Volume I

GEOLOGIC SUMMARY REPORT OF THE

1989 EXPLORATION PROGRAM SUNNYSIDE TAR SANDS PROJECT

CARBON COUNTY UTAH

for ROBERT E. LUMPKIN

DIRECTOR, SOLID RESOURCES AMOCO CORPORATION NAPERVILLE, ILLINOIS

by WM. S. CALKIN, D.Sc. CONSULTING GEOLOGIST GOLDEN, COLORADO

July 30, 1990

Volume I

TABLE OF CONTENTS

SUMMARY AND CONCLUSIONS 1

RECOMMENDATIONS 4

INTRODUCTION 5

GEOGRAPHIC SETTING 6

Location 6

Access 6

LAND STATUS 8

HISTORICAL PERSPECTIVE AND PROJECT CHRONOLOGY 9

REGIONAL SETTING 18

Geology 18 Structural Setting 18 Regional Framework 18 Geophysics 19

Aeromagnetics 19 Gravity 20 Seismic 20

GEOLOGY OF PROJECT AREA 22

Structure 22

Mt. Bartles-Bruin Point Flexure 22

Structure Contour Map of Blue Marker 23

Green River Formation 25

Parachute Creek Member 26

Wavy Bedded Tuff 27 Mahogany Oil Shale 28 R-5 Oil Shale 3 0 Lower Tuff 31 Blue Marker 31

Garden Gulch Member 34 Douglas Creek Member 36

Sunnyside Delta Complex 38

Oil

Bruin Point Subdelta 40 Dry Canyon Subdelta 42 Whitmore Canyon Subdelta 43

Shales and Limestones 44

Shales 44

Limestones 47

Rock Data 49

Porosity and Permeability 49

Compressive Strength 50

TAR SANDS 52

Maps and Cross Sections 53

Tar Sand Isopach Map 53 Base of Saturation Map 54 Roan Cliffs Strike Section A-A1 54 Range Creek Strike Section B-B' 56 Bruin Point Dip Section C-C 57 South Area Dip Section D-D1 57 North Area Dip Section E-E1 58

Sheet Sands and Channel Sands 59 Depositional Environments 60

Sedimentary Structures 61 Lag Deposits 64 Textures 64 Mineral Composition 65

Interpretation 66

DRILL HOLE AND MEASURED SECTION SYNTHESIS 70

Drill Hole Data 71

1989 Core Logging 73

Highlights of 1989 Drill Hole Strip Logs 74

Measured Section Data 82

Highlights of 1989 Measured Section

Strip Logs 84

WELL LOGS 86

Gamma-Density- Caliper 86 Multi-Channel Sonic 87

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Focused Electric 88 Tar Sand Analysis 88 Well Log Interpretation 88

SURFACE GAMMA RAY LOGS 91

GEOCHEMISTRY 93

Kerogen Type 93 Project Evidence 94 Formation of Oil Shale 94 Biodegration of Bitumen 95 Thermal Maturity 96

REFERENCES 98

APPENDIX

Photos 1-8 Figures 1-28 Tables 1-7

Volume I

LIST OF PHOTOS

Photo 1 Aerial Mosaic of the Sunnyside Tar Sands Area Looking Southeast

Photo 2 View of South Area Along Roan Cliffs

Photo 3 View of Measured Section No. 61 on Roan Cliffs

Photo 4 Outcrop of Wavy Bedded Tuff

Photo 5 Core Sample of Algal Stromatolite in R-3 Oil Shale Interval

Photo 6 Roadside Outcrop of Blue Marker Near Bruin Point

Photo 7 Blue Marker in Core, Drill Hole RCT-11

Photo 8 Outcrop of Carbonate Interval, Measured Section 15

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Volume I

LIST OF FIGURES

Figure 1. General Location Map, Sunnyside Tar Sands, Uinta Basin, Utah.

Figure 2. Area Location Map, Sunnyside Tar Sands.

Figure 3. Location of Mt. Bartles-Bruin Point Segmented Flexure, Measured Sections of 1986-88 and Drill Sites of 1988, Sunnyside Tar Sands Area, Carbon County, Utah.

Figure 4. Leasehold and Fee Ownership Map, Sunnyside Tar Sands, Carbon County, Utah.

Figure 5. Surface Ownership Map, Sunnyside Tar Sands, Carbon County, Utah.

Figure 6. Northeast Portion of Energy Resources of Utah.

Figure 7. Paleogeography of the Paleocene (66-58Ma), Northeast Utah.

Figure 8. Paleogeography of the Eocene (58-37Ma), Northeast Utah.

Figure 9. Stratigraphic Section and Isopach Maps of Uinta Basin.

Figure 10. Northeast Utah Correlation Chart.

Figure 11. Index Map of Uinta and Piceance Creek Basins.

Figure 12. West to East Cross Section of the Uinta Basin Looking North.

Figure 13. Idealized Section of Bruin Point Subdelta Showing Tar Zones and Depositional Environments.

Figure 14. Idealized Section of Dry Canyon Subdelta Showing Tar Zones and Depositional Environments.

Figure 15. Stratigraphic Markers in the Parachute Creek Member, Sunnyside Tar Sands, Carbon County, Utah.

Figure