidaled No. 6 Claim See. 6: N12SW/4 Consolidated No. 7 Claim Sec 6: Lots 15 (40.00) and 16 (43.91) Consolidated No, 8 Claim Sec. 6_ Lots 9 (43.92) and 10 (40.00) Consolidated No. 9 Claim Sec. 6: Lots 7 (4000) and 6 (43.93) 1111111I p`.aaeot i ors# : 762463 it l' ./:109 i`4 26,3E PM Jean F1ber.t'c. -�} :� 'fr. CO 4J .,1 .% a. : r€e 6225.0C Dec fee :, «g„ lls1Hx1 CHEVRON EXHIBIT "A" 158350 691400 Chevron U.S.A. Inc. Petroleum Development Corporation 1447 579 623087 11/15/2002 65 78 58 5S 55 2 96W 96W 96W 96W 96W 18 5 19 20 29 Eaton Basic Agmt. No. 10 & 11 Fee, 6S, 96W Midland #2 Sec. 18: Lots 1 (38,43), 2 (34.02) and WI2NE14 Midland #4 Sec. 18: SW/4 D.D. Potter No. 12 Fee, 7S, 96W Grand View No. 4 Placer Mining Claim, Sec. 5: SW/4 Grand View No. 7 Placer Mining Claim, Sec. 5: Lots 3 (35.66).4 (35.41) and S/2NW14 Grand View No. 8 Placer Mining claim, Sec. 5: Lots 1 (32.62), 2 (35.84), 5 (36.34) and SW/4NE14 Eaton Basic Agreement No. 1&2 Fee, 100.00% 5S, 96W French #12 Sec. 19: NEI4NE14 Eaton Basic Agmt. No. 5&6 Fee, 59, 96W French No. 9&10 Sac. 19: Lots 3 (50.91) and 4(50.71) French No. 11 Sec. 19: S/2NE14 Eaton Basic Agreement No. 1&2 Fee, 55, 96W Federal #26 Soc. 20: NE/4 Eaton Basic Agmt. No. 5&6 Foe, 58, 96W French No. 26&27 Sec. 20: SW/4 R.L. Eaton Agmt. No. 1 Fee, 58, 96W Federal No. 29 Placer Mining Claim Sec. 29: S/2NE/4 Eaton Basic Agreement No. 1&2 Fee, 55, 90W N12 of Federal #29 Sec. 29: N/2NE14 Ealbn Basic Agmt. No, 5&5 Fee, 5S, 96W French No. 28&29 Sec. 29: SW/4 81.25% 1111 ;lir, itrtR111141 144 1".146r14MNYa"iirrIti 1 " 11 H Regie Lror : 762463 C'''C! x "4.28 35 Pt1 Jean Alber ice a. nr `• Pr V. 522E 00 Rae Fee 0 U` t LC +1:-v _� «ff„ JI IIHX1 HEVRONT: :'Wim' lG;rIASE EXHIBIT "A" 5S 5S , 55 5S 55 55 J A.3 96W 96W 96W 96W 96W 96W 30 31 32 33 34 35 Eaton Basic Agmt. No. 586 Fee, 58, 96W French No: 5&6 Sec. 30: Lots 3 (50.20) and 4 (50.02) French No. 788 Sec. 30: NEM Eaton Basic Agmt. No, 586 Foe, 5S, 96W Frenal No. 182 Sec. 31: Lots 3 (50.23) and 4 (50.34) French No. 384 Sec. 31: NE/4 Eaton Basic Agmt No, 586 Fee, 5S, 96W French No. 30831 Sec. 32: NE/4 R.L. Eaton Agmt. No. 1 Fee, 5S, 96W The Virginia No. 1 Placer Mining Claim Sec. 32. 5/2SW/4 The Virginia No. 2 Placer Mining Claim Sec. 32: Nt2SW/4 R.L. Eaton Agml. No. 1 Fee, 55, 96W The Virginia No. 3 Placer Mining Claim Sec. 33: S/25W/4 The Virginia No. 4 Placer Mining Claim Sec. 33: N/2SW/4 The Virginia No. 5 Placer Mining Claim Sec. 33: S/2NE14 Unocal Trade Fee. 55, 96W Consolidated No. 12 Placer Mining Claim Sec. 34; S/25E/4 Consolidated No. 13 Placer Mining Claim Sec, 34: N/25E/4 Unocal Trade Fee, 5S, 96W Bituminiie No. 15 Placer Mining Claim Sec. 35: NE/4SE/4 Part of Biturninits Na. 16 Placer Mining Claim Sec. 35: NW/45E14 C.H. Dragen Fee, 55, 96W J.B. No. 4 Placer Claim Sec. 35; S/2SE/4 Riec._ t.c 752463 011"''210S L1-.25 35 PM lean n1Gersec 47 _ .rc i -ca 1226 •" Dec Fee.O CsC, ,:^n.:r_iL .aa«r CO «S„ L111111Ard CHEVRON SAD v I✓, 5E.. 158351 691500 EXHIBIT "A" Chevron U.S.A. fnc. Petroleum Development Corporation 585 62-4066 11/15/2002 65 6S 65 6S 6S 6S 65 9TW 97W 97W 97W 97W 97W 97W 1 2 11 12 13 21 22 Eaton Basic Agrnt No. 7 Fee, 6S, 100.00% 81.25% 9TW Gem No. 2 Placer Claim Sec. 1: SW/4 Gem Na. 8 Placer Claim Sec. 1: Lots 11 (40:00), 12 (40.00). 13 (40.00), 14 (40.00) Gem No. 9 Placer Claim Sec. 1: Lots 23 (40.00) and 24 (40.00) Eaton Basic Agmt. No. 7 Fee, 6S, 97W Gem No. 4 Placer Claim Sec. 2: SW/4 Gem No. 6 Placer Claim Sec. 2: Lots 11 (40,00). 12 (40.00), 13 (40.00), 14 (40.00) Gem No. 10 Placer Claim Sec_ 2: Lots 23 (40.00) and 24 (40.00) Eaton Basic Agmt. No. 8 Fee, 6S, 97W Pratt No. 12 Placer Mining Claim Sec. 11: NEJ4 Eaton Basic Agrnl No. 8 Foe, 6S, 97W Pratt No. 8 Claim Sec, 11: SW/4 Eaton Basic Agmt No. 9 Fee, 6S. 97W Community #2 Sec. 12: W/2NE/4 Eaton Basic Agmt.. No. 7 Fee, 6S, 97W Community No. 1 Placer Claim Sec. 12: EJ2NEJ4 Eaton Basic Agmt_ No. 108,11 Fee, 6S, °7W Midland i78 Sec, 13: SW/4 C.H. Darrow Fee, 65, 97W Eureka Placer Mining Claim No. 21-3 Soc. 21: SW/4 Oklahoma Placer Mining Claim No. 6 Sec- 21: NE/4 C.H. Carrow Fee, 6S, 97W eureka Placer Mining Claim No. 22-3 Sec. 22: SW/4 k lil Eict *UW 1 ''1 4 Wt6l f[te'st W4.i 61l 11111 P•c;.ation#: 762463 ! •,2,1P9 Cw ?6:35 PM .lean Aiberie 4 r 45 4ec c., S226.00 DOC Fee 0 v __C _ T, •��' “+Q» JIS1HX3 EXHIBIT "A" i' 65 6S 97W 97W 28 33 C.H. Darrow Fee. 6S, 97W Naomi Placer Mining Claim No. 3 Sec. 28- NE/4 D.D. Potter #7 Fee, 6S. 97W Denver No. 112 Placer Mining Claim Sec. 28' SW/4 D.D. Potter #11 Fee, 65, 97W Sec. 33: Lots 1 (54.94) and 2 (54.92) 111`I � ,t' `�i� �ai�Et tvillfhlrif04tiffiNfiil.itii SI 111 Re ce p L a ank! . 762463 01130!' op -4 )R 35 Pn dean Alter Loa GP 44 cr d„ f••27r CC 'Doe Fee p - �FfI„ 1,1£I1HX'7 r I Chevron 't(SO 1111110 January 26, 2007 Garden Gulch, LLC c/o Petroleum Development Corporation 3801 Carson Avenue Evans, Colorado 80620 Attn: Mr. Dewey Gerdom Re: Garden Gulch Road. Extension Dear Dewey: Mid -Continent Business Unit Chevron U.S.A. Inc. 11111 5. Wiicrest, Houston, TX 77099 P.O. Box 36366, (Houston, TX 77236 QLS # 699369 This letter agreement (this "Agreement") sets forth the agreement among Chevron Shale Oil Company, a division of Chevron U.S.A. Inc., successor by name change to ChevronTexaco Shale Oil. Company (``CSOC"), Garden Gulch, LLC ("Operator"), Petroleum Development Corporation ("PDC"), Berry Petroleum Company (`Berry"), Marathon Oil Company ("Marathon"), PGR Partners, LLC ("PGR"), Teton Piceance, LLC ("Teton") and Williams Production RMT Company ("Williams"). All of the foregoing named parties, less CSOC, are referred to herein individually as a "Party" and collectively as the "Parties." The Parties have agreed to build an extension of the Garden Gulch Road (the "Road") as described hereinafter (the "Road Extension") and CSOC has agreed to such Road Extension, subject to the terms and conditions contained herein. The Parties and CSOC have agreed as follows: 1. The Parties agree to build the Road Extension as depicted on the attached Exhibits "A-1" through "A-10" (the "Road Extension"). The Parties hereby amend that certain Construction and Maintenance Agreement dated November 1, 2005, covering the Road to include the Road Extension as a part of the Road for purposes of such Agreement. 2. CSOC shall contribute its surface fee for right-of-way (as depicted on the attached Exhibits "A-1" through "A-10") for the Road Extension and the Parties shall be responsible for all costs and risks associated with constructing and maintaining the Road Extension, 3. The Parties hereby appoint the Operator as their lead representative who will be in charge of constructing the Road Extension. However, as between the Parties and CSOC, the Parties agree to be ultimately responsible for the construction and maintenance of the Road Extension. 4. The Operator shall proceed with the construction of the Road Extension in accordance with the following: a. In the construction., maintenance and remediation of the Road Extension. Operator will comply with all applicable federal, state, tribal and local laws and with all rules, regulations and orders of all regulatory authorities having jurisdiction. Operator may not enter onto CSOC's surface fee until it has obtained same. If Operator fails to comply with all laws, rules, regulations and orders or fails to obtain the necessary governmental approvals before entering the CSOC's surface fee, then CSOC may terminate this agreernent by giving written notice of said termination to Operator. b. The entire width of the Road Extension, which includes any adjoining safety berms, retaining wall, structures, culverts, other, etc., shall not exceed one hundred (100) feet at any point. The route and center line of the Road Extension must adhere to the same as shown on the surveys attached hereto as Exhibits "A-1" through "A-10". c. Operator shall maintain the Road Extension in good repair at all times and shall be responsible, at its sole cost and expense, for maintenance of the Road Extension, and shall perform same in a good and workmanlike manner in order for the Parties to retain their licenses to use the Road Extension. Operator shall maintain safety on the Road Extension during construction and thereafter. Operator shall not be able to transfer its duty to maintain the Road Extension, without CSOC's prior written consent, which consent may be withheld by CSOC for any reason or no reason. d. Operator, and any party who uses the Road Extension, shall maintain insurance in the amounts and types as indicated on Exhibit "B" hereto. 5. The Road Extension shall be owned by CSOC as to all portions thereof which are on or cross over CSOC owned surface. A depiction of the surface ownership underneath the Road Extension is shown on Exhibit "C" attached hereto. Said Exhibit "C" does not establish surface ownership, actual ownership is controlling 6. CSOC hereby grants an individual, non-exclusive, cost-free right and license to each Party to use CSOC surface that is part of the completed Road Extension for the purpose of accessing and developing the minerals they own or lease in the area. This license shall last for as long as said Party owns minerals in the area and as long as it pays a proportionate share of the continuing annual maintenance costs for the Road Extension. No Party may assign any portion of its license to use the Road Extension without the prior written consent of CSOC, which consent may be withheld for any reason or no reason. No third party shall be allowed to use the Road Extension without paying a fee to be determined by Operator and CSOC (if Operator and CSOC are unable to agree as to a fee, CSOC shall set the fee). All fees received from third parties, excluding maintenance, shall be divided evenly between Operator and CSOC. 7. CSOC shall not be obligated to pay any maintenance costs for the Road Extension unless and until such time as it begins to use the Road Extension to actually mine its minerals or drill its own oil and/or gas wells. At that time CSOC shall enter into an agreement regarding maintenance costs for the Road Extension with the Parties which will require CSOC to pay its proportionate share of the maintenance costs for the Road Extension based on its percentage use of the Road Extension versus the other users thereof. 8. One or more of the Parties may desire to construct a road on acreage adjacent to CSOC surface. As a precondition to the right of such Party or Parties to connect any such road (a "Connected Road") to the Road Extension, such Party or Parties shall: a. to the extent a Connected Road is located on surface lands owned by one or more of the Parties, grant to CSOC a perpetual, irrevocable, nonexclusive, cost-free easement, right-of-way, license or other right, in recordable form, to use the Connected Road, together with a corridor defined as the area within SO feet of either side of the center line of the Connected Road, for all lawful purposes including, without limitation, ingress and egress to and from other CSOC surface lands for all purposes including oil shale exploration and development, and including, without limitation, maintenance, upgrading and widening of the Connected Road within such corridor (collectively, "CSOC Uses"); and/or b, to the extent a Connected Road is located on surface lands owned by third parties other than a Party hereto and over which one or more Parties hereto have acquired an easement, right-of-way, license or other right (a "Third -Party Use Right"), and subject to any consent right held by the third party surface owner, the Party or Parties holding such Third Party Use Right shall (i) sublicense or sublet to CSOC on a nonexclusive basis and for the duration of the Third Party Use Right such portion of such Third Party Use Right as is necessary to accommodate and permit the CSOC Uses to the extent allowed under the terms of the Third Party Use Right, and (ii) use its reasonable best efforts to obtain any required third -party consent. Notwithstanding any other provision in this Agreement or any other Agreement between the Parties hereto, the duties imposed upon the Parties by this paragraph, and the rights enjoyed by CSOC under this paragraph, shall be binding upon the successors, heirs, and assigns of the Parties. The Parties shall inform any successor, heir, and/or assign of the obligations imposed under this paragraph, and shall take all reasonable and necessary actions to ensure that such successor, heir, andior assign accepts and assumes the duties imposed under this paragraph. 9. A segment of the Road Extension that is on CSOC surface, approximately between Stations 97+00 and 112+00, will be in a draw immediately west of another draw containing an existing two -track road heading north out of Little Creek drainage in the N/2S/2 Section 29, T5S, R96W, 6th P.M. The existing two -track on CSOC surface shall be abandoned and upon completion of the portion of the Road Extension contemplated by this provision. Operator shall place and maintain obstacles across the abandoned two -track so that it can no longer be used.. 10. A segment of the Road Extension on CSOC surface in the SW/4 Section 1, T6S, R97W, 6`i P.M., approximately between Stations 374+00 and 395+00, will replace an existing two -track road. Upon completion of the portion of the Road Extension contemplated by this provision. the segment of existing two -track on CSOC surface that is being replaced shall be abandoned and Operator shall place and maintain obstacles across the abandoned two -track so it can no longer be used. 11. Operator shall avoid damaging, to the extent feasible, the existing aspen grove at the point where the Road Extension intersects the access road to the Chevron 13-213 well pad in the NW/4 Section 13, T6S, R97W 6th P.M. (approximately Station 544+00). 12. Operator shall comply with all federal, state and local laws and regulations governing the discharge of construction and other materials into drainages. Operator shall be responsible for the adequacy of the road design, including, but not limited to, culvert designs.. 13. Operator shall control fugitive dust during construction of the Road Extension, 14. Operator shall be responsible for the cost, installation and maintenance of signage at intersections of roads to aid in navigation for emergency and law enforcement personnel. Operator shall be responsible for the cost to install and maintain speed limit signs and other caution signs as specified by CSOC Health, Environment & Safety personnel. 15. Operator shall ensure all road cut and fill areas and other disturbed areas on CSOC surface are re-contoured to generally conform with the surrounding terrain. Ita. All disturbed areas on CSOC surface shall be reseeded by Operator using seed mix approved by CSOC's surface lessees until a self-sustaining stand of vegetation is achieved. 17. All disturbed areas on CSOC surface shall be sprayed for weeds by Operator for a period of three (3) years following construction. IR. Road Construction activities on CSOC surface shall he coordinated by Operator with CSOC's surface lessees to minimize conflicts for all parties. Please indicate your agreement to the terms set forth above by executing this Agreement in the space provided below and returning a fully executed copy to my attention at the above address. This Agreement, as set forth herein, shall he effective as of' the date all. Parties properly execute the same and a Bally executed original is provided to CSOC. This Agreement may he executed or ratified in one or more counterparts and all of the executed or ratified counterparts shall together constitute on instrument. Sincerely, Cl IEVRON SHALE OIL COMPANY. a division of Chevron U.S.A. Inc. *` r By: � . 4) Name: e • ire" ;3 Title: A# PII— ete7 AGREED TO AND ACCEPTED this day of , 2007. GARDEN GULCH, LLC, by Petroleum Development Corporation, Manager By: Name: Deward W. Gerdont Title: Vice President Exploration AGREED TO AND ACCEPTED this day of , 2007. PETROLEUM DEVELOPMENT CORPORATION 13y: Name: Deward W. Gerdo m Title: Vice President, Exploration 18. }Rad Construction activities on CSOC surface shall be coordinated by Operator with CSOC's surface lessees to minimize conflicts for all parties. Please indicate your agreement to the terms set forth above by executing this Agreement in the space provided below and returning a fully executed copy to my attention at the above address: This Agreement, as set forth herein, shall be effective as of the date all Parties properly execute the same and a fully executed original is provided to CSOC. This Agreement may be executed or ratified in one or marc counterparts and all of the executed or ratified counterparts shall together constitute on instrument. Sincerely, CHEVRON SHALE 011 COMPANY, a division of Chevron U.S.A. inc. By; Name: Title: AGREED TO AND ACCEPTED this / . s day of 1 J, ' , 2007. GARDEN G. C , by Petroleum P - -..7 (. t Corporation, Manager By; 1 1ai� Name: Deward -rdom Title: Vice Presi "I°, Exploration AGREE this ) av of PETROL "U )3odicPh By: '4, AIM Name: Deward Title: Vice Pres AND EP TED , 2007, NT CORPORATION AGREED TO AND ACCEPTED this '4 day k _ �, 2007. BERRY PP' ^ 0 z M CO PAT By: Na' Title: V ( AGREED TO AND ACCEPTED this day of , 2007. MARATHON OIL COMPANY By: Name: Title: AGREED TO AND ACCEPTED this day of , 2007. PGR PARTNERS, LLC By: Naive: AGREED TO AND ACCEPTED this day of , 2007. TETON PICEANCE. LLC By: Name: Title: AGREED TO AND ACCEPTED this day of , 2007. BERRY PETROLEUM COMPANY By: Name: Tide: AGREED TO AND ACCEPTED this IJai,_ day of .r , . 2007. MARATHON OIL COMP By: Name: Jon D. Wilcox Title: rs-fad AGREED TO AND ACCEPTED this day of , 2007. PGR PARTNERS, LLC By: Name: Title: AGREED TO AND ACCEPTED) this day of , 2007. TETON PICEANCE, LLC By: Name: Title: AGREED TO AND ACCEPTED this day of , 2007. BERRY PETROLEUM COMPANY By: Name: Ttic: AGREED TO AND ACCEPTED this day of , 2007. MARATHON OIL COMPANY By: Name: Title: AGREED TO AN 'CEPTED this_ SO day of , 2007. PGR. PAR E LLC( By: Name: TO/ -40 (. Title: 414A AGREED TO AND ACCEPTED this day of , 2007. TETON PICEANCE, LLC By: Name: Title: AGREED TO AND ACCEPTED this day or , 2007. BERRY PETROLEUM COMPANY By: Naine: 'Ville: AGREED TO AND ACCEPTED this day of , 2007. MARATHON OIL COMPANY By: Name: AGREED TO AND ACCEPTED this day of , 2007. PGR PARTNERS, LLC By: Name: Title: AGREED TO AND ACCEPTED this .14iday of 17344,14424.1 , 2007. TETON PICEANCF. LLC Name: Title: AGREED TO AND ACCEPTED this ; , day of , 2007. WILLIAMS PRODIJCFION RMT COMPANY By.- Name: Qc.rta,,r s Title: O. A€emit 112r crr+..cc:. -{I riLr►,t o.S Exhibit "A-1" CP 44 ,qt CKRAB RIDGE R D 1- OMI S ROI6<d AN ASH 0AD CCPV P R TJS R96 CHEVRON 0— 14i Amakkalit r wry BERRY I Amon T5S R96 H,_ 1 (ATI1M 1 L_ B1J •W 1/ I L 16S IR96W _ LA IATHAM �F - TRAIL RD: GE ROAD f IIIL�j PRATUER BERR rtrm Ern CRAP,-IIC 5CALf IN I'ik' CENTERLINE METES AND BOUNDS OF FROPOSED BERRY PETROLEUM COMPANY 24' WIDE GARDEN GULCH EXTENSION SITUATE IN SECTIONS 29, 30, 32 AND 33 TOWNSHIP 5 SOUTH, RANEF 96 WEST AND SECTIONS 1, 11, 12, AND 13, TOWNSHIP 6 SOUTH, RANGE 97 WEST, SIXTH PRINCIPAL MERIDIAN, GARFIELD COUNTY, COLORADO G NIBT LIG1 00N1 6 QV 'rb RdC. apcM2 0411,411Cat SLAP 1:%1.*, CAP 0:1152 ACNifIHOeR tliNhJ PRA fiec et ph 717. .c eC••rt.CAwCn • LCP. CIT .cr. Exhibit "A-2" 0111111ffiffil !ITIPHIMIUN 11. 21 1 Exhibit "A-3" II Igill! WFI!IU f-pF� 1• r. l�l4lll R R a 1 Y s R FI EMI" tal Mafia M WWI MFAIMMr-VM FAM apis i'Ta �s NFMN■WMNI t11/MIAMIMFMN 555I 1 PMT 5 LIAR ffnia : e MATCH UNE Exhibit "A-4" .1111 I . '1111111111111111111i1111, t '141t./ !III; I ; Exhibit "A5" 1111,111!IIII!!1[1 11 814 Id 1=1 M rn .11 4 rn r -- a ' cc tn g -3 0 tal thr) 0 4 tz, 1 U -A741,1 1.1:4 *.1 7 ; A le+mi 40. MATCH LiNZ TI.214-4O Exhibit "A-6" MORN 4 - g PitT 11' 54 A '04 S.? /11',3. • -1,.„Q, INT111 LT136 Trr 1:MS "PP1V-t.,11 • t irra. 33331.3 olg' 1 k1/4, 0; • 111/43 rm.. re n 000r. wor ,ea .0.91,"Agv a 1/41/4,P 4L 11 .7" -'''4‘ '' 1!,4it i { 'T.g 1131 ' 1 ayn 4,3c3 .=3. 4 MATCH LINE .7- Exhibit "A-7" e gEVe,n"iaaYr42'Ayyer'•. R"I''''-'14-9. -��'�F1-. ' ..,[arse i,' 66G8iel 6s-Lll 'alii WI sPeaset' 0,' ntri o 'G e 41, C▪ O � y i t J o y+ A 1 A AICA uht n.11 ...Nei •e"4-00 re -0023 .h1. M4.. 1)14TCH hill 'SfA- 916Fe6 ego .tea 0-0 F ge, A \l -43 1 N Exhibit "A-8" mmummo: mpit per 1.11. 41111P1111111!1] 11,1111P01,11S1 Wl- r,4P_.] .1111111121MTIR a H P-1 ria (i) 0 5 A g .7E'f ,. s 11•1,1 41 , , e.t --,-.- , k 1 m. rev, I h 71 i pl A .2 • .:.A. PJ \ WAN' Si tc, •':" :,- H : ) rs 7z; a 0 at" , Z NAVA LIM Trtig,sag j 1V 13 ,VillaH a Exhibit "A-9" - A 2 r• 2E1' 4ig • 41i:4411U-0D , ew w•W -AF,..1., rrA IT 0. -,1 WI' I.Wr• • 7 - i • ;1- ; M.-60.6119.11.-aw..,„ANM.no,./INO.w/WIr ..k• Yin "o — 4 " =.1 wren, weir .7*1 A • ." W A A' AVS/H31H3ON/H3HIVHd g 9 r 0 u , r - - Fer g S5. 1 1 4 Exhibit "A-10" A §414111 wr-sTraa 111'75.7- • *1 011,. 1 0 it r l• •,••••• ;# # i A 4 4 ...{ . . . . '; . 10, 1 -' • '4" ' .I;Iii . ..... o. z 'I\ s=11 L4 Exhibit B GRANTEE INSURANCE REQUIREMENT. Without in any way limiting GRANTEE'S liability under this Agreement, GRANTEE shall maintain, during the term of this Agreement, the following insurance with companies and on terms satisfactory to GRANTOR: A. Worker's Compensation and Employers' Liability Insurance as prescribed by applicable law. The limit of liability for Employers' Liability Insurance shall not be less than $1.000.000 per occurrence. B. Comprehensive or Commercial General Liability Insurance (Bodily Injury and Property Damage), including the following supplementary coverages: Contractual Liability to cover liability assumed by GRANTEE under this Agreement; Product and Completed Operations Liability Insurance; Broad Form Property Damage Liability Insurance; and coverage for Explosion, Collapse and Underground Hazards. The limit of liability for such insurance shall not be less than $1,000,000 per occurrence. C. Automobile Bodily Injury and Property Damage Liability Insurance. Such insurance shall extend to owned, non -owned and hired automobiles used in the performance of this Agreement. The limits of liability of such insurance shall not be less than $1,000,000 per person/ $1,000,000 per occurrence for bodily injury and $1,000,000 per occurrence for property damage. The insurance specified in this Section Seven shall contain a waiver of subrogation against GRANTOR, and shall name GRANTOR as an additional insured with respect to the activities performed pursuant to this Agreement. In addition., said insurance shall include a requirement that the insurer provide GRANTOR with 30 -days' written notice prior to the effective date of any cancellation or material change of the insurance. PRIOR. TO HAVING ANY RIGHT TO ACCESS THE LANDS SUBJECT HERETO OR EXERCISING ANY OF THE RIGHTS GRANTED IN THIS AGREEMENT, GRANTEE MUST FURNISH GRANTOR WITH COPIES OF THE INSURANCE POLICIES OR CERTIFICATES OF SAID INSURANCE PROVIDING THE COVERAGES AND ENDORSEMENTS REQUIRED HEREIN. All insurance policies or certificates of insurance provided to GRANTOR shall be in a form acceptable to GRANTOR, shall reference this Agreement's QLS number as found at the top of page one of this Agreement and shall be provided to GRANTOR prior to GRANTEE exercising any of the rights granted herein. Exhibit "C" Argt 41goimmi ' TOB ROTWI T6S E X February 12, 2014 Marathon Oil Company Piceance Operations Wyoming Asset Team Grand Junction, Colorado Garfield County Community Development 108 8th Street, Suite 401 Glenwood Springs. CO 81601 RE: Marathon Oil Limited Impact Review Application (#LIPA 7775) To Whom It May Concern: Caerus GO and Gas, LLC 600 Seventeenth Street Suite 1600N Denver. CO 80202 This letter shall serve as notice to Garfield County Community Development and Planning group that to our knowledge as operator of the Garden Gulch Road and Extension Road (the "Roads") that Marathon Oil is a current licensee, entitled to use permitted by, and subject to, all applicable Road agreements. Marathon Oil has paid in full the outstanding Joint Interest Billings on the road issued by Caerus as of February 12"', 2014; however, nothing herein shall in any way limit Caerus' or Prior Operators rights to collect any amounts that may now be, or may in the future become, due Thank you, K. JeterfT mas Chief Fjn cial Officer Caerus it and Gas LLC Emergency Response Plan* Marathon Oil Company 32C Produced Water Pond OA Project No. 012-1372 *Complete Emergency Response Plan is provided in electronic version only Marathon Oil PICEANCE OPERATIONS EMERGENCY RESPONSE PLAN P ce nce Base, Co 743 HORIZON COURT - SUITE 220 GRAND JUNCTION, CO 81506 970-245-5233 Main Number 866-MOC-CERT (866-662-2378) Tho Resuonse Group Emergency Hespanse ■Pre -Planning & Support Marathon Oil' if Piceance Operations Emergency Response Plan Foreword TABLE OF CONTENTS March 2013 O The Response Group Page 1 PLAN ORGANIZATION SECTION Foreword: Table of Contents, Distribution List, Record of Revisions FWD General: Purpose and Scope, Regulatory Compliance, Plan Review, Operations Information / Description, Diagrams / Maps, Person -in -Charge Information 1 Emergency Response Information: Initial Discovery / Response Actions, Notifications, Response Personnel, Emergency Response Contractors, Immediate Response Actions, Emergency Response Equipment, Demobilization, Incident Documentation 2 Z Q U) -I Z ZL- _ I-. (I} QZ EO Pollution Prevention Measures: Hazard Evaluation, Vulnerability Analysis, Spill Containment & Recovery, Analysis for the Potential of an Oil Spill, Spill History, Product Characteristics/Hazards, MSDSs 3 Plan Implementation: Plan Implementation, Contractor Equipment and Manpower, Response Documentation, Site Safety and Health Plan, Decontamination Plan, Waste Management Plan, Disposal Plan, Containment and Drainage Planning, Security Plan, Wildlife Protection and Rehabilitation 4 d- a. co' O w Maintenance and Training Program: Self -Inspection Procedures, Response Equipment Inspection, Testing and Deployment Drills, Secondary Containment Inspection, Drills and Exercises, Response Training 5 (,) » Z V Q Z UJ LU Response Management System: Incident Management Team Description, ICS Structure, Common Responsibilities, Roles & Responsibilities Checklists, Public Affairs Guidance, Res.onse Manasement System 6 0 2 IL a- W , . e- endFCeS Notifications A 2I IJ,J Glossary! Acronyms B Forms C Diagrams D Waterline Maps E Waste Management and Disposal Plan F Well Control Emergency Management Plan G Inland Spill Response Tactics Guide H March 2013 O The Response Group Page 1 Marathon Oil' Piceance Operations - IA Emergency Response Plan Section 1:. General Section 1: General 1.1 Purpose and Scope 1 1.2 Regulatory Compliance 2 1.3 Plan Review 2 1.4 Operations Information / Description 3 1.5 Diagrams 3 1.6 Person -in -Charge Responsibilities 3 1.7 Person -in -Charge Contact Information 4 March 2013 © The Response Group Marathon Oil' Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions 1 21.1 SpiU Response Notification 1 Figure 2.1 —PiceonnoOperatimnu Spill Response Flowchart 2 Figure 2.2 — NAPO Environmental Incident Report 3 Figure 2.3 — 011 SpiIl and Hazardous Substance Release Report Form 4 Figure 2.4—CDPHE5Day Spill Reporting Form 8 2.2 Response Actions .1O 2.2.1 Corporate Emergency ResponseTeam (CERT) 10 2.2.2 CERT Notifications/Activations 11 2.2.3 CERT Team Leader Notifications 12 Figure 2.5 Major Emergency Reporting Flowchart 12 2.2.4 Response Considerations 13 2.2.5 Initial Containment Actions 14 2.2.6 Condensate/Produced Water Spill 15 Figure 2.6 — Spill Estimation Factors 21 2.2.7 Fire / Explosion ' 23 2.2.8 Toxio/F|mmmsb|eGmn Release 26 Figure 2.7 — Gas Release Emergency Flowchart 27 2.2.9 Gas Pipeline Response Guide 28 2.3.10 Air Monitoring .45 Figure 2.8—Air Monitoring Decision Flowchart 45 2.2.11 Well Control/Drilling/Completions Ernergency Measures 50 Figure 2.9 — Well Coritrol/Drilling/Completions Emergency Flowchart 52 2.2.12 Severe Weather 55 Figure 2.10 — Tornado/Earthquake/Flood Emergency Flowchart 57 2.2.13 Medical Emergency 60 Figure 2.11 -. Medical Emergerrcy Flowchart . 63 2.2.14 Failure ofTransfer Equipment 66 2.2.15 Tank Overfill / Failure 66 2.2.16 Piping Ruptre/Leak (under pressure and no pressure) 66 2.2.17 Manifold Failure 66 2.2.18 Bomb Threat 67 Figure 2.12— Bomb Threat Flowchart 67 March 2013 0 The Response Group WWII Marathon 011 Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.3 Emergency Response Equipment 71 2.3.1 Facility Owned Response Equipment 71 2.3.2 Contractor Owned Response Equipment 75 2.3.3 Letters of Intent 76 Ecos Letter of Intent 76 CES Letter of Intent 77 Clean Harbors Letter of Intent 78 Veolia Letter of Intent 79 2.3.4 Response Contractor Equipment Lists 85 Ecos 85 CES 86 Clean Harbors 104 Veolia 109 2.4 Demobilization 130 2.4.1 Equipment Demobilization 130 2.5 Incident Documentation Procedures and Response Critique 135 2.5.1 Post Incident Review 135 March 2013 0 The Response Group Marathon Oil` Piceance Operations Emergency Response Plan Section 3: Pollution Prevention Measures Section 3: Pollution Prevention Measures 3.1 Hazard Evaluation 1 3.1.1 Hazard Identification 1 3.1.2 Tank Table 2 Table 3.1 — Container and Potential Spills Table: Piceance Operations 3 3.1.3 Hazard Identification Surface Impoundments (SI) 3 3.2 Vulnerability Analysis 16 3.2.1 Threatened, Endangered and Special Concern Species in Colorado 17 3.3 Environmental Sensitivity Information 25 Figure 3.1 Sensitive Area Protection Implementation Sequence 26 3.4 Spill Containment and Recovery 27 Figure 3.2 Response Techniques for Produced Water or Condensate 28 Figure 3.3 Response Tactics for Various Shorelines 29 Figure 3.4 Summary of Shoreline and Terrestrial Clean Techniques 31 Figure 3.5 Water Flushing Guidelines 34 3.5 Analysis of the Potential for a Condensate or Produced Water Spill 35 3.6 Product Characteristics and Hazards 36 Figure 3.6 Summary of Commodity Characteristics 37 Figure 3.7 Material Safety Data Sheets 38 March 2013 © The Response Group /Mx Marathon OffJai Piceance Operations Emergency Response Plan Section 4: Plan Implementation Section 4: Plan Implementation 4.1 Plan Implementation 1 4.1.1 Response Resources 1 4.2 Contractor Equipment and Manpower 2 4.3 Response Documentation 3 4.4 Site Safety and Health Plan 4 4.4.1 General Safety Briefing 4 4.4.2 Emergency Action Conditions 4 4.4.3 Heat Stress ..5 4.4.4 Heat Stress and Related Health Effects 5 4.4.5 Work Rest Cycles (ACGIH) 7 4.4.6 Worker Monitoring Programs 7 4.4.7 Heat Stress Management Program 9 4.4.8 Cold Stress and Hypothermia Information 10 4.4.9 Hypothermia 11 4.4.10 Handling Cold Stress and Hypothermia Victims .11 4.4.11 Water Immersion Victims 12 4.4.12 Hypothermia Summary 13 4.4.13 Other Cold Stress Injuries 13 4.4.14 Evaluating Cold Exposure Hazards 15 4.4.15 Preventing Cold Stress 16 4.4.16 Protective Clothing / Equipment 17 4.4.17 Selection of Materials 20 4.4.18 Marathon Oil Company Recommended Sanitation Requirements 20 4.4.19 Emergency Response Traffic Safety Guidelines 22 4.5 Decontamination Plan 23 4.5,1 General Considerations 23 Figure 4.1 — Decontamination Methods Diagram 26 4.5.2 Personal Protective Equipment 27 4.5.3 Minimum Acceptable Personal Protective Equipment for Each Level of Protection 28 4.5.4 Heavy Equipment Decontamination 29 4.5.5 Personnel Decontamination 30 4.5.6 Warning and Alarms 32 4.5.7 Debriefing 32 March 2013 © The Response Group Piceance Operations Emergency Response Plan Section 4: Plan Implementation Figure 4.2 — Decontamination Plan 33 Figure 4.3— Level A 34 Figure 4.4 — Level B 35 Figure 4.5 — Level C 36 Figure4.6—LevelD 37 Figure 4.7 — Decontamination Plan 38 4.6 Waste Management Plan 42 4.6.1 Introduction 42 4.6.2 General Considerations .42 4.6.3 Waste Management 42 4.6.4 Containment Management 44 4.6.5 Environmental Monitoring 45 4.6.6 Final Demobilization 45 Figure 4.8 — General Waste Containment and Disposal Checklist 46 Figure 4.9 — Temporary Storage Methods 47 Figure 4.10 — Waste Management Plan 48 4.6.7 Sailing Sampling and Analysis Plan Guidance _ 50 Figure 4.11 — Soil Sampling and Analysis Plan 53 4.6.8 Water and Product Sampling and Analysis Plan Guidance 55 Figure 4.12 — Water and Product Sampling and Analysis Plan 59 Figure 4.13 — Water Location 1 Sampling Plan 61 4.6.9 Recovered Oil and Water Management Plan 63 4.7 Disposal Plan 76 4.8 Containment and Drainage Planning 77 4.8.1 Facility Berm/Dike 77 4.8.2 Redundant Secondary Containment 78 4.8.3 Areas without Secondary Containment 79 4.8.4 Drainage from Berm/Diked Areas 79 4.8.5 Drainage from Unbermed/Undiked Areas 79 4.9 Incident Security Plan 80 4.10 Wildlife Protection and Rehabilitation 82 4,10.1 Introduction 82 4.10.2 Establishment of Rehabilitation Center 82 4.10.3 Wildlife Assessment 82 4.10.4 Wildlife Management 83 4.10.5 Facility Requirements 83 March 2013 © The Response Group (i`t.11 Marathon Oil Piceance Operations Section 4: Emergency Response Plan Plan Implementation 4.10.6 Protection Techniques 92 4.10.7 Data Interpretation 92 4.11 Safe Work Practices for Oiled Bird Rehabilitation 94 4.11.1 References 94 4.11.2 Hazards to be addressed 94 4.11.3 Safe Work Practices 96 4.11.4 Design and Construction of REHAB Centers 98 4.11.5 Remember 99 March 2013 0 The Response Group rkei Marathon Oil' Piceance Operations Emergency Response Pian Section 5: Maintenance & Training Section 5: Maintenance and Training Program 5.1 Facility Self -Inspection 1 5.2 Inspection Procedures 2 5.2.1 Sample Inspection Checklists 2 5.2.2 Inspection Guidance 3 Figure 5.1 — Sample Facility Quarterly Inspection Record 4 Figure 5.2 — Sample Annual Pipe and Flowline Inspection Record 5 5.2.3 Written Instructions for Contractors 6 5.3 Inspection Forms 7 5.3.1 External Inspection Form — Mobile Containers Supporting Non -E&P 7 5.3.2 External Inspection Form — Tanks and Containers 8 5.3.3 External Inspection Forms — Secondary Containment 9 5.3.4 Internal Tank Inspection Form 10 5.3.5 External Inspection Forms — Processing and Facility Equipment 12 5.3.6 32C Centralized E&P Waste Facility— Monthly Inspection Sheet 13 5.4 Response Equipment Inspection 14 5.4.1 Sample Response Equipment Inspection Log 14 5.5 Response Equipment Testing & Deployment Drills 15 Figure 5.3 — Sample Response Equipment Testing and Deployment Drill Log 15 5.6 Secondary Containment Inspection 16 Figure 5.4 — Sample Secondary Containment Drainage Log 17 5.7 Drills and Exercises 18 5.7.1 Sample Qualified Individual Notification Drill Logs 20 5.7.2 Sample Incident Management Team Tabletop Exercise Logs 21 5.7.3 Sample Spill / Exercise Documentation Form 22 5.8 Response Training 26 5.8.1 Classroom Training 26 5.8.2 HAZWOPER Response Qualifications . 27 5.8.3 Sample Personnel Response Training Logs 27 5.8.4 Sample Discharge Prevention Training Logs 28 5.8.5 HAZWOPER Levels.,,,, 29 March 2013 U The Response Group Marathon Oil Piceance Operations Emergency Response Pian Section 6: Response Management System Section 6: Response Management System 6.1 Incident Management Team (IMT) Description 1 6.1.1 Purpose 1 6.1.2 Activation Procedures 1 6.1.3 Phases of Response Management 2 6.1.4 Levels of Response 2 Figure 6.1 - Emergency Response Team (ERT) Organization Charts 3 Figure 6.2 - Tier II — North American Production Organization Regional Response Team NAPRRT 4 Figure 6.3 - Tier III — EST Emergency Strike Team CERT 5 6.1.5 Team Member Response Times 6 6.1.6 Additional Company Resources 6 Figure 6.4 — IMT Activation Procedure 7 6.2 Incident Command System Structure 8 6.3 Common Responsibilities 12 6.4 Roles and Responsibilities Checklists 14 6.5 Public Affairs Guidance 39 6.5.1 Guidelines for Dealing with the Media 39 Figure 6.5 — Incident Fact Sheet .41 March 2013 The Response Group Piceance Operations Emergency Response Plan Appendix A: Notifications Appendix A: Notifications A.1 Notification 1 A.1.1 Emergency Notification Phone List 1 A2 External Notifications 3 A.2.1 Federal and. State Notifications 3 National Response Center 3 Environmental Protection Agency 4 Bureau of Land Management 5 U.S. Fish and Wildlife Service 6 Occupational Safety & Health Administration 6 U.S. Army Corp of Engineers 7 Colorado Oil and Gas Conservation Commission 8 Colorado Department of Public Health and Environment 9 A.2.2 Marathon MCAT Piceance Operations Team Office Contacts 14 A.2.3 Radio Frequency Information for Piceance: 14 A.2.4 LEPC 1 OEM 15 A.2.5 Local Notifications — Grand Junction/Piceance, CO 16 A.2.6 Utilities 17 k2.7 Airports 17 A.2.8 Oil and Gas Operator Emergency Phone Numbers 18 A.2.9 Surface Owners 19 A.2.10 Additional Emergency Response Contact Information 20 A.2.11 Hotels and Catering 21 A.3 Response Personnel ., 22 A.3.1 Corporate Emergency Response Team (CERT) 22 A.3.2 CERT Notifications/Activations 23 A.3.3 CERT Team Leader Notifications 24 A.3.4 Emergency Response Contractors 26 A.4 Internet Links for Supplemental ER Information 32 A.4.1 National Links 32 A.4.2 Specialty Contractor Resources 34 A.4.3 OSRO Links 35 A.2.4 State of Colorado Links 35 March 2013 O The Response Grou IMO Marathon Oil Pceance Operations Emergency Response Plan Appendix S: Glossary / Acronyms ti Appendix i3: Glossary of Terms and Acronyms Definition TermMD A Absorbent Material Any of several materials designed to absorb oil, both hydrocarbon and non -hydrocarbon. Access/Staging Areas Designated areas offering access to spill sites for the gathering and deployment of spill response equipment and personnel. Activate The process of mobilizing personnel and/or equipment within the response organization to engage in response operations. Adjoining Shoreline Any area within the mean high water line of any "navigable waters" listed. Adverse Weather The weather conditions that will be considered when identifying response systems and equipment in a response plan for the applicable operation environment. Factors to 1 consider include significant wave height, ice conditions, temperatures, weather-related visibility, and currents within the area in which the systems or equipment are intended to function. AFE Authorization for Expenditure Agency A division of government with a specific function offering a particular kind of assistance. In ICS, agencies are defined either as jurisdictional (having statutory responsibility for incident management) or as assisting or cooperating (providing resources or other assistance). Agency Representative Individual assigned to an incident from an assisting or cooperating agency that has been delegated full authority to make decisions on all matters affecting his/her agency's participation at the incident. Allocated Resources Resources dispatched to an incident. ALS Advanced Life Support Alteration Any work on a tank or related equipment involving cutting, burning, welding, or heating operations that changes the physical dimensions or configuration of a tank. AQI Alternate Qualified Individual Area The geographic area for which a separate and distinct Area Contingency Plan has been prepared as described in the Oil Pollution Act of 1990. For EPA Areas with sub -area plans or annexes to the Area Contingency Plan, the EPA Regional Administrator will decide which sub -area is to be exercised within the triennial cycle. March 2013 O The Response Group Page 1 1 \ 1/ Marathon Oil' Appendix C: Forms Piceance Operations Emergency Response Plan Appendix C: Forms TRG Trajectory Request Form 1 ICS Forms 3 Air Monitoring Plan 66 March 2013 0 The Response Group if VI Marathon Oii PICEANCE EMERGENCY CONTACTS October 2013 Plan...Focus...Adapt...Nobody Gets Hurt! Contacts for Escorts, Hazards, Incidents, etc. (Marathon Roads and Pads) Joe Elder/Moody (970) 314-5034 (UGS to MM 17.5; Jackrabbit Ridge Road; Route 2) Jason Metcalf/Metcalf (Route 2) Contacts for Escorts, Hazards, Incidents, etc. (Garden Gulch Cliff Road and Extension Road) ➢ Garden Gulch Cliff Road/Caerus (Operator)/Terry Tracy at (970) 734-7078 ➢ Garden Gulch Cliff Road/Metcalf Excavation (Contractor) at (970) 216-9349 (24-hour emergency number) ➢ Garden Gulch Cliff Road Core Hours of Operation (7 days/week): o Winter; Nov. 1 — March 31; 4 am — 6 pm o Summer; April 1 — Oct. 31; 6 am — 6 pm ➢ Garden Gulch Extension Road/Berry (Operator)/Tom Hogelin (970) 948-2785 ➢ Garden Gulch Extension Road/Moody (Contractor)/Joe Elder (970) 314-5034 (UGS to MM 17.5) ➢ Garden Gulch Extension Road Core Hours of Operation: Mon. — Fri.; 7 am — 4 pm CB Channels • Channel 28 for GGR/GGRx • Channel 19 for Jackrabbit Ridge • Channel 22 for southwest of Upper Guard Shack (Crawford Trail/LoganWash/Oxy) Primary Contacts for Marathon Access Roads and Pads Name Company Mobile Office E-mail Scott Trucks Prod. Lead (970) 623-5858 (970) 285-5003 sstrucks@marathonoil.com Bob Lopez Prod. Supv. (970) 712-1603 (970) 285-5004 robertlopez@marathonoil.com Dustin Snow Route 1 (970) 589-0409 (970) 285-5006 dsnow@marathonoil.com Erik Fuller Route 2 (970) 366-2073 (970) 285-5117 epfuller@marathonoil.com Gale Bowles Route 3 (970) 640-6121 (970) 285-5119 gbowles@marathoil.com Ben Talancon Safety Tech (970) 778-5114 (970) 285-5118 bmtalancon@marathonoil.com Eric Ward Ops. Supt. (970) 589-5949 (970) 244-5735 erward@marathonoil.com Emergency Contacts Lower Guard Shack (970) 216-9349 Upper Guard Shack Radio communication w/ Lower Guard Shack (subject to change) EMS/GarCo Dispatch 911 or (970) 625-8095 Care Flight / 800-332-4923 Garfield Co. Sheriff Rifle (970) 945-0453 EnCana Guard Shack Parachute (970) 285-9496 Garden Gulch Road (GGR): • Email road communications and scheduling to office@metcalfexcavation.com • Provide 24 hour notice for oversize loads, convoys, rig moves, frac- crews, workover rigs, road closures and first time road users. • Understand and follow Road User Policy (Sept. 2012). Weather: 10 Miles NW Parachute CO 39.54N 108.19W (Elev. 8397 ft) http://forecast.weather.gov/MapClick.php?lat=39.54323497544602&lon=-108.1988525390625&site=gjt&smap=l &marine=0&unit=0&lg=en Weather: 11 Miles WNW Parachute CO 39.49N 108.24W (Elev. 7252 ft) http://forecast.weather.gov/MapClick.php?MapType=3 &site=GJT&CiTemplate=l &map.x=183&map.y=104 Oxy website for road conditions and chain use (CB Ch 25 for towing; DIA): www.lwroad.com Marathon's Winter Map Link (24"x36"; password is roadsl2): http://www.whsmithpc.com/WHS/downloads/SNOW12 PLAN24X36.pdf Steve Schram Qualified Individual Tier I Team Structure Office Phone Cell Phone E -Mail Eric R. Ward Steve Schram Bob Lo.ez Incident Commander [Eric R. Ward Logistics Section Chief Lloyd Schwartz Sue Beardslee Situation Unit Leader Vicki Schoeber` Robin Po Environmental Officer [Scott Distel Safety Officer Ben Talancon Michelle Koch* Planning Section Chief Steve Schram Scott Trucks Operations Section Chief Bob Lopez Scott Trucks Public Relations Cynthia Bates 970-244-5735 970 244 5729 970-244-5736 970-244-5735 970 244 5729 713-296-2811 307-672-4659 970-244-5754 970-244-5734 970-244-5738 405-720-5532 970-244-5724 405-720-5531 970 244 5729 970-285-5003 970-244-5736 970-285-5003 970-244-5756 Notes: Yellow denote alternate contacts * Michelle Koch will be an addtitional alternate Environmental Officer if needed. Vicki Schoeber will be an additional alternate Environmental Officer if needed. 970-589-5949 970 210 8846 970-712-1603 970-589-5949 970 210 8846 832-803-8938 307-461-1003 970-712-0554 970-640-2810 307-399-2329 405-388-6940 970-778-5114 567-525-6160 970 210 8846 970-623-5858 970-712-1603 970-623-5858 970-245-5233 ERWard{cMarathonOil.com smschram@marathonoil.com RobertLopez a.MarathonOil.com ERWard©MarathonOil.com smschram@marathonoil.com LSchwartz©MarathonOil.com SABeardslee@marathonoil.com VLSchoeber©MarathonOil.com RPopp©MarathonOil.com SDistel@marathonoil.com JTBrown©marathonoil.com bmtalancon©marathonoil.com M LKoch@marathonoil.com smschram(a)marathonoil.com sstrucks@marathonoil.com RobertLopez a.MarathonOil.com sstrucks@.marathonoil.com CLBates@MarathonOil.com updated 10/8/13 iTu Marathon OilO PICEANCE OPERATIONS EMERGENCY RESPONSE PLAN Piceance Basin, CO 743 HORIZON COURT - SUITE 220 GRAND JUNCTION, CO 81506 970-245-5233 Main Number 866-MOC-CERT (866-662-2378) The Response Group Emergency Response Pre -Planning & Support Marathon Oil` Piceance Operations Emergency Response Plan Foreword TABLE OF CONTENTS March 2013 © The Response Group I PLAN ORGANIZATION ECTIO Foreword: Table of Contents, Distribution List, Record of Revisions FWD General: Purpose and Scope, Regulatory Compliance, Plan Review, Operations Information / Description, Diagrams / Maps, Person -in -Charge Information 1 Emergency Response Information: Initial Discovery / Response Actions, Notifications, Response Personnel, Emergency Response Contractors, Immediate Response Actions, Emergency Response Equipment, Demobilization, Incident Documentation 2 Z CO a Z ' _0 W - CI) Q Z re 0 W a 1 CL W O W o > Z 0 Q Z w W V 9 Lr - CL w Pollution Prevention Measures: Hazard Evaluation, Vulnerability Analysis, Spill Containment & Recovery, Analysis for the Potential of an Oil Spill, Spill History, Product Characteristics/Hazards, MSDSs 3 Plan Implementation: Plan Implementation, Contractor Equipment and Manpower, Response Documentation, Site Safety and Health Plan, Decontamination Plan, Waste Management Plan, Disposal Plan, Containment and Drainage Planning, Security Plan, Wildlife Protection and Rehabilitation 4 Maintenance and Training Program: Self -Inspection Procedures, Response Equipment Inspection, Testing and Deployment Drills, Secondary Containment Inspection, Drills and Exercises, Response Training 5 Response Management System: Incident Management Team Description, ICS Structure, Common Responsibilities, Roles & Responsibilities Checklists, Public Affairs Guidance, Res•onse Management System 6 A • • endices Notifications A W Glossary / Acronyms B Forms C Diagrams D Waterline Maps E AllIli Waste Management and Disposal Plan F Well Control Emergency Management Plan G I Inland Spill Response Tactics Guide H March 2013 © The Response Group I iF'LAN NUMBER Ii' t+./1 Marathon Oil` Piceance Operations Emergency Response Plan Foreword DISTRIBUTION LIST ASSIGNED TO NUMBER OF COPIES 1 t Bryan Beautz 2 3 Grand Junction Office Parachute Office 1 hard copy 1 hard copy 1 hard copy March 2013 © The Response Group Page 2 Ii' te./1 Marathon Oil` RECORD OF REVISIONS Piceance Operations Emergency Response Plan Foreword REVISION"PAGE(S) DATE REMOVED jib 1 INSERTED I REASON FOR REVISION July 2009 Entire Plan Entire Plan New plan implemented January 2010 Entire Plan Entire Plan Removed all references to Drunkards Wash and Wamsutter operations and issued entire new plan covering Piceance operations only. March 2010 Entire Plan Entire Plan Changed title of document; updates to phone numbers in Section 2 January 2011 Entire Plan Entire Plan Updated title of document. July 2011 Entire Plan Entire Plan Logo update, revision to Section 2 and Appendix A. March 2013 Entire Plan Entire Plan Logo update, updates to Section 2, Appendix A; add Well Control Management Plan, Inland Spill Response Tactics Guide; updated response equipment listing. 1 March 2013 © The Response Group Ii' t+./1 Marathon Oil` Piceance Operations Emergency Response Plan Section 1: General Section 1: General 1.1 Purpose and Scope 1 1.2 Regulatory Compliance 2 1.3 Plan Review 2 1.4 Operations Information / Description 3 1.5 Diagrams 3 1.6 Person -in -Charge Responsibilities 3 1.7 Person -in -Charge Contact Information 4 March 2013 0 The Response Group indY Marathon Oil` Piceance Operations Emergency Response Plan Section 1: General 1.1 Purpose and Scope This response plan contains information applicable to the Marathon operations and locations in the Piceance Operations Area, hereafter referred to as "Company". The Marathon Piceance Operations Emergency Response Plan (ERP) is designed to provide Marathon company employees, and/or contractors, with information regarding specific systems, procedures, and operations, which will aid in the response to incidents. The plan covers emergencies that are global in nature and extend beyond a simple operational upset handled by operations personnel. While not designed as a "how to" manual, this document will serve as a resource tool for response to a variety of incidents. It is the responsibility of each employee to be familiar with and to be able to initiate this plan. Also, these individuals are responsible for assisting visitors, contractors, and other persons to assure their welfare. Printed copies may not reflect the most recent updates to this plan. Please refer to electronic versions on MOC CERT webpage located under Piceance Operations Emergency Response Plan section. Specific objectives of this plan are to: ✓ Define procedures and systems to help prevent emergencies. ✓ Define alert, notification, and accountability (both internal and external) procedures to be followed when an emergency incident occurs. ✓ Define the organizational structure within Marathon for responding to incidents occurring at the sites covered in this plan. ✓ Identify and list all available equipment and personnel resources for response to all facility incidents (both internal and external). ✓ Diagram response systems for use in emergencies. ✓ Outline general precautions to be taken in preparation for inclement weather. ✓ Describe the training requirements for Marathon response personnel. ✓ Identify sensitivities and protection strategies for response to spills within the geographic location boundaries of the plan. ✓ Satisfy requirements of regulatory agencies mandating written procedures to address response to emergencies occurring at Marathon sites in Colorado. March 2013 © The Response Group Page 1 indY Marathon Oil` ffIEW Piceance Operations mergency Response Plan Section 1: General 1.1 Purpose and Scope (Cont'd) This plan, with the resources and equipment listed herein, is a planning document to demonstrate the potential response capability available to respond to a condensate or produced water spill, or other defined emergency from each site within Colorado. It is not a guarantee of what will occur or the equipment/deployment sequencing that will be used in an actual event. Nothing in this plan is intended to limit the discretion of Marathon company employees, and/or contractors, to select any sequence of actions or to take whatever time they deem necessary to maximize the effectiveness of the response, consistent with safety considerations. This plan represents a planning standard, but is not and should not be regarded as a performance guarantee. Response operations in any event will be tailored to meet the actual circumstances. 1.2 Regulatory Compliance The ERP is based on the National Incident Management System (NIMS) Incident Command System and applicable state regulations. The Operations Superintendent is responsible for the implementation of this plan in coordination with the Incident Command System (ICS). 1.3 Plan Review The Emergency Response Coordinator is responsible for enforcing the schedule of implementation of the requirements of the completed plan. The plan must also be revised prior to implementing a change to the practices identified, and updated with revisions and history after an incident occurs. In the event that the Company experiences a discharge or release, the effectiveness of the plan will be evaluated and updated as necessary. If new information or different operating conditions would substantially effect implementation of the Plan, the Company will modify the Plan to address such a change. Ch `• -s . e defined as se that result Chan • e in: V Company policy as it relates to crisis management operations. ✓ Structure of response organizations. V Incident Management System. V Training and exercise programs or requirements. All revisions will be recorded on the Record of Revisions table in the Foreword. The Distribution List is also located in this section. March 2013 © The Response Group Page 2 Marathon Oil` Piceance Operations mergency Response Plan 1.4 Operations Information / Description Section 1: General Owner Marathon Oil CompanyOwner Address 5555 San Felipe Road Houston, TX 77263 Phone (24 HR): 866-MOC-CERT (866-662-2378) Location Address: 743 Horizon Court — Suite 220 Grand Junction, CO 81506 County (ies) Garfield and Mesa State(s): Colorado 1.5 Diagrams See Appendix D of this plan for Maps and Diagrams. 1.6 Person -in -Charge Responsibilities The duties of the designated Person -In -Charge are specified below: Additional duties or responsibilities assigned to the Person -in -Charge as defined by Marathon Corporation may be added to reflect the full scope of activity required. March 2013 © The Response Group Page 3 ✓ Activate internal alarms and hazard communications systems to notify all facility personnel ✓ Notify all response personnel, as needed .7Identify the character, exact source, amount, and extent of the release, as well as the other items needed for notification ✓ Notify and provide necessary information to appropriate Federal, State, and local authorities with the designated response roles, including the National Response Center, State Emergency Response Commission, and Local Emergency Planning Commission ✓ Assess the interaction of the discharged substance with water and/or other substances stored at the facility and notify response personnel at the scene with results ✓ Assess the possible hazards to human health and the environment due as a result of the release. This assessment must consider both the direct and indirect effects of the release (i.e., the effects of any hazardous surface waters, runoffs from water or chemical agents used to control fire and heat -induced explosion) ✓ Assess and implement prompt removal actions to contain and then remove the substance released ✓ Coordinate rescue and response action as previously arranged with all response personnel ✓ Use authority to immediately access company funding to initiate clean up activities ✓ Direct clean up activities until properly relieved of this responsibility Additional duties or responsibilities assigned to the Person -in -Charge as defined by Marathon Corporation may be added to reflect the full scope of activity required. March 2013 © The Response Group Page 3 imp Marathon Oil Piceance Operations Emergency Response Plan 1.7 Person -in -Charge Contact Information Section 1: General The Tier 1 Team Structure contact information is to be inserted into hard copies by local operations. March 2013 0 The Response Group Page Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions 1 2.1.1 Spill Response Notification 1 Figure 2.1 — Piceance Operations Spill Response Flowchart 2 Figure 2.2 — NAPO Environmental Incident Report 3 Figure 2.3 — Oil Spill and Hazardous Substance Release Report Form 4 Figure 2.4 — CDPHE 5 Day Spill Reporting Form 8 2.2 Response Actions 10 2.2.1 Corporate Emergency Response Team (CERT) 10 2.2.2 CERT Notifications/Activations 11 2.2.3 CERT Team Leader Notifications 12 Figure 2.5 Major Emergency Reporting Flowchart 12 2.2.4 Response Considerations 13 2.2.5 Initial Containment Actions 14 2.2.6 Condensate/Produced Water Spill 15 Figure 2.6 — Spill Estimation Factors 21 2.2.7 Fire / Explosion 23 2.2.8 Toxic/Flammable Gas Release 26 Figure 2.7 — Gas Release Emergency Flowchart 27 2.2.9 Gas Pipeline Response Guide 28 2.2.10 Air Monitoring 45 Figure 2.8 — Air Monitoring Decision Flowchart 45 2.2.11 Well Control/Drilling/Completions Emergency Measures 50 Figure 2.9 — Well Control/Drilling/Completions Emergency Flowchart 52 2.2.12 Severe Weather 55 Figure 2.10 — Tornado/Earthquake/Flood Emergency Flowchart 57 2.2.13 Medical Emergency 60 Figure 2.11 — Medical Emergency Flowchart 63 2.2.14 Failure of Transfer Equipment 66 2.2.15 Tank Overfill / Failure 66 2.2.16 Piping Rupture/Leak (under pressure and no pressure) 66 2.2.17 Manifold Failure 66 2.2.18 Bomb Threat 67 Figure 2.12 — Bomb Threat Flowchart 67 2.2.19 Evacuation 69 March 2013 .} © The Response Group indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.3 Emergency Response Equipment 71 2.3.1 Facility Owned Response Equipment 71 2.3.2 Contractor Owned Response Equipment 75 2.3.3 Letters of Intent 76 Ecos Letter of Intent 76 CES Letter of Intent 77 Clean Harbors Letter of Intent 78 Veolia Letter of Intent 79 2.3.4 Response Contractor Equipment Lists 85 Ecos 85 CES 86 Clean Harbors 104 Veolia 109 2.4 Demobilization 130 2.4.1 Equipment Demobilization 130 2.5 Incident Documentation Procedures and Response Critique 135 2.5.1 Post Incident Review 135 March 2013 © The Response Group Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions The information provided throughout this section shall describe what will be needed in an actual emergency involving the discharge of condensate, produced water, or a combination of hazardous substances and condensate/produced water discharge. This same information will also aid in the assessment of the company's ability to respond to a worst case discharge while identifying additional assistance opportunities. 2.1 Initial Discovery / Response Actions 2.1.1 Spill Response Notification The information provided in the Spill Response Notification Form creates a checklist of information that shall be provided to the National Response Center (NRC) and other response personnel. All information on this checklist must be known at the time of notification, or be in the process of being collected. The information contained in this form is similar to the form used by NRC. Note: Do not delay spill notification to collect the information on the list. Initial response actions are those taken by local personnel immediately upon becoming aware of a discharge or emergency incident. Timely implementation of these initial steps is of the utmost importance because they can greatly affect the overall response operation. Initial Discovery / Response Actions Checklist a. DISCOVERER I Initiate Initial Response Procedures and Notifications PERSON -IN -CHARGE RESPSONSE GUIDELINES The appropriate response to a particular incident may vary depending on the nature and severity of the incident. ✓ Action Definition 1 Consider safety of personnel / call for medical assistance if needed. Pull an alarm, push an evacuation button, use radio or call 911. EVACUATE IF NECESSARY. • 2 • Shut off ignition sources. Motors, open flames, electrical circuits. 3 Secure the source. Act quickly to shut-in source, close valves, etc. (IF SAFE TO DO SO, PROPERLY TRAINED & HAVE PROPER PPE). • 4 Coordinate rescue and medical response actions. Perform this task only if trained to do so (i.e., member of medical & rescue teams) Refer to hospital listings in local notifications section of Section 2. • 5 Identify pollutant and assess possible hazards to human health and the environment. Identify source and volume; characterize oxygen levels, explosive character, toxicity of air on scene, splash and ingestive hazards. • 6 Initiate containment if necessary and safe to do so. Contact OSROs as necessary. • 7 • Report all incidents. Follow Notification Procedures, Section 2. March 2013 © The Response Group Page 1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Respons Actions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 SpiII Response Notification (Cont'd) Figure 2.1 — Piceance Operations SpiII Response Flowchart Bh@cmcrw Report Emergency Take Immediate Response Actions Continue Response Determine Potential for Impact of Sensitive Areas Decon / Demobilization D oll�ni�ll�rlli ��?}o�,��il • Report the spill to the Production Supervisor • Production Supervisor to notify proper Federal/State authorities • Refer to the Agency Notification section for reporting requirements and contact information 2 3 4 5 • Conduct hazard assessment • Develop site safety plan prior to entry • Analyze spill type to determine immediate actions to shut off source • Stop discharge if safe to do so • Construct containment barrier downstream of spill • Use sorbent material to minimize spread • Call for vacuum truck and other response equipment if practical • Eliminate sources of ignition to prevent fire/explosion • Restrict entry into affected area to those involved in the cleanup operations • Assess spill size and volume • Perform surveillance • If no threat exists, continue current response • If threat exists, employ protection methods • Develop decontamination and disposal plans prior to conducting operations in area where a potential for exposure to hazardous substances exists • Develop demobilization plan prior to ceasina operations March 2013 © The Response Group Page 2 Marathon Oil` Piceance Operations Emergency Response Plan 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 Spill Response Notification (Cont'd) Figure 2.2 — NAPO Environmental Incident Report MOO NAPO WITHAL EMVIkONMENTAL INCI[IEMr RE P4ikt 0 IMtu.Jnr. 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Ano NA -'Van Folhw-up • 1:',IEIP_411J.- �'1g11 :nay P-06.a.r :_. 1[•'•' lle-uer1 Froin CR•x :.gill 4E001 .lIE 4`P4 Errorri@Mil F €tbio7r71 ox.i, completer 1+ 05is NonRl4'n116 In8 :niirJcttr4 17 ortooak MINIM March 2013 © The Response Group Page 3 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 Spill Response Notification (Cont'd) Figure 2.3 — Oil Spill and Hazardous Substance Release Report Form OIL SPILL AND HAZARDOUS SUBSTANCE RELEASE REPORT FORM r Marathon Oil Company Region/Division/District r Marathon Petroleum Company Division/District r Marathon Pipe Line Company Division/District r Other: SPILL DATE MO DA YR EST. SPILL TIME AM PM ESTIMATED SPILL VOLUME TYPE OF MATERIAL SPILLED SIGHTED BY VOLUME RECOVERED 1/0/1900 12:00 AM 0 0 LOCATION OF SPILL: (Include State, County, Lease, Field, Rig/Platform) Onshore Section Township Offshore OCS-G-No. Range Latitude Longitude DESCRIPTION OF SPILL AREA, LOCATION & DIRECTION OF MOVEMENT: WATER/GROUNDWATER AFFECTED r Yes r No If Yes, Name of water body affected: Sheen/Slick Appearance t‘.ceor: r,erely visible, rainbox, dark black, etc.) Weather: r Clear r Cloudy r Fog r Rain r Snow r Ice Temperature Wind: Velocity mph Direction (N, SE, etc., From) Wave: Height ft. Direction (N, SE, etc., To) Current: Velocity mph Direction (N, SE, etc., To) Tides: (ebb, flood, high, low, direction, velocity, etc.) CAUSE OF SPILL: (Facts only, No Opinion or Speculation) Form 1487-D Rev. 9-87 -OVER- March 2013 © The Response Group Page 4 Ii''t►./1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 Spill Response Notification (Cont'd) Figure 2.3 — Oil Spill and Hazardous Substance Release Report Form (Cont'd) RESPONSE PROCEDURES: (Containment, recovery & cleanup procedures): STEPS TAKEN TO PREVENT RECURRENCE: APPARENT HAZARDS TO LIFE AND PROPERTY: FACILITY DAMAGE OR INJURIES: EMPLOYEE RESPONSIBLE FOR CLEANUP: NOTIFICATION OF REGULATORY AGENCIES: A. Agency Telephone No. Time Date Person Contacted Comments B. Agency Telephone No. Time Date Person Contacted Comments C. Agency Telephone No. Time Date Person Contacted Comments D. Agency Telephone No. Time Date Person Contacted Comments PERSON MAKING CONTACT WITH AGENCIES: IF CORPORATE OFFICE NOTIFIED: Person Contacted: Person Filing Report: Print Name Form 1487 Rev 9-88 (BACK) Upon completion of this form, return to the Instructions Time Date Signature Instructions Date March 2013 © The Response Group Page 5 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 Spill Response Notification (Cont'd) Figure 2.3 — Oil Spill and Hazardous Substance Release Report Form (Cont'd) OIL SPILL AND HAZARDOUS SUBSTANCE RELEASE REPORT FORM r Marathon Oil Company Region/Division/District r Marathon Petroleum Company Division/District r Marathon Pipe Line Company Division/District r Other: SPILL DATE MO DA YR EST. SPILL TIME AM PM ESTIMATED SPILL VOLUME TYPE OF MATERIAL SPILLED SIGHTED BY VOLUME RECOVERED 1/0/1900 12:00 AM 0 0 LOCATION OF SPILL: (Include State, County, Lease, Field, Rig/Platform) Onshore Section Township Offshore OCS-G-No. Range Latitude Longitude DESCRIPTION OF SPILL AREA, LOCATION & DIRECTION OF MOVEMENT: WATER/GROUNDWATER AFFECTED r Yes r No If Yes, Name of water body affected: Sheen/Slick Appearance p..olor: shy., y, .,erely visible, rainbox, dark black, etc.) Weather: r Clear r Cloudy r Fog r Rain r Snow r Ice Temperature Wind: Velocity mph Direction (N, SE, etc., From) Wave: Height ft. Direction (N, SE, etc., To) Current: Velocity mph Direction (N, SE, etc., To) Tides: (ebb, flood, high, low, direction, velocity, etc.) CAUSE OF SPILL: (Facts only, No Opinion or Speculation) Form 1487-D Rev. 9-87 -OVER- March 2013 © The Response Group Page 6 IN. hy MarathonOil• Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 Spill Response Notification (Cont'd) Figure 2.3 — Oil Spill and Hazardous Substance Release Report Form (Cont'd) CAUSE OF SPILL: (Facts only, No Opinion or Speculation) RESPONSE PROCEDURES: (Containment, recovery & cleanup procedures): STEPS TAKEN TO PREVENT RECURRENCE: APPARENTHAZAROS TO LIFE AND PROPERTY: rACILFTY DAMAGE OR INJURIES: EMPLOYEE RESPONSIBLE FOR CEANUP: NOTIFICATION OF REGULATORY AGENCIES: Agency Telephone No. Time Date Person Contacted Comments Agency Telephone No Time ❑ale Person Contacted Comments Agency Telephone No. Time Date Person Contacted Comments Agency Telephone No, Time Date Person Contacted Comn-ient PERSON MAKING CONTACT WITH AGENCIES: IF CORPORATE OFFICE NOTIFIED: Person Contacted: Person Ring Report: Print Name Time Signature Date March 2013 © The Response Group Page 7 Marathonoil 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 SpiII Response Notification (Cont'd) Figure 2.4 — CDPHE 5 Day SpiII Reporting Form Piceance Operations mergency Response Plan Section 2: Emergency Response Actions Colorado Department of Public Health and Environment Incident 1 SpiII 1 SSO Release Reporting Water Quality Control Division Five (9) Day Reporting Form Deriver Field Engiiieeririg Unit ❑ 4300 Cherry Creek Dr. South, 132 Denver, Colorado 80246-1530 Phone: 3D3-882-3650 Fax: 303-782-D390 Contact email: annemarie.goalsby@state co.us E Soullerrr Field Enyineeriiiy Ui.it 4718 North Eizabeth Si_, Suite 8 Pueblo, CO 81008 Telephone: 719-545-4550 Fax: 719-543-8441 Contact email: carol.keeuer@state.co_us • Wesie-ii Field Errgireeriiig Unit 777 South 6th Street, Room 232 Grand Junction, GO 81501 Telephone: 970-24B-7150 Fax: 970-248-7198 Contact email: inichelle_thiebaud@state_co.us Reporting Form: Incident 1 SpiII 1 Sanitary Sewer Overflow (SSO) The Division distinguishes between reporting requremen for spills that occur with respect to activities that result in a discharge that is authonzed under a CDPS permit and those that are not_ Reportinc and management of spills that occur with respect to activities resulting in a disc^iarge authorized under a permit should be pe -formed n accordance with the specific requirements of that rlermit if the permit cops not require a 5 -day repnrt, please prrvide= the infnrma-inn below in writing_ For non -Permitted activities, or in the case of an activity where a permit does not address reporting of or response to a given sp:II, please suarriita written iespurrse to the Water (Dually Control D vision williirr five (5) Nub! days of Ike date of the event. If sufficient space is not provided then please attach other sheets. Please send the completed form including signature via fax or emal to the Division's Field Engineering Unit office for the County that the incident t spill I SSO took place (sec above )_ If you have any questions please contact the Diviaton"s Field Engineer at your earliest convenience. The Field Engineer County list is available at: http:IJvrww.cdp ie_state_eo_r,slwgfengineenngltech iom.him! Prior to the five (5) working day deadline, you may request an extension to submit the report if sample analyses justifiably are Doing to require more time to analyze than the reporting time allows_ To request an extension please serd an email to Me Division's Field Engineer for the County that the incident I spill / SSC took place or to the email listed above. Incident Background Informa:ion County inciifeiit? Spill Nurritrei (Division provktec) • Sanitary Sewer Overllo +iReuse • Petroleum Product ❑ Chemical Type of Incident !Spill f SSO (check cite) ❑ 'MP Treatment Plant Bypass or 1pset ,throigh an authorized (Mail pont) m • Cobiner Sewer Overflow El8iosollds ❑ Jnptanned potable water reease (e.g., water line streak) ❑ Omer Contact Information Potentiaty Responsible Party (I -Ht -°I: Contact Name Potentially Resporsible Party LN1a1-1. Company ) Agency PRP Pnone /Fax Fhnne•PRP ax: email address CDPS Perm:Number CDPS Permittee Name: Reported by Of not PRP): Contact Name Reported by (1 not PRP): Company 1 Agency Reported by (rr not PRP): Phone / Fax Prone: Fax: Reported Dy (°r not PRP)_ email address Incident Information: Please provide the following information. A Incident / spill + SSO source, cause, and event description Response: B Material released (e.g., untreatec wastewater, aiosdids, specifc chemicals or products) and estimated toia. quantity (e.g., gallons). Please attach MSDS for any and all chemicals or products involved in spill or release_ Response: C Actual or estimatec dates and times cf the event. including duration and actual date and tirne spill was fully controlled/sttop:ed_ if release is still occuring, the date and time die release is expected to be stoppec. Response: Revised November 2011 Incident Reporting Hotline 1-877-518-5608 Page I oft « 0. ƒ ■ 0 C 0 0 2 2 CD CD 'rkp Piceance Opera ions - Section Marathon Oil. Emergency Response Plan Emergency ResponseActions 2.1 Initial Discovery / Response Actions (Cont'd) 2.1.1 SpiII Response Notification (Cont'd) Figure 2.4 — CDPHE 5 Day SpiII Reporting Form (Cont'd) Revised Vavemher2C r I Incident Reporting Hotline 1-E77.518.5&O8 Page 2of2 Coloracc Department of Public Health and Environment Incident 1 Spill I SSD Release Reporting Water Duality Contr©I Division Five (5) Day Reporting Farrar c r m Incident Impact to Areas a- Water Users — z 02D6 � , §%& \\§ \rb } /� f%! ®(§ /(= (2/ //; 64� \\\ eap 0{. (}w �E \\ 8 .() .m al - '4 f § m m o Resporse: How were the impacted area users (e.g., aark patrons) and downstream water users notified (e.g., signs posted. list dtmrlstieerrr users cunlda vtd psi lune). Resporse: Did Me incicenl i spIII r ssu Impact any areas re.g., patine use areas Including parks cr swim beaches) or downstream water users {e.g., public w water s.ipplrers, Irrigation ditierslonsl- Please list impacted areas anra'orusers, trier Iocaticn, and potential impacts. +222 I # }} E= §/ a)\3 f 3-Z\\ E \ \ \ / / / ( K `k/ O { %@ Resporse: Did Tow or materials reach groundwater of the State? If so, please describe the path of flow to State waters and whicn Sta-ie water body impaced (e.g. spill soaked into gro.and and wet soli was not excavated}. 11 yes. what quantity of material (e_g_, gallons' reached the ground or groundwaterand what ryas the resulting Impact? ig Were any water quality samples or other sampes taken'? ifso, please describe sampling process an attached resutls_ Resporse: Did fow or materials reach surface waters of tre State? If aa, please oescrbe the path of lbw to State waters and which State water body was impacred (e:g_, spill impacted a sto-rn drain which was directly connected to Cherry Creek, Colcrado fiivei,etc.)_ Ifyes,what r}udrrlilyurmaterial{e.g. gallas} reached the surface wale' andtnIeLyaw, lirere lLiriyimpact? ƒ ) Steps taken or ntanrrert to prevent reoccurrence rf the event $ ) q Describe measures taken or planned to contain, redjce, and clear up spill or release_ f ; Locatloa of release {e.g.. address latllonp, road narne and mile marker). o 13 2 1} chat the information prcrtcd allow is accurate and complete. Typed Name and Title on ca sr et, ✓ Emergency preparedness The responsibilities of senior management, of the Emergency Preparedness Group, and of operating organizations; and The preparedness and response programs comprising Marathon's approach to crisis management. Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions 2.2.1 Corporate Emergency Response Team (CERT) Marathon Oil Company's Emergency Preparedness Policy and Plan outlines the rathon company -wide policy on: To assure that total corporate manpower, resources, support, and response management are available to communicate, respond to, and manage an emergency, Marathon Oil Company maintains a Corporate Emergency Response Team (CERT). ERT has three • s nsibiliti ✓ To provide SUPPORT to Asset Team Management in an emergency / To NOTIFY and ADVISE Executive Management concerning an emergency ✓ To provide response management team assistance, including the capability of a STRIKE TEAM taking command of the response operations. One of the general provisions of Marathon's Emergency Preparedness Policy and Plan is local management's responsibility to notify CERT whenever an emergency is or may become a major emergency. The CERT team leader is the person Asset Team Management must notify. In consultation with Asset Team Management, the CERT team leader will decide what level of CERT support is needed. W • . : n take several forms icluding: ✓ Executive management notification; ✓ Providing support through any or all of the emergency support groups ; ✓ Activation of the Houston CERT situation rooms to coordinate response activities; ✓ Providing on-site response management assistance with the emergency strike team (EST). The EST is a fully trained and prepared stand-alone response management team, capable of supplementing, relieving or taking command of an emergency. The EST has full access to and incorporates the support and resources available from the ESG. The EST is trained in the Incident Command System (ICS), which is used during drills, training, and emergency responses. March 2013 © The Response Group 1111 Page 10 AWN Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Respons Actions 2.2 Response Actions (Cont'd) 2.2.2 CERT Notifications/Activations To assure that total corporate manpower, resources, support, and response management are available to communicate, respond to, and manage an emergency, Marathon Oil Company maintains a Corporate Emergency Response Team (CERT). As identified in the Emergency Policy and Plan document local management has a responsibility to notify CERT whenever an emergency is or may become a Major Emergency. Local Management must utilize their best judgment to notify CERT for potential involvement. One should error on the conservative aside rather than not notifying CERT. •-- - _,,. 'n • are examples of Major Emer• enc ' -' An event resulting in a fatality An evacuation of five (5) or more residential homes or all or part of one or more public buildings. An event resulting in the hospitalization of three (3) or more people An event which receives more than passing local media coverage or any regional/national media attention. An explosion /fire not immediately handled by local resources. Whenever loss of well control occurs. An explosion/fire which could result in substantial loss. Any terrorist activities. Any hydrocarbon spill in excess of 500 barrels or any spill in excess of 50 barrels that reaches fresh water A natural disaster which may develop into a Major Emergency. A hazardous substance spill/release in excess of three (3) times the U.S. Federally reportable quantity. A situation -involving product recalls or tainted or contaminated merchandise. A smaller spill or release of hazardous substance in environmentally or socially sensitive areas. Any other event in which third -party damage could exceed $100,000 or Company property damages or losses could exceed $250,000. NOTE: THIS LIST IS NOT TO BE CONSTRUED AS ALL-INCLUSIVE. LOCAL MANAGEMENT SHOULD UTILIZE THEIR BEST JUDGEMENT IN INFORMING CERT OF MAJOR EMERGENCIES. LOCAL MANAGEMENT is responsible for responding to emergencies that impact their facilities and operations. If the emergency is a MAJOR EMERGENCY, or if the emergency has the potential of developing into a MAJOR EMERGENCY, LOCAL MANAGEMENT MUST NOTIFY THE CERT TEAM LPAIIP IMMEDIATELY AFTER ACTIVATING THE LOCAL RESPONSE PLAN. ACCESS TO, AND ACTIVATION OF THE EMERGENCY STRIKE TEAM (EST), INTERNATIONAL EMERGENCY STRIKE TEAM (IEST), OR EMERGENCY SUPPORT GROUP (ESG) IS ACCOMPLISHED THROUGH CONTACTING THE APPROPRIATE CERT TEAM LPACEFR March 2013 © The Response Group Page 11 Ii''t`►./1 Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.3 CERT Team Leader Notifications A CERT TEAM LEADER (MOC) is available 24 hours a day and can be contacted as detailed below. The caller shall indicate that this is a corporate emergency and request to be connected with a CR! TEAM LEADER (Use the CERT Notification/Activation Information sheet to record incident information) MARATHON OIL CERT TEAM LEADER- 1-866-MOC CERT (662-2378) OR 1-606-329-5701 Marathon Central Notification System will connect Local Management with a !='r TEAM LEADER Figure 2.5 Major Emergency Reporting Flowchart EXECUTIVE MANAGEMENT A LINE MANAGEMENT 1 LOCAL MANAGEMENT Activate/Initiate Response Actions MAJOR EMERGENCY 1 4 + CERT TEAM LEADER EST IEST ESG The CERT TRAM LEAfER in consultation with Local Management, will decide what level of CERT support is needed. Activation can take several forms including: Executive Management Notification Support from the EST, IEST or ESG ✓ Activation of the Houston CERT Situation Rooms March 2013 © The Response Group Page 12 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.4 Response Considerations Wil=rEM Combustible Products ✓ Give careful consideration for containment actions conducted during inclement weather or adverse conditions, such as high winds or rapid currents. ✓ Eliminate all ignition sources and keep boats as far as possible from the spill area. ✓ Be aware of hazards such as fires, explosions and exposure to toxic chemicals at lethal or sublethal levels. ✓ Avoid contact with the spilled product and ensure that the area remains secure to boat and air traffic. V Be aware of potential changes to position and movement of slick due to tidal action. ✓ The Safety Officer will be initially responsible to assure the safety of all people who may be impacted by the spill. ✓ The Safety Officer will be responsible for the preparation of the Health and Safety Plan and will establish safety zones, as appropriate. ✓ All response contractor Safety Officers will be advisors to the Company Safety Officer on health and safety issues. ✓ Consider using trained personnel equipped with supplied air respirators and air monitoring instruments (02, H2S and combustible gas meters) to identify and mark/map unsafe areas. March 2013 © The Response Group Page 13 Combustible Products ✓ Identify source and stop discharge, if possible. ✓ Deploy Facility containment boom and skimmers if available, to attempt to isolate the slick and reduce the spread and potential impact area. Monitor the boom for effectiveness. ✓ If shorelines may be impacted, consider deploying exclusion boom to reduce the impact to shoreline. ✓ If there is still boom remaining, attempt to isolate pockets of condensate/produced water where possible to facilitate more efficient recovery. ✓ If product escapes, deploy sorbents along the shoreline to capture product during tidal cycles. Monitor the sorbents periodically for effectiveness and replace as needed. ✓ If product is ignited, Site Safety Officer should consider the need for responders to use respiratory protection. ✓ Activate response contractors to assist in containment efforts and begin recovery operations. ✓ Advise neighboring operators of any threat to their property or personnel. ✓ Determine the direction and expected duration of spill movement. ✓ Review the location of environmentally and economically sensitive areas. ✓ Determine which of these areas may be threatened by the spill and direct contractors to proceed with boom and skimmers to these specified locations. March 2013 © The Response Group Page 13 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.4 Response Considerations (Cont'd) laminable Initial Producs ex: con • ensat - ✓ Identify source and stop discharge, if possible. ✓ If shorelines may be impacted, consider deploying exclusion boom to reduce the impact to shoreline. ✓ If product escapes, deploy sorbents along the shoreline to capture product during tidal cycles. Monitor the sorbents periodically for effectiveness and replace as needed. ✓ If product is ignited, Site Safety Officer should consider the need for responders to use respiratory protection. ✓ Activate response contractors to assist in containment efforts and begin recovery operations. ✓ Advise neighboring operators of any threat to their property or personnel. ✓ Determine the direction and expected duration of spill movement. ✓ Review the location of environmentally and economically sensitive areas. ✓ Determine which areas may be threatened by the spill and evaluate deploying diversion/exclusion boom to these specified areas. 2.2.5 Initial Containment Actions March 2013 © The Response Group Page 14 Initial Containment Actions Initial containment actions will focus on utilizing on-site containment boom to: ✓ Limit the spread of condensate/produced water, thereby reducing the surface area and shoreline to be cleaned, ✓ Concentrate the condensate/produced water, when safe to do so, making physical recovery more efficient, and ✓ Limit the environmental impact to the immediate spill area. Selection of the appropriate location and method will depend upon: ✓ Whether the product spilled is produced water or condensate, ✓ Whether the spill occurs during an ebb or flood tide, ✓ Length of time spill occurs before being noticed, ✓ Amount of spill, ✓ Area of coverage, ✓ Environmental factors such as wind speed and direction, and ✓ Safety considerations. March 2013 © The Response Group Page 14 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill On Land All spills, regardless of the quantity, shall be reported to the respective area Production Supervisor. The Production Supervisor and/or their designee shall then use the flowcharts contained in the Reporting Section(s) of this is manual to determine if the spill is reportable. If the spill is determined to be reportable, the Production Supervisor will be responsible for notifying the proper federal/state and local authorities, the area's Asset Team leader and HES Department of the spill. If additional Marathon Oil Company (MOC) resources are needed to respond to the spill, the Production Supervisor shall inform the Asset Team leader of this need. The Asset Team leader will be responsible for obtaining the additional MOC resources that are needed to respond to the spill (i.e. activating the Incident Command System). Gas leaks and gas line breaks shall be reported in the same manner as condensate/produced water spills. All gas leaks (whether it is natural gas or casinghead gas) need to be reported to the appropriate state oil and gas regulatory agency. Venting of gas from tanks, pressure relief valves, etc. is not reportable under this section. However, these types of releases may be reportable under Federal regulations (CERCLA/SARA) or under the State Air Control Agency regulations. If the escaping gas or oil contains H2S, consult the applicable H2S Contingency Plan for that facility for additional guidance. In the case of a condensate/produced water spill/gas leak from a producing well, a testing vessel, a tank, flow line or any other related oil field equipment, action should be designed to protect human life and control the spill as rapidly as possible. All steps should be considered carefully; however, the timing of these steps should be altered to fit the individual circumstances. March 2013 © The Response Group Page 15 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water SpiII (Cont'd) On Land ctions to Respond to a Condensate/Poduced Water SpiII / Gas Le. -: V An employee sighting a spill shall identify the safety concerns and analyze the type of spill to determine the immediate action to be taken to shut off the source of the spill, and to contain the condensate / produced water released. ✓ Obtain labor and equipment from the nearest source to construct a containment barrier as rapidly as possible. ✓ If Item above is only a temporary measure and earth moving equipment is required, call out the necessary equipment from the source from which it is most readily available. ✓ Employ the use of the most readily available absorbent material (straw, dirt, lost circulation material, etc.). When the location is a heavy clay soil, dirt will be ineffectual. ✓ If practical, call for vacuum truck to pick up hydrocarbons. ✓ Collect lighters and matches from personnel working in the area to assure an explosion or fire does not occur. ✓ Restrict entry into affected area to persons involved in containment and cleanup operations. ✓ Notify Asset Team leader of spill and action being taken. The Asset Team leader will notify the Business Unit's upper management of the spill. ✓ Keep livestock away from affected area and if practical, notify the farmer or rancher of the situation. ✓ The Production Supervisor will notify the required regulatory agencies of the spill. Refer to Contact Information in Section 2.2 of this plan. ✓ In the event the spill results in curtailing deliveries, the Production Superintendent will notify the purchaser. ✓ The Duty Officer at the National Response Center must be notified immediately when a spill reaches "waters of the U.S.", or it appears certain that the spill will reach "waters of the U.S.". March 2013 © The Response Group Page 16 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill (Cont'd) On Inland Water All action should be designed to protect human life and control the spill as rapidly as possible. All steps listed should be considered; however, timing of these steps should be altered to the individual circumstances to best accomplish these objectives. Any employee sighting a spill shall identify the safety concerns and analyze the type of spill to determine the immediate action to be taken to shut off the source of the spill, and to contain the condensate/produced water released. The employee is responsible for notifying his supervisor or the Production Supervisor who will then advise the Asset Team leader of the spill. The Production Supervisor shall notify immediately the appropriate state and federal agencies. e following employee and/or Production Supervisor will uitheir best estimate of the information concerning the spill: I ✓ Location of the spill ✓ Source and type of product spilled V Is the source of the spill controlled? I V Area covered and approximate volume ✓ Direction and speed of movement of spill I ✓ Currents (if applicable) ✓ Estimate of the area likely to be affected ✓ Other actions taken ✓ The Incident Commander or his/her designated representative shall keep a daily log of response activities. The log book shall be bound, not loose leaf. Entries shall be dated, time and signed. March 2013 © The Response Group Page 17 ✓ If the spill is minor (5 to 25 bbls) and a boom is not immediately available, sorbent material should be spread on the spill and collected afterwards. ✓ Attempts should be made to clean up the shoreline and recover as much product as possible. NOTE: In the event of a spill, the HES Professional will contact the appropriate state regulatory agency to receive permission to dispose of spilt fluids to an injection location. If permission is NOT granted, the fluids must be collected and trucked off-site to be disposed of properly in an approved location. March 2013 © The Response Group Page 17 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill (Cont'd) On Inland Water (Cont'd) CERT Reporting Requirements In certain cases a spill or release may trigger reporting requirements under Marathon's Corporate Emergency Response Plan. Refer to the CERT section to make this determination. Note: CERT notification is to be made by the Business Unit Manager or his/her designee. Regulatory Agencies to Be Notified The flowcharts contained in the State and Federal Reporting sections provide guidance for determining when a spill is reportable and which regulatory agencies need to be notified. Phone numbers for all of these agencies are listed in the section entitled, "Agency Information." March 2013 © The Response Group Page 18 In all 1) stop services etc. probability, a major spill (greater than 25 bbls) will initially require two basic efforts: the leak, and 2) contain the spill. Stopping the leak may require other outside such as well control specialists, a drilling or workover rig, pipeline repair crew, Requirements should be determined and action initiated as soon as possible. ✓ To contain the spill, if a containment boom is readily available, order it out immediately and commence skimming operations as soon as possible. ✓ If a contract or coop -containment service is to be employed, it should be mobilized without delay. ✓ If weather and water conditions are such that the time required to implement containment will permit the spill to spread beyond possible containment; sorbent material should be spread on the spill. V Shoreline work sites for each facility shall be pre -selected, marked as such and made known to the employees who will be involved in spill control activities for the facility. ✓ In shallow water, containment should be attempted by boom and the material hand - harvested. ✓ If sorbent material has been employed, the local air control agency should be contacted for permission to burn the collected material. ✓ When applicable, aircraft should be employed to discourage waterfowl from staying in the spill area. ✓ A photographic record of the spill movement, containment and cleanup operations, damage to property, fish kills, efforts to disperse waterfowl, waterfowl kills, and other relevant actions should be kept. NOTE: In the event of a spill, the HES Professional will contact the appropriate state regulatory agency to receive permission to dispose of spilt fluids to an injection location. If permission is NOT granted, the fluids must be collected and trucked off-site to be disposed of properly in an approved location. CERT Reporting Requirements In certain cases a spill or release may trigger reporting requirements under Marathon's Corporate Emergency Response Plan. Refer to the CERT section to make this determination. Note: CERT notification is to be made by the Business Unit Manager or his/her designee. Regulatory Agencies to Be Notified The flowcharts contained in the State and Federal Reporting sections provide guidance for determining when a spill is reportable and which regulatory agencies need to be notified. Phone numbers for all of these agencies are listed in the section entitled, "Agency Information." March 2013 © The Response Group Page 18 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill (Cont'd) Definition of Watercourse or Waters of the U.S. The term watercourse is defined as any spill which enters or threatens to enter the navigable waters of the United States and is reportable to the NRC. However, due to the complexity of the definition of navigable waters, in the event of a spill which threatens a waterway, the HES&S department should be consulted to make an initial determination as to whether or not navigable waters of the United States might be impacted. CERCLA/SARA Reporting Requirements In some cases a spill may trigger reporting requirements under EPA's CERCLA/SARA regulations. Reference the CERCLA/SARA document to determine when a spill is covered by these reporting requirements. March 2013 © The Response Group Page 19 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill (Cont'd) CERT Reporting Requirements In certain cases a spill or release may trigger reporting requirements under Marathon's Corporate Emergency Response Plan. Refer to the CERT section of the Emergency Response Plan to make this determination. 4 ill Volume Estimating Early in a spill response, estimation of spill volume is required in order to: V Report to agencies ✓ Determine liquid recovery requirements ✓ Assess manpower and equipment requirements V Determine disposal and interim storage requirements In the event that actual spill volumes are not available, it may be necessary to estimate this volume. March 2013 © The Response Group Page 20 stimation. et V Visual observation and calibration with the A.P.I. Task Force on Oil Spill Cleanup, Committee for Air and Water Conservation's Spill Size Estimation Matrix. This matrix is included as Figure 2.4. ✓ Other methods which can be used to determine size and volume of a spill include, but are not limited to: • Other methods which can be used to determine size and volume of a spill include, but are not limited to: • Vessel/line capacity formulas • Infra -red thermal imaging March 2013 © The Response Group Page 20 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water SpiII (Cont'd) Figure 2.6 — SpiII Estimation Factors Use this table to calculate the amount of condensate / produced water released. Estimated Area* (sq ft) �•• • 'r• • • _..e •.__ Barely Discerni ble Silvery Sheen Faint Colors Bright Bands of Color Dull Brown Dark Brown 1,000 < 1/8 < 1/8 < 1/8 < 1/8 < 1/8 < 1/8 5,000 < 1/8 < 1/8 < 1/8 < 1/8 < 1/8 3/8 10,000 < 1/8 < 1/8 < 1/8 < 1/8 1/4 2/5 15,000 < 1/8 < 1/8 < 1/8 < 1/8 3/8 1/2 20,000 < 1/8 < 1/8 < 1/8 1/4 2/5 1 30,000 < 1/8 < 1/8 < 1/8 1/4 3/5 1 50,000 < 1/8 < 1/8 1/4 2/5 1 3 100,000 < 1/8 1/4 2/5 3/4 3 5 300,000 3/8 3/5 1 2 6 14 600,000 1/2 1 2 4 13 29 900,000 3/4 2 3 7 20 43 1,000,000 7/8 2 4 7 22 47 1,250,000 1 2 5 9 27 59 1,500,000 1 3 5 11 32 70 1,750,000 2 3 6 13 38 82 2,000,000 2 4 7 14 43 94 4,000,000 4 8 15 30 90 95 6,000,000 5 11 22 44 132 286 8,000,000 7 15 29 58 174 377 10,000,000 9 18 36 72 216 468 12,500,000 11 23 45 90 270 585 15,000,000 14 27 54 108 324 702 17,500,000 16 32 63 126 378 819 20,000,000 18 37 72 144 432 936 22,500,000 21 41 82 164 492 1,066 25,000,000 23 45 90 180 540 1,170 27,500,000 25 50 100 200 600 1,300 *Arrived at by multiplying estimated length of spill by estimated width. Round up to next highest value. **Calculated from guide published by the API Task Force on Oil SpiII Cleanup, Committee for Air and Water Conservation. < Means less than March 2013 © The Response Group Page 21 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.6 Condensate/Produced Water Spill (Cont'd) Estimating Spill Trajectories Spill trajectories may initially be estimated in order to predict direction and speed of the slick movement. Trajectory calculations provide an estimate of where slicks may impact shorelines and other sensitive areas and provide an estimate of the most likely locations for protection, containment and recovery. Marathon will utilize internal subject matter experts with consultants as necessary to perform trajectory analysis and fate & effect modeling. Input variables for proper modeling include, but are not limited to: V Spill location, volume, and time of spill ✓ Nature of the spill - continuous or single incident V Wind speed & direction V Water movement (current) speed & direction V Water temperature V Sea state ✓ Atmospheric temperature / Characteristics of spilled material This in orma ion can be obtainem many sources, including but not limited toil ✓ Reports from personnel at the spill site ✓ Commercial weather services ✓ National Oceanic and Atmospheric Administration (NOAA) ✓ Internal Marathon databases ✓ Marathon & commercial laboratories Marathon utilizes an extensive communication infrastructure in its operations. This infrastructure includes telephone & radio networks. These networks will be used to connect all elements of the response. Back-up systems exist in the form of commercial VHF radios, cellular telephones, and couriers. Marathon Corporation and various contractors own and maintain mobile command centers with extensive communication capabilities. Standard ICS Forms will be used wherever possible. March 2013 © The Response Group Page 22 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.7 Fire / Explosion In case of a fire at any Marathon Oil Company facility, action should be designed to protect human life and control the emergency as rapidly as possible. All steps should be considered; however, timing of these steps may be altered to the individual circumstances to best accomplish these objectives. Secondary Action The Production Supervisor and/or their designee will notify the Asset Team leader and appropriate government agencies • Analyze the type of fire; call the local Fire Department(s) or 911 as appropriate for your area. If the fire is not beyond incipient stage, attempt to extinguish fire using • appropriate equipment and methods, if trained to do so. If the fire is beyond incipient stage, evacuate and secure the area until fire department arrives. • If fire suppression is not achieved within a reasonable period of time, call a conference with the Chief Fire Officer, Supervisor, Asset Team leader, service companies, and other Marathon personnel who may be present, and consider alternate methods to control the blaze. Make sure that fire department(s) has adequate directions to the facility. Inform the fire fighters if sour gas is present. • Shut off all feeder lines into the facility/ installation. I ■ Cut off all electrical power in area of fire. I■ Account for personnel who may have been in the area at the time. In the event of injury, call for medical and/or ambulance service. • Remove unauthorized personnel from the area and isolate area. Notify local law enforcement agency and request assistance, if necessary. • If liquid hydrocarbons or gas are in the storage tanks or gas plant, pump or flow from the affected installation when practical. If fluid being pumped is highly flammable, check temperature and remove hydrocarbons from installation as long as possible. ■ If condensate or produced water is flowing or spilling on the ground, call a service company to dig earthen pond at safe distance so that product can flow and collect in the pond. Make every reasonable effort to keep flowing product out of streams, draws and drainage ditches. Activate spill containment and cleanup procedures, if applicable. ■ Make arrangements for continuous water supply. ■ Maintain a safe working distance from fire at all times. ■ In the event the fire curtails sales or deliveries, the Asset Team leader, and/or his designee will notify the purchaser. • Secondary Action The Production Supervisor and/or their designee will notify the Asset Team leader and appropriate government agencies • Route all questions from the press or other sources concerning the situation to the Region's Public Affairs Officer and/or Incident Commander. • If fire suppression is not achieved within a reasonable period of time, call a conference with the Chief Fire Officer, Supervisor, Asset Team leader, service companies, and other Marathon personnel who may be present, and consider alternate methods to control the blaze. March 2013 © The Response Group Page 23 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.7 Fire / Explosion (Cont'd) Prefire Preparations Assign specific duties to the Field Operators, Field Technicians, Production Leaders, Production Supervisor and other personnel to execute in case of a fire. CERT Reporting Requirements A fire or explosion may result in an event that could trigger activation of Marathon's Corporate Emergency Response Plan. Refer to the CERT section of the Emergency Response Plan to make this determination. Regulatory Agencies to Be Notified If it is a Federal lease, the proper federal agencies (i.e. Bureau of Land Management) must be notified as well. If as a result of the fire any condensate or produced water enters into a watercourse, the National Response Center (NRC) will also have to be notified. The burning of any natural gas containing H2S may trigger reporting requirements under CERCLA/SARA Title 111 regulations. This determination can be made by consulting the CERCLA/SARA document or by contacting the HES Department. If there is an H2S Contingency Plan available for the area, consult it for additional guidance. March 2013 © The Response Group Page 24 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.7 Fire / Explosion (Cont'd) Pb@E.HCC C p®MTCM 19b@WWW Porgy@ o 2@CD0 0© 0 M_@y Determine the Type of Fire Report Emergency Cut off Additional Sources Account for Personnel Develop Further Arrangements Notifications 1 • If fire is not beyond incipient stage, attempt to extinguish the fire if trained to do so. 2 3 5 6 • Call 911 as appropriate for the area • Give adequate directions • Inform fire department if sour gas is present • Notify Production Superintendent • Shut off all feeder lines into the facility/installation • Cut off all electrical power in area of fire • If hydrocarbons are in storage flow away from affected area • Account for personnel who may have been in the area at the time • In the event of injury, call for medical service • Remove unauthorized personnel and isolate the area • Notify local law enforcement and request assistance if needed • Make arrangements for continuous water supply if needed • If hydrocarbons were spilt develop containment and clean-up plans • Refer to the Agency Notification section for reporting requirements and contact information March 2013 © The Response Group Page 25 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.8 Toxic/Flammable Gas Release Iligaiiiiiignin ■ When a gas release is noticed at any facility, secure the source if safe to do so. Account for all personnel in the unit or area where the release occurred. 1 ■ Evacuate all non-essential personnel from the Facility. 1 ■ Establish communications. ■ Rescue missing or injured personnel as required. ■ Control the flow of source, if able to identify and possible. I • • Person in Charge should call 911 for outside assistance. ■ Conduct air monitoring to ensure safety of personnel and appropriate PPE is required to respond. • Disconnect the entire electrical system, if possible ■ Evacuate nearby residents if required. ■ March 2013 © The Response Group Page 26 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions H@OE.H@@ 2.2 Response Actions (Cont'd) Figure 2.7 — Gas Release Emergency Flowchart ©y© 191b@CYMT RTAM PlICM@M'A Assess Severity Protect Yourself and Others in the Area Reassess the Situation Assess Severity 1 2 4 • If you can do so safely, stop the leak and notify your supervisor • Evacuate yourself and others to a safe location • Eliminate potential ignition sources • Notify supervisor of the situation • If it is now safe for onsite personnel to initiate actions to control the incident and fuel source then do so • If it is not safe to take action, remain in a safe location and wait for external response • Refer to the Agency Notification section for reporting requirements and contact information March 2013 © The Response Group Page 27 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions I 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide 2.2.9.1 Pipeline Incidents A pipeline incident exists when third -party damage, corrosion, material defects, worker error or natural events cause a fire, explosion, accidental release, or operational failure that disrupts normal operating conditions. Pipeline incidents present some of the most dangerous situations an emergency responder may encounter. Pipelines contain flammable, hazardous and even deadly petroleum gases, liquids, and other chemical products that present emergency responders with a myriad of hazards and risks that vary depending on the topography, weather, and properties of the material involved. For the majority of pipeline incidents, you will have a limited number of options to actually stop the leak. In almost all cases, the pipeline operator will be required to resolve the incident safely. Consequently, your goal is to minimize the level of risk to other responders, the community and the environment. Advance knowledge of where pipelines are located in your community and operations area, the products transported in them, and how to contact and work together with the pipeline operator in the event of an incident are key factors to an effective and safe response. Each pipeline operator maintains an emergency response plan that outlines the roles and responsibilities of company, contractor, and local response personnel. To effectively respond to a pipeline leak, spill or fire, emergency responders need to understand the hazards and risks associated with the incident. You should seek additional information about the pipeline in question as soon as possible. Calling the 24-hour emergency phone number on a nearby pipeline marker sign, contacting the appropriate emergency response agency, and consulting the information in the DOT Emergency Response Guidebook or Emergency Response Plan may provide more detailed, situation -specific information. Regardless of the nature of the pipeline incident, following standardized procedures will bring consistency to the response operation and will help minimize the risk of exposure to all responders. Pipeline operators hope you never have to respond to a pipeline incident, but if you do, remember: ■ Every incident is different — each will have special problems and concerns. Carefully select actions to protect people, property and the environment. I■ Continue to gather information and monitor the situation until the threat is removed. ■ March 2013 © The Response Group Page 28 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps Following standardized procedures will bring consistency to each response operation and will help minimize the risk of exposure to all responders. The information in this guide provides a framework to discuss safety issues as they relate to the hazards and risks presented by pipeline emergencies in your community. Assess the Situation Approach with Caution from Upwind Location To protect yourself and other responders from any hazards associated with the incident it is critical you approach cautiously from an upwind and/or crosswind location. ituation Asses a - . Do not park over manholes or storm drains. ■ Do not approach the scene with vehicles or mechanized equipment until the isolation zones have been established. Vehicle engines are a potential ignition source. Do not walk or drive into a vapor cloud or puddle of liquid. I ■ Use appropriate air -monitoring equipment to establish the extent of vapor travel. ■ Because any number of fire and health hazards may be involved, it is important you resist the urge to rush in until you know more about the product and hazards involved in the incident. ■ Consider the following: • Is there a fire, spill or leak? • What are the weather conditions? • What direction is the wind blowing? • What is the terrain like? • Who and what is at risk: People, Property or Environment? • Is there a vapor cloud? • What actions should be taken: evacuation or diking? • What human/equipment resources are required and readily available? • What can be done immediately? • March 2013 © The Response Group Page 29 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Assess the Situation (Cont'd) Secure the Scene Without entering the immediate hazard area, you want to isolate the area and deny entry to unauthorized persons including other responders. It may be necessary to evacuate everyone in the danger area to a safe location upwind of the incident area. Employ and Activate the Incident Command System Developed by the Department of Homeland Security, the National Incident Management System (NIMS) integrates effective practices in emergency preparedness and response into a comprehensive national framework for incident management. The ICS enables responders at all jurisdictional levels and across all disciplines to work together - effectively and efficiently. Because pipeline incidents require coordination of information and resources among all responders, the Incident Command System (ICS) is one of the most important 'best practices' in the NIMS. The ICS provides common terminology, organizational structure and duties, and operational procedures among operator personnel and various federal, state and local regulatory and response agencies that may be involved in response operations. Identify an Incident Commander. The Incident Commander is the person responsible for the management of on -scene emergency response operations. In cooperation with the pipeline operator's person in charge, the Incident Commander determines when it is safe for the response teams to enter the area and access the pipeline. The Incident Commander must be trained to perform these responsibilities and not be automatically authorized by virtue of his/her normal position within the organization. Establish a secured command post, lines of communication and a staging area for additional responding equipment and personnel. NOTE: If other public safety units are on -scene, ensure operations are coordinated and unified command is established. March 2013 © The Response Group Page 30 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Assess the Situation (Cont'd) Identify the Hazards A product's physical and chemical properties determine how the product will behave and how it can cause harm. Emergency responders need to analyze the problem and assess potential outcomes based on the hazardous materials involved, type of container and its integrity, and the environment where the incident has occurred. Understanding the hazards will enable you to understand what risk you will be taking and how to select the best course of action with the least risk. Request the MSDS for the product or material. • • 1 Mona ctions Locate a pipeline marker sign to identify the pipeline product, operator and 24-hour emergency phone number. Flammable atmospheres 1 ■ Call the emergency phone number to report the incident to the pipeline operator's control center. Control center personnel may provide additional information about the pipeline product and its hazards. Hydrogen sulfide (H2S) in pipelines I ■ ❑ Oxygen deficient/enriched atmospheres 1 • • Mona ctions Locate a pipeline marker sign to identify the pipeline product, operator and 24-hour emergency phone number. • Call the emergency phone number to report the incident to the pipeline operator's control center. Control center personnel may provide additional information about the pipeline product and its hazards. ■ Use the DOT Emergency Response Guidebook or Material Safety Data Sheet to initially analyze the key properties (flash point, explosive range, specific gravity, and vapor density). ■ Use air -monitoring equipment appropriate to the materials in the pipeline. Do NOT assume gases or vapors are harmless because of a lack of smell or quick desensitization to the strong odors of materials such as hydrogen sulfide. ■ Use the highest level of precaution and protection until you know the area is safe of flammable, toxic, mechanized and electrical hazards. • NOTE: If natural gas is escaping inside a building, refer to Section 2.2.6.5 of this plan for additional precautions. March 2013 © The Response Group Page 31 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Respond to Protect People, Property and the Environment Protective actions are those steps taken to preserve the health and safety of emergency responders and the public during a pipeline incident. While the pipeline operator concentrates on the pipeline, responders should concentrate on isolating and removing ignition sources and moving the public out of harm's way. Several response procedures can and should be pursued simultaneously. You will also need to continually reassess and modify your response accordingly. Establish Isolation Zones and Set Up Barricades Isolation zones and barricades prevent unauthorized people and unprotected emergency responders from entering the hazard area and becoming injured. The size of the containment area will be dictated by the location and size of the release. You also want to consider atmospheric conditions, as isolation distances change from daytime to nighttime due to different mixing and dispersion conditions in the air. Remember, gas odor or the lack of gas odor is not a sufficient measurement to establish safe isolation zones. Additional Actions Based on the type of incident, use any or all of the following to calculate and establish isolation zones: • DOT Emergency Response Guidebook or Product MSDS • Information from the pipeline operator's representative • Heat intensity levels • Measurements from air -monitoring equipment Use visible landmarks, barricade tape and traffic cones to identify hot/warm/cold zones. • Define entry and exit routes. Plan an escape route in case conditions deteriorate. ■ Be certain to allow enough room to move and remove your own equipment. The more time, distance and shielding between you and the material the lower the risk. March 2013 © The Response Group Page 32 1 Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Respond to Protect People, Property and the Environment (Cont'd) Rescue and Evacuate People Any efforts made to rescue persons and protect property or the environment must be weighed against the possibility that you could become part of the problem. Additional Actions • Do not walk or drive into a vapor cloud or puddle of liquid. • Evacuate or shelter -in-place as necessary, providing instruction and frequent updates to the public while evacuated or sheltered -in-place. ❑ Administer first aid and medical treatment, as needed. • Enter the area only when wearing appropriate protective gear, such as Structural Fire Fighters' Protective Clothing (SFPC) (helmet, coat, pants, boots, gloves and hood) and a Positive Pressure Self -Contained Breathing Apparatus (SCBA). Because no single protective clothing material will protect you from all dangerous pipeline materials, always use the highest level of caution. Refer to product MSDS for specific PPE requirements. Eliminate Ignition Sources Ignition sources include electrical motors, firearms, vehicles, telephones, emergency radios, cigarettes, construction equipment, static electricity, open flames or sparks. Ad !bona ci I Eliminate ignition sources, if possible without additional exposure or great risk. • Park all emergency vehicles at a safe distance beyond the isolation zone (upwind). I • Do NOT light a match, start an engine, use a telephone or radio, switch lights on or• off, or use anything that may create a spark. March 2013 © The Response Group Page 33 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Respond to Protect People, Property and the Environment (Cont'd) Control Fires, Vapor and Leaks Because there are many variables to consider, the decision to use water on fires or spills involving water -reactive materials should be based on information from an authoritative source, such as the pipeline operator, who can be contacted by calling the 24-hour emergency phone number listed on a nearby pipeline marker sign. WARNING: Some products can react violently or even explosively with water. Water getting inside a ruptured or leaking container may cause an explosion or the product's reaction with water may be more toxic, corrosive, or otherwise more undesirable than the product of a fire without water applied. Consequently, it is best to leave a fire or leak alone except to prevent its spreading. Fire Control Extinguishing a primary fire can result in explosive re -ignition. Unless it is necessary to save human life, flammable gas fires should NOT be extinguished on flammable gas pipelines unless the fuel source has been isolated and the pipeline operator advises you to take this action! If the fuel source is not shut off and the fire is extinguished, leaking gas can migrate away from the pipeline and find an ignition source. Additional Actions • Let the primary fire burn. Eliminate potential ignition sources. • Cool surrounding structures, equipment and vessels. Because water is an inefficient and even dangerous way to fight fuel fires, use a fog pattern, NOT a straight stream of water. Please note some products are not compatible with water; refer to the DOT Emergency Response Guidebook or MSDS sheet. Do not inhale fumes, smoke or vapors. ■ Once the primary fire is out, beware of hot spot re -ignition. • Do not operate pipeline equipment. • March 2013 © The Response Group Page 34 Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Respond to Protect People, Property and the Environment (Cont'd) Control Fires, Vapor and Leaks Vapor Control Limiting the amount of vapor released from a pool of flammable or corrosive liquids requires the use of proper protective clothing, specialized equipment, appropriate chemical agents, and skilled personnel. For these reasons, it is best to contain the hazards and wait for the pipeline operator's representative to handle the pipeline and its product. Additi• .c_'• Do not inhale fumes, smoke or vapors. ■ Eliminate ignition sources! Flammable gases may escape under pressure from a pipeline, form a vapor cloud, and be ignited by an ignition source in the area. Explosions of unconfined vapor clouds can cause major structural damage and quickly escalate the emergency beyond responder capabilities. • Do NOT ignite a vapor cloud! Pipeline operators will perform this dangerous task if approved through the Unified Command. • Avoid forced ventilation of structures and excavations. Forced ventilation can actually increase the possibility of a flammable atmosphere. • Limited fog misting can be of some benefit if knocking down a vapor cloud, especially if such a cloud appears to be spreading beyond the containment site. Fog misting must be used carefully to prevent incompatible product/water mixing or the spread of product to other areas, as containment dikes may become overfilled. Product -compatible foam can be used to suppress vapors or for rescue situations, however, be extremely cautious if fuel discharge is not yet stopped. • CAUTION: Before using water spray or foam to control vapor emissions or suppress ignition, obtain technical advice based on chemical name identification. Refer to the pipeline operator's product MSDS and DOT Emergency Response Guidebook. March 2013 © The Response Group Page 35 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Respond to Protect People, Property and the Environment (Cont'd) Control Fires, Vapor and Leaks Leak Control In addition to hazards such as flammability, toxicity and oxygen deficiency, liquid pipeline leaks and ruptures can create major problems with spill confinement and containment. What seems like a minor spill may evolve into a major spill as liquid inside the pipeline continues to bleed out of the line. Even after line shut in the pipeline will continue to release material until the line has depressurized. Work with the pipeline operator to identify a way to depressurize the pipeline away from the response site. Additional Actions ■ Ask yourself where the spill will be in a few hours, how close the incident is to exposures or sensitive areas, and what can be done to confine the spill or divert it away from exposures. Establish barriers to prevent the leak from spreading to water sources, storm drains or other sensitive areas. There are several basic containment devices that can be used to prevent the migration of petroleum products on land or on small streams, such as: • Storm sewer or manhole dam • Small stream containment boom • Pipe skimming underflow dam • Wire fence or straw filter dam • If a leak is accidentally ignited, firefighting should focus on limiting the spread of fire damage, but in NO circumstances should efforts be made to extinguish the fire until the source of supply has been cut off or controlled. ■ Do not walk into or touch spilled material. ■ Do not operate pipeline equipment. ■ March 2013 © The Response Group Page 36 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Call for Assistance of Trained Personnel Contact Your Organization As soon as possible, contact your organization. This will set in motion a series of events ranging from dispatching additional trained personnel to the scene to activating the local emergency response plan. Ensure that other local emergency response departments have been notified. Cal the Pipeline Operator if not Operated by Marathon Immediately call the 24-hour emergency phone number of the pipeline operator, which is listed on a marker sign located at a nearby road crossing, railroad or other point along the pipeline right-of-way. During the call, pipeline control center personnel will dispatch a representative to the scene. The control center will immediately act to shutdown the pipeline and isolate the emergency. The pipeline control center may also have the capability to remotely open and close manifold valves and to transfer products both to and from the main pipeline at marketing and distribution facilities. Be prepared toprovide pipeline control center personnel with the following n#o -mation a I❑ Call-back number, contact name (usually the Incident Commander) Detailed location, including state, county, town, street or road Type of emergency: fire, leak, vapor When incident was reported locally Any known injuries Other officials on site: police, fire, medical, LEPCs, etc. 11 1 1 1 1 ❑ Surrounding exposures/sensitive areas Any special conditions: nearby school, hospital, prison, railroad, etc. 1 ■ Local conditions: weather, terrain Obtain National Assistance If the pipeline operator's 24-hour emergency phone number is not available, contact the appropriate emergency response agency listed in the DOT Emergency Response Guidebook, operators' product MSDS and Emergency Response Plan. March 2013 © The Response Group Page 37 Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.2 Incident Response Steps (Cont'd) Work Together with the Pipeline Operator Pipeline operator personnel will establish product containment and drain barriers while working in concert with local emergency responders to limit or contain the spill, and avoid possible ignition of a leak or vapor cloud. Pipelirte Operator's 'e '.resertetiv Serves as the primary contact for communication between the operator's team and emergency responders. They will be familiar with the Incident Command System and are normally HAZWOPER certified as well. • I■ Determine whether the zone of influence needs additional barricading and diking. Establishes contact with the Incident Commander before and upon arrival to avoid accidental entry into isolation zones or ignition of the release. • Provide standby rescue personnel to pipeline operator personnel entering the incident area to stop the release. Coordinate any search and rescue operations. Communicates which actions to take especially as they relate to containment and control of the pipeline product. The pipeline operator's representative(s) is trained to know: • How to shut off the supply of gas or liquid. Only the operator's representative is trained to operate pipeline equipment. • What potential hazards may be present at the location. • What additional complications may result from response activities as they relate to the pipeline and its product. • How to fight small fires with hand held extinguishers, administer basic first aid, perform CPR, and assist with evacuations or traffic control. • Help maintain containment dams and install more as needed. Together, • Maintain site control and act as Incident Commander in coordination with pipeline operator. Eliminate ignition sources. Provide standby fire -watch personnel. 1 I■ Determine whether the zone of influence needs additional barricading and diking. Suppress vapor generation. • Provide standby rescue personnel to pipeline operator personnel entering the incident area to stop the release. Coordinate any search and rescue operations. • Help maintain containment dams and install more as needed. • Monitor the atmosphere in the repair and containment areas. • Together, • nci ent omman er andPipeline perator s epresentative: Review whether it is safe for the operator's emergency response team and/or their equipment to enter the incident area. • Determine whether the zone of influence needs additional barricading and diking. • Decide when the area is safe for the affected public to re-enter. March 2013 © The Response Group Page 38 Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.3 Damage Reporting Report any damage or unusual and suspicious activities along a pipeline right-of- way to the pipeline operator. The operator will immediately investigate and repair any damage. Improved communication and cooperation with local organizations are key components to protecting life, enhancing public safety, improving emergency preparedness, increasing protection of the environment, and preventing damage to pipeline property and facilities. March 2013 © The Response Group Page 39 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.4 Recommended Minimum Evacuation Distances for Natural Gas Pipeline Leaks and Ruptures Pipeline Size (inches) 4 6 8 10 12 16 20 22 Pressure (psog) 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 24 30 36 42 91 137 182 228 274 365 456 502 547 684 821 958 129 193 258 322 387 516 645 709 774 967 1161 1354 158 237 316 395 474 632 790 869 948 1185 1422 1659 182 274 365 456 547 730 912 1003 1094 1368 1642 1915 204 306 408 510 612 816 1020 1122 1224 1529 1835 2141 223 335 447 558 670 894 1117 1229 1340 1675 2011 2346 241 362 483 603 724 965 1206 1327 1448 1810 2172 2534 258 387 516 645 774 1032 1290 1419 1548 1935 2322 2709 274 410 547 684 821 1094 1368 1505 1642 2052 2462 2873 288 433 577 721 865 1154 1442 1586 1730 2163 2596 3028 302 454 605 756 907 1210 1512 1664 1815 2269 2722 3176 316 474 632 790 948 1264 1580 1738 1896 2369 2843 3317 329 493 658 822 986 1315 1644 1809 1973 2466 2959 3453 341 512 682 853 1024 1365 1706 1877 2047 2559 3071 3583 353 530 706 883 1060 1413 1766 1943 2119 2649 3179 3709 365 547 730 912 1094 1459 1824 2006 2189 2736 3283 3830 376 564 752 940 1128 1504 1880 2068 2256 2820 3384 3948 387 580 774 967 1161 1548 1935 2128 2322 2902 3482 4063 398 596 795 994 1193 1590 1988 2186 2385 2981 3578 4174 408 612 816 1020 1224 1631 2039 2243 2447 3059 3671 4283 418 627 836 1045 1254 1672 2090 2299 2508 3134 3761 4388 428 642 856 1069 1283 1711 2139 2353 2567 3208 3850 4492 *Not applicable for Butane, Propane or other Hazardous Liquids The applicable leak or rupture condition is that of a sustained trench fire fueled by non -toxic natural gas escaping from two full bore pipe ends. Blast overpressure is not addressed. The distances shown in Table 1 are intended to provide protection from burn injury and correspond to a thermal heat flux exposure level of 450 Btu/hr ft2. This is the accepted limit of heat exposure for unprotected outdoor areas where people congregate; as established by the US Department of Housing & Urban Development Code 24CFR51, Subpart C, Siting of HUD Assisted Projects Near Hazardous Operations Handling Conventional Fuels or Chemicals of an Explosive or Flammable Nature. The formula used to calculate distance was taken from the Gas Research Institute Report GRI -00/0189, A Model for Sizing High Consequence Areas Associated with Natural Gas Pipelines, 2001, prepared by C-FER Technologies. That model does not take into account wind or other factors which may greatly influence specific conditions. Users are advised that the distances shown in Table 1 are considered to be "general information" only and are not intended to replace a site specific risk analysis. The Pipeline Association for Public Awareness makes no warranty with respect to the usefulness of this information and assumes no liability for any and all damages resulting from its use. Anyone using this information does so at their own risk. March 2013 © The Response Group Page 40 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.5 Natural Gas Escaping Inside a Building otetial ards Fire or Explosion EXTREMELY FLAMMABLE I ■ Establish an effective and safe perimeter. Will be easily ignited by heat, sparks or flames. I ■ Position apparatus out of danger zone (avoid front of building and over manhole covers and sewers). Keep unauthorized personnel away. Will form explosive mixtures with air. ■ ❑ Vapors from liquefied gas are initially heavier than air and spread along ground. CAUTION: Natural Gas / Methane (UN1971) is lighter than air and will rise. Natural Gas / Methane (UN1971) fires are difficult to detect since they burn with an invisible flame. Use an alternate method of detection (thermal camera, broom, etc.) • Evacuate the public to a safe distance Vapors may travel to source of ignition and flash back. ■ As soon as possible, contact the gas operator and coordinate large scale evacuations with trained emergency responders. • DOT ERG states 150-300 feet initially. Note: Area will depend on the material involved • Pipeline operators, however, upon assessment at arrival may recommend a greater evacuation distance. Cylinders exposed to fire may vent and release flammable gas through pressure relief devices. • Containers may explode when heated. I ■ Ruptured cylinders may rocket. I ■ Health Vapors may cause dizziness or asphyxiation without warning. I ■ Some may be irritating if inhaled at high concentrations. I ■ Contact with gas or liquefied gas may cause burns, severe injury and/or frostbite. ■ Fire may produce irritating and/or toxic gases. I ■ March 2013 © The Response Group Page 41 Approach cautiously. ■ Establish an effective and safe perimeter. ■ Position apparatus out of danger zone (avoid front of building and over manhole covers and sewers). Keep unauthorized personnel away. • Secure the scene and deny entry. ■ Evacuation Evacuate the public to a safe distance ■ As soon as possible, contact the gas operator and coordinate large scale evacuations with trained emergency responders. • DOT ERG states 150-300 feet initially. Note: Area will depend on the material involved • Pipeline operators, however, upon assessment at arrival may recommend a greater evacuation distance. • March 2013 © The Response Group Page 41 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.5 Natural Gas Escaping Inside a Building (Cont'd) Emergency Response Wear positive pressure self-contained breathing apparatus (SCBA) as well as full structural firefighter protective clothing. • Structural firefighters' protective clothing will only provide limited thermal protection Listen for hissing sound, but use CAUTION as no noise may be heard. • Monitor the atmosphere, using multiple monitors where possible • Action Criteria: 0 to 10% of the LEL - Use Extreme Caution • Action Criteria: 10% of the LEL or greater - DO NOT ENTER THE BUILDING • If possible, determine the source of the release without risk to the responders. Multiple locations are possible due to damage or pullout at joints. • Monitor for natural gas traveling away from source toward exposures. • Control ignition sources (smoking, open flames, internal combustion engines and motors). Do not operate electric devices such as switches, etc. Sparks can cause ignition. • Be cautious of contacting the piping system; a static spark may occur and result in ignition. • Whenever possible, adopt a defensive or non-intervention mode and wait for the utility company to arrive. • ❑ Protect exposures from the radiant heat of the fire. Never extinguish the fire until the leak can be shut off and controlled, unless there is immediate danger to life. • With any leak, always anticipate and expect that ignition will occur. • March 2013 © The Response Group Page 42 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.5 Natural Gas Escaping Inside a Building (Cont'd) Tactical Considerations • Natural gas released inside buildings presents one of the greatest flammable hazards to emergency responders. Building full of natural gas should only be approached when needed with extreme caution and with a minimum number of personnel. Air Monitor readings in excess of 10% LEL require evacuation of the building. ■ Stop or control the gas release at the appliance, or service meter valve. ■ If possible to do safely, ventilate the area. If the flammable atmosphere is above the upper explosive limit (UEL), keep in mind that during ventilation the atmosphere will pass back through the flammable range of 4% to 16% gas to air. Also, remember that fans are a potential ignition source. • Natural gas, depending on the makeup, requires a minimum mixture of 4% to 16% in air to ignite (40,000 ppm. to 160,000 ppm) • NOTE: Odor can be detected as low as 1 ppm. However, if underground migration occurs, odorant may be stripped from the gas. Not all gas has odor added ■ NORMALLY, DO NOT EXTINGUISH A LEAKING GAS FIRE UNLESS LEAK CAN BE STOPPED. Extinguish surrounding fires, but not gas fed fire. • Use protective hose streams to approach if necessary. ■ DO NOT CLOSE main valves or any other large transmission or distribution vales. This can lead to serious problems elsewhere in the system; pipeline operator will operate appropriate valves to isolate the system. • Closed valves should remain closed until opened by pipeline operations personnel. Apply correct lock out tag out procedures. ■ March 2013 © The Response Group Page 43 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.9 Gas Pipeline Response Guide (Cont'd) 2.2.9.5 Natural Gas Escaping Inside a Building (Cont'd) st Aid 1 Move victim to fresh air. ■ Call 911 or emergency medical service. • • Assess the victim to determine if he/she is breathing normally. The level of treatment provided should be based on your level of individual training. • Professional Rescuers will provide artificial respirations if the victim is in respiratory distress. Non -Professional Rescuers begin CPR (if correctly trained and certified) if the victim is not breathing normally • Administer oxygen if breathing is difficult. • ■ Remove and isolate contaminated clothing and shoes. ■ In case of burns, immediately cool affected skin for as long as possible with cold water. Do not remove clothing if adhering to skin. • Keep victim warm and quiet. ■ Ensure that medical personnel are aware of the material(s) involved and take precautions to protect themselves. • Other Considerations 1 Decontaminate if necessary to remove the odorant and materials prior to treatment• and transport. Debrief all responders and schedule a critique with all involved. ■ Document and save all information, notes and communications. 1 ■ March 2013 © The Response Group Page 44 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.10 Air Monitoring Figure 2.8 — Air Monitoring Decision Flowchart Get a list of the chemicals of concern for the incident Has modeling been done by Env. to determine air emission plumes? NO Obtain site map, develop & plot sampling locations for Level II Team 2 Obtain MSDS and review components of chemical(s) YES 1 Determine potential health effects of chemical(s) Document on Level II Team IH Form & Site Safety Plan and indicate the PPE required Obtain site map, and use modeling as a guide to plot sampling locations on map for Level II Team. YES Do significant health effects exist? NO Document on Level II Team IH Form & Site Safety Plan and indicate no PPE required March 2013 © The Response Group Page 45 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.10 Air Monitoring (Cont'd) Figure 2.8 — Air Monitoring Decision Flowchart (Cont'd) Determine the number of people required to accomplish air monitoring. Identify what type(s) of equipment needed for monitoring & document on Level II IH Form 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. Fax/Email Level II IH Form & Plotted site plan to response .......) site. NO Are people & equipment available within area to accomplish monitoring? .00) YES 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. March 2013 © The Response Group Page 46 Ii''t`►./1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.10 Air Monitoring (Cont'd) IH AIR Monitoring Information Form for Level II Team Product(s) Of Concern Product Component(s) of Concern Probable Exposure Health Effects of Product PPE Required Number of People Required to Monitor (including Names & Organization) March 2013 © The Response Group Page 47 Ii''t`►./1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.10 Air Monitoring (Cont'd) IH AIR Monitoring Information Form for Level II Team (Cont'd) Equipment Needed To Monitor (including where equipment is coming from) Monitoring Locations See site plan with marked monitoring locations. Monitoring Results Action Plan March 2013 © The Response Group Page 48 Ii''t`►./1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.10 Air Monitoring (Cont'd) Level II Response Air Monitoring Log Sampler Name: Date: Facility Name: Monitoring For: Equipment Used (Circle all equipment used): Direct Reading Detector Tubes Other For Direct Reading Equip: For Detector Tubes: For Other Mfg & Model: Mfg: Describe Monitoring Equipment: Serial No.: Tube Type: Calibration Date: Tube Range: Monitoring Results Location Time (include am or pm) Reading (include units) March 2013 © The Response Group Page 49 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.11 Well Control/Drilling/Completions Emergency Measures The on-site Drilling Supervisor/Engineer is responsible for immediate actions to be taken at the well site. As soon as possible, he should notify the Drilling/Completions Superintendent to request assistance in calling out the necessary support services. The Drilling/Completions Superintendent will also be responsible for activating Marathon's Incident Command System, notifying NAPO Asset Team Production Supervisor and ensuring that applicable regulatory agency notifications are made. In the case of the loss of well control, spill or release at an oil or gas well, action should be designed to protect human life and control the disaster as rapidly as possible. All steps should be considered; however, the timing of these steps should be altered to fit individual circumstances. We ontrol Checklist If a rig is on location, shut down all engines and evacuate all personnel to a safe distance. Account for all personnel. • Move all vehicles out of the immediate area and clear location of all other equipment that can be safely moved provided there is no danger of explosion. • Call out needed firefighting equipment as available. ■ Alert medical and ambulance services, and call out what is deemed necessary. ■ Notify the nearest law enforcement agency; request their assistance to seal off the area from sightseers. • If loss of well control does occur within a populated area, immediately dispatch the necessary personnel to evacuate the area with the help of local law enforcement personnel. ■ Make arrangements to obtain a continuous water supply. ■ If the well is blowing out liquid formation fluids, call out the equipment and personnel necessary to construct barriers to contain these fluids. • Notify the D&C Superintendent, or highest level of operations supervision, which can be contacted. Request they notify the NAPO Asset Team Management, Government Agencies, well control specialists, CERT, other working interest owners, the landowner and the contractor's management. • Order the necessary safety equipment, such as air tanks and masks in case of sour gas, brass tools, etc. I • Order the necessary mud materials, and mixing and pumping equipment. ■ Lay kill lines from a safe location to the well. I ■ Mix mud if required to kill well. ■ Cooperate with the professional well control specialists to secure all necessary special tools and services as rapidly as possible. • Once the well is brought under control, install the appropriate wellhead equipment and/or plug the well with cement after securing permission from the appropriate responsible company management and regulatory agencies. ■ March 2013 © The Response Group Page 50 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.11 Well Control/Drilling/Completions Emergency Measures (Cont'd) Preliminary Precautions All on-site drilling/completions supervisors/engineers should have updated kill sheets prepared on a location during the drilling of the well. All BOP equipment should be tested on a regular basis to insure that they are operable. H2S monitors and personal protective equipment (SCBA's, air lines etc) shall be on location prior to drilling into any formation known or suspected to contain H2S. Rig personnel shall be trained in the use and operation of this equipment. If an H2S Contingency Plan is available for this particular field or area, consult it for additional guidance. CERT Reporting Requirements A loss of well control, spill or release may result in certain events that could cause Marathon's Corporate Emergency Response Plan to be activated. Refer to the CERT section of the Emergency Response Plan to make this report. Regulatory Agencies to Be Notified The appropriate state regulatory agencies to be contacted are listed in Section 2.2.1 of this plan. In addition to these agencies, if any fluid enters into a watercourse, the National Response Center (NRC) will also have to be notified. Telephone numbers for all of these agencies are listed under the section entitled, "Government Agencies." The release of H2S gas during a loss of well control may trigger additional reporting requirements under the CERCLA/SARA Title III regulations. This determination can be made by reviewing the CERCLA/SARA document or by contacting the Health, Environment, and Safety Department. Area Specific SPCC plan For additional drilling and completions spill prevention countermeasures and control information, refer to MOC Area Specific SPCC Plan. March 2013 © The Response Group Page 51 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) Figure 2.9 — Well Control/Drilling/Completions Emergency Flowchart D&C Superintendent Activating Marathon's Incident Command System/Notifying NAPO Production Supervisor Ensure applicable regulatory agency notifications are made. Call out needed firefighting equipment and other resources as available and necessary. Secure all necessary special tools and services as rapidly as possible. Yes 1 Lay kill lines from a safe location to the well. Mix mud if required to kill well. Well Emergency D&C Supervisor / Engineer contacts the D&C Superintendent Shut down al engines and evacuate all personnel to a safe distance 1 Account for all personnel. Take Actions to Protect Yourself and Others • Move all vehicles out of the immediate area and clear location of all other equipment that can be safely moved provided there is no danger of explosion. 1 Is it Safe for On Site Personnel to Initiate Actions to Control Incident and Potential Fuel Sources? No 1 Remain in Safe Location Maintain Security of Area Await External Response March 2013 © The Response Group Page 52 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Respons Actions 2.2 Response Actions (Cont'd) 2.2.11 Well Control/Drilling/Completions Emergency Measures (Cont'd) Equipment Shut Down Evacuation Move Equipment CaII in support Make Future Arrangements Gain Control of Well Notifications Ph@gH@@ ©@@i iTaCDM, CMighgl 1 • If a rig is on location, shut down all engines 3 • Evacuate all personnel to a safe distance • Account for all personnel who were in the area at the time • Move all vehicles out of the immediate area • Clear all other equipment that can be safely moved provided there is no danger of explosion 6 • Call for needed firefighting equipment • Alert medical and ambulance services as deemed necessary • Notify law enforcement agencies to assist with securing the area and aiding any evacuations as needed • Notify NAPO Production Supervisor • Make arrangements for continuous water supply if needed • Develop containment and clean-up plans • Order necessary safety equipment • Order mud materials and mixing equipment • Lay kill lines from a safe location • Mix mud if required • Cooperate with professional well control specialists • Once controlled, install appropriate wellhead equipment 7 • Refer to the Agency Notifications section for reporting requirements and contact information March 2013 © The Response Group --•— Page 53 Incident Occurs Injury / Near Miss / Spill / Vehicle / Other • CLand or Offshore Call: MOCcert 866-662-2378 WWD/C Incident Reporting Flowchart Major or Minor Incident? Minor ► Major ► Call your Superintendent and HES Professional for verification that a further investigation is necessary within 24 hours • If NO If YES • If YES 1 Management will sign MOCcert report HES Tech will file incident as CLOSED Fill out the WWD&C Incident Report Form with draft corrective actions within 24 hours •C Injury? Call Axiom (877) 502-9466 for case management assistance • Complete 1st' 2nd & 4th pages of the WWD&C Incident Report ONLY If If NO 1 Cnvironmental? ) Complete the 1st and 4th pages of the WWD&C Incident Report ONLY CWitnesses? ) YES 1 iI Have Witnesses Complete and Sign Witness Statement Form If YES Complete 1st' 3'd & 4th pages of the WWD&C Incident Report ONLY If NO Email the report to your Superintendent and HES Professional • Email all incident related documentation to HES Professional for processing WWD&C Supt. and HES will review the corrective actions for vPSI compliance and approve • Approved Incident Report is sent to the HES Tech for management to approve and enter into SIMS Post a copy of ONLY the corrective actions ► at site and DESTROY/ DELETE other copies of Incident Report HES Tech generates a Corrective Actions follow- up email from SIMS Responsible Person for Corrective Action receives email and replies with the closure date of the Corrective Action HES Tech enters closure date into SIMS and incident is CLOSED indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Respons Actions 2.2 Response Actions (Cont'd) 2.2.12 Severe Weather All actions should be designed to protect human life and safeguard against the disaster. All steps listed should be considered; however, timing of these steps may be altered to fit the individual circumstances. Tornadoes are a real threat in the Piceance Operations Area. It is difficult to prepare in advance for a tornado since its frequency, location and direction is unpredictable. When an area is threatened, protection of the employee is the primary concern. When sufficient notice is available, take whatever steps possible to minimize property damage such as: 1=1 • Store and/or secure all drums, buckets, signs and other small objects which might blow away. • Remove equipment easily moved from low areas easily, which might be damaged by flooding. • Board up windows, secure doors in buildings, and remove window type air condition units. • Evacuate unnecessar mobile equipment and personnel to a safe location. • If time permits, start filling tanks and thin-walled vessels with water, shut-in wells and associated facilities. March 2013 © The Response Group Page 55 Thunderstorms This thunderstorms, / Lightning / High Winds Checklist checklist identifies actions to be taken when the Facility is threatened by producing lightning or high winds. • Upon notification by weather monitoring of impending severe weather conditions, notify the Production Supervisor or the Field Office of the situation. Personnel will be instructed to shut down all nonessential activities and take shelter where available until the storm has passed. • Immediately bring personnel off vessels, tanks, pipe racks, and other elevated work areas. Suspend product loading operations and close all tank openings. • Take shelter until the storm has passed. March 2013 © The Response Group Page 55 I indY Marathon Oil` Piceance Operations mergency Response Plan 2.2 Response Actions (Cont'd) 2.2.12 Severe Weather (Cont'd) Section 2: Emergency Response Actions March 2013 © The Response Group Page 56 1 master ctivities - ost Make contact with CERT, local Civil Defense, law enforcement, Red Cross or other disaster agencies. • Make available to the community the equipment, materials, and manpower to restore essential services and to accomplish rescue work. Survey damage to Company properties and report to the Production Superintendent and/or Asset Team Manager. • 1 • If necessary, implement spill containment and cleanup activities. 1 ■ Make photographic record of damage to Company facilities for insurance purposes. 1 ■ Restore undamaged properties to production. Through Business Unit Management, establish procedures to be followed, with respect to possible insurance claims, in restoring damaged facilities to production. • • Prepare a complete report covering damage. March 2013 © The Response Group Page 56 /n r Marathon Oil` 6 Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.12 Severe Weather (Cont'd) Figure 2.10 — Tornado/Earthquake/Flood Emergency Flowchart TORNADOIEARTHQIJAKEIFLOOD EMERGENCY FLOWCHART tCRea FAR tHOUAKErFi°7p ACTIVATE INCIDENT ALARM NOTIFY PERSONNEL IN AREA YES SHUT iN FIELD ACCOUNT FOR ML PERSONNEL AND EVACUATE ALL NM -ESSENTIAL PERSONNEL YES NCS EVACUATE REMAINING PERSONNEL 4 RETURN TO F.ELO ASR TORNAO D EARTMOJ AK EFL O1DD TI -BEAT SUBSIDES • CONDUCT ATHOROUGH FACILrTY EAM INATION RESUME NORMAL OPERATIONS March 2013 © The Response Group Page 57 indY Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.12 Severe Weather (Cont'd) CERT Reporting Requirements A natural disaster may result in an event which could trigger the activation of Marathon's Corporate Emergency Response Plan. Refer to the CERT section of the Emergency Response plan to help make this determination. Regulatory Agencies to Be Notified If a natural disaster causes the release or spill of products, various state or Federal agencies may need to be contacted. Refer to the state and federal reporting sections of this plan to determine the reporting requirements or contact the HES Department. March 2013 © The Response Group Page 58 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.12 Severe Weather (Cont'd) Notify Other Personnel Shut in Facility if Required Account for Personnel Return to Field Notifications I@_@@ ©y@ MEI] Bhg@Tg, 2 3 4 5 • Activate warning system as required • Notify Production Supervisor • Shut-in field if conditions merit • Secure equipment and materials which might move during a disaster • Account for all personnel in the area • Evacuate all non-essential personnel • If the situation becomes life threatening, evacuate remaining personnel • Conduct a site evaluation and report status to the Production Supervisor and Asset Team Manager • Implement Spill containment and cleanup if required • Refer to the Agency Notification section for reporting requirements and contact information March 2013 © The Response Group Page 59 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions I 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency Medical Emergency Checklist The following checklist identifies key items to consider during a medical emergency at a company facility. ■ Stabilize the victim. Provide BASIC LIFE SUPPORT at the scene if necessary by: ■ ■ Maintain airway/breathing — administer CPR ■ ■ Control bleeding ■ Treat for shock • Activate professional medical care for the victim by: ■ Call :">“- to arrange for ground or air ambulance support. Provide the 911 dispatch the following information: ✓ Your name and location ✓ Type of medical emergency ✓ Name and location of the injured ✓ Condition of injured ✓ Contact phone number • ■ Contact drilling rig paramedic, if applicable. ■ Transport the victim to a local hospital or physician. Note: Evacuation of seriously ill or injured persons should be conducted by ground or air ambulance only. Transportation by company or private vehicle should be discouraged, unless advised to do so by medical authorities. All medical emergencies should be documented on appropriate company reports. In'ur / Illness Checklist The following checklist identifies key items to consider during a minor injury or illness occurring at a company facility: ■ Assess the situation and contact Field Office or Safety Department. Determine the level of medical attention needed - first aid or outside professional assistance. (Contact Axiom Case Management.) • ■ Administer first aid if necessary. Transport or activate professional medical care to provide medical support at local hospital or physician if necessary. • Note: Evacuation of seriously ill or injured persons should be conducted by ground or air ambulance only. Transportation by company or private vehicle should be discouraged, unless advised to do so by medical authorities. All medical emergencies should be documented on appropriate company reports. March 2013 © The Response Group Page 60 Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency (Cont'd) MARATHON OIL COMPANY - NAPO HES Procedure: INJURY CASE MANAGEMENT Document No. 006 Process No. SAF -011-P Effective case management provides for consistent, timely, and proper Overview medical diagnosis and treatment for work-related injuries and illnesses. Reporting This procedure will be followed for case management of all work-related injuries or illnesses (Marathon or contractor): Step Action 1 Work-related injury/illness is reported immediately to the supervisor or Marathon Person in Charge (PIC) / HES Representative. 2 If injury/illness is critical or life threatening, call 911. 3 Contact Axiom (877-502-9466) for all work-related injuries/illnesses regardless of the severity. Axiom Response Axiom will use the following procedure for all injuries/illnesses: Step Action 1 The Axiom Case Manager will call back within 5 minutes to discuss the incident and injury with the employee. 2 Axiom will assist in determining if the employee requires evaluation at a medical facility. If ... Then ... Medical Treatment Recommended Axiom will direct the employee to a medical facility and provide the initial information on the case to the health care provider. The employee's supervisor or designee should accompany the employee to the facility. Note: Final decisions on contractor medical treatment and locations of treatment remain with the contractor. Axiom representatives provide professional consultation /advice only. March 2013 © The Response Group Page 61 Marathon Oil` Piceance Operations mergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency (Cont'd) (continued) Step Action 2 If ... Then ... No Medical Treatment Recommended Axiom will provide telephonic treatment recommendations and monitor the employee's condition. 3 Axiom will speak with the examining physician before the employee leaves the medical facility. 4 Axiom will follow-up with the injured employee following the injury until their company's worker compensation case manager is assigned (typically within 72 hours following the incident). Case Contractor companies may apply for an exemption from the requirement Management to use Axiom for their case management. This exemption is subject to Exemption approval and Marathon retains the right to remove this exemption at any time if the company's case management procedures and/or services are deemed ineffective during testing, auditing, or as a result of an incident. The following are the minimum case management criteria necessary to apply for an exemption: • Case managers are available by phone 24 hours/day, 7 days/week, 365 days/year, • Case manager telephone response time is 10 minutes or less, • Case managers are registered nurses, physicians assistants, or board-certified physicians, • Case manager is licensed in all states where the contractor's work on behalf of Marathon is being performed, and • Case Managers are contacted for all work-related injuries/illnesses regardless of severity. A contractor company requesting an exemption from using Axiom should complete the Case Management Exemption form and submit it to the HES Department in Houston. References The following are references and other documentation that apply to this procedure: • Case Management Exemption Form March 2013 _ 0 The Response Group Page 62 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency (Cont'd) Figure 2.11 — Medical Emergency Flowchart Marathon Employee/Contractor is injured or becomes ill • Report injury or illness immediately to MOC supervision Complete "Authorization for Release of Medical Information" form if they seek medical attention V Obtain Work Related Incident Packet from MOC supervision • Action of MOC Supervision Work Area If able, complete Section I of Marathon's OI&I Form All Asset Areas (except Gulf of Mexico) Call (866) 662-2378 or (866) MOC CERT Business Unit (Contact Axiom (877-502-9466) for all work-related Insure employee receives adequate medical attention If OSHA recordable injury or illness at a wellsite in State of CO, notify COGCC within 24 hours Was there more than 3 or more employees hospitalized? • YES • Notify CERT. Notification must be made to OSHA within 8 hours • NO Continue with investigation reporting • Complete preliminary investigation and Supervisor's portion of OI&I Form Obtain Witness Summaries • Send Work Related Incident package with completed forms to HES&S Department within 24 March 2013 © The Response Group • Page 63 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency (Cont'd) Marathon Employee Injured or III Employee's Supervisor or PIC • If other than an emergency, contact MOC CERT (866-662- 2378) before the employee is taken for medical treatment. • For cases with medical treatment, instruct MOC CERT to contact Health Services (HS) to initiate proper case management between Ops, HS, and HES (as needed). • Ensure employee has a "Work Related Incident Packet." • If one or more employees are hospitalized or if there is a fatality, contact HES immediately. • Complete Section II of OI&I Form and return to HES within 3 calendar days of the incident. • Obtain Witness Summaries. • Complete additional incident investigation as needed. • Send "Release of Medical Information" and the "Physical Capacities Physician's Report" forms to Health Services or HR, as applicable. • Notify your supervisor as soon as possible but no later than 24 hours after the incident. • Obtain a "Work Related Incident Packet" from your supervisor. • If able, complete Section 1 of the Occupational Injury and Illness (OI&1) Form. • Notify 911 or rig paramedic, if applicable. Management 0 • Complete Section IV of the OW From. • As needed, make CERT notification. HES Department 0 • Complete Section II of OI&I Form. • Notify Health Services or other case manager, as needed, to assist with medical management. • Assist with Incident Investigation, as needed. • Send Ol&I Form to Houston within 7 calendar days of incident. NOTE: If incident is OSHA recordable, ensure it is posted to log within 7 calendar days. March 2013 © The Response Group Page 64 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.13 Medical Emergency (Cont'd) 00A7 @ ©T 1IP_O7®@ HE°aTTl==UEF=ooh . Contractor Worker Injured or III Employees Supervisor or PIC v • Ensure contractor receives needed medical assistance. Request contract company representative accompany injured / ill person to medical facility. • Call MOC CERT (866-662-2378) to report the incident. • If one or more contractor employees are hospitalized or if there is a fatality, contact HES immediately. • Complete Section II of OI&I Form and return to HES within 3 calendar days of the incident. • Obtain Witness Summaries. • Complete additional incident investigation as needed. • Send witness summaries to HES Department. • Notify the MOC supervisor as soon as possible but no later than 24 hours after the incident. • If able, complete Section I of the Occupational Injury an Illness (OI&I) Report Form. • Notify 911 or rig paramedic, if applicable. Management v • Complete Section IV of the OI&I From. • As needed, make CERT notification. HES&S Department v • Complete Section II of OI&I Form. • Send OI&I Form to Houston within 7 calendar days of incident. • Assist with Incident Investigation as needed. March 2013 © The Response Group Page 65 1 Piceance Operations mergency Response Plan 2.2 Response Actions (Cont d) 2.2.14 Failure of Transfer Equipment Section 2: Emergency Response Actions Failure of Transfer E • ui • men ■ ■ Terminate transfer operations and close block valves. Transfer fluid to another tank with adequate storage capacity, if possible. ■ Drain product into containment areas, if possible. ■ Notify vessel personnel. I■ Eliminate sources of vapor cloud ignition by shutting down all engines and motors. ■ Keep all vessels and marine traffic out of the area. 2.2.15 Tank Overfill / Failure Tank Overfill / Failure ■ Shut down or divert source of incoming flow to tank. ■ Transfer fluid to another tank with adequate storage capacity, if possible. ■ Ensure that dike discharge valves are closed. ■ Monitor barge curbing for leaks and potential capacity limitations. ■ Begin transferring spilled product to another tank as soon as possible. 2.2.16 Piping Rupture/Leak (under pressure and no pressure) Piping Rupture/Leak (under pressurrand no pressure) ■ Shut down pumps. Close the closest block valves on each side of the rupture. Drain the line back into vessels or contained areas, if possible. Alert nearby personnel of potential safety hazards. • ■ If piping is under pressure, and there is a leak in piping, relieve pressure by draining into containment area or back to a tank, if possible, then repair line according to established procedures. Shut down sources of vapor cloud ignition and evacuate personnel, if necessary, until the leak is controlled. • 2.2.17 Manifold Failure March 2013 © The Response Group Page 66 anifol • F • -I Terminate transfer operations immediately. ■ ■ Isolate the damaged area by closing block valves on both sides of the leak/rupture. ■ Shut down engines and motors. Eliminate sources of vapor cloud ignition. ■ Drain fluids back into containment areas, if possible. March 2013 © The Response Group Page 66 Irte/1 Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.18 Bomb Threat Figure 2.12 — Bomb Threat Flowchart INCIDENT/THREAT • REMAIN CALM AND GATHER INFORMATION • Exact Words of the Caller: Threat Information Time call received:_a.m. p.m. Ended: a.m. p.m. Question to Ask: 1. WHEN is bomb going to explode? 2. WHERE is bomb right now? 3 . WHAT does it look like? 4. WHY id you place bomb? 5. WHAT is your name and address? DESCRIPTION OF CALLERS VOICE: Male Young Tone of Voice_ Female Middle-aged Accent Old_ Is voice familiar? If YES, who did it sound like? Background Noise? NAME OF PERSON RECEIVING CALL: NOTIFY SUPERVISOR • NOFITY LAW ENFORCEMENT • REMOVE PERSONNEL FROM THREATENED AREA UNTIL THREAT SUBSIDES MAKE A CERT REPORT March 2013 © The Response Group Page 67 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Response Actions 2.2 Response Actions (Cont'd) 2.2.18 Bomb Threat (Cont'd) het Remain Calm Gather as Much Information as Possible Notifications Secure the Threatened Area CERT Report I©Bo apTERM§ TTT@Nr Z@7@BD'J 1 2 • Remain calm and try to keep the individual on the line. • Time call was received and ended • Who, what, when, where and why • Description of voice: Is the voice familiar? • Background noise 3 • Notify supervisor of the situation • Notify Law enforcement 4 5 • Remove personnel from threatened area until the treat subsides • Call the CERT Team to notify them of the threat March 2013 © The Response Group Page 68 indY Marathon Oil` Piceance Operations Emergency Response Plan Section 2: Emergency Respons Actions 2.2 Response Actions (Cont'd) 2.2.19 Evacuation Based on analysis of the sites as discussed elsewhere in the plan, an evacuation plan shall be developed. In addition, plans to evacuate parts of the facility that are at a high risk of exposure in the event of a discharge or other release must be developed. Evacuation routes must be shown on a diagram of the facility (refer to diagrams). Local evacuation plans and diagrams are maintained at the local operations level. When developing evacuation plan, consideration must be given to the following ctors, as appropriate: ✓ Location of stored materials ✓ Hazard imposed by discharge material V Discharge flow direction ✓ Prevailing wind direction and speed V Water currents, tides, or wave conditions (if applicable) ✓ Arrival route of emergency response personnel and response equipment ✓ Evacuation routes I ✓ Alternative routes of evacuation ✓ Transportation of injured personnel to the nearest emergency medical facility I ✓ Location of alarm/notification systems ✓ The need for a centralized check-in area for evacuation validation (roll call) ✓ Selection of a mitigation command center I ✓ Location of shelter at the facility as an alternative to evacuation I One resource that may be helpful to owners/operators in preparing this section of the response plan is The Handbook of Chemical Hazard Analysis Procedures by the Federal Emergency Management Agency (FEMA), Department of Transportation (DOT) and EPA. The Handbook of Chemical Hazard Analysis Procedures is available from FEMA, Publication Office, 500 C. Street S.W. Washington D.0 20472, (202) 646-3484. March 2013 © The Response Group Page 69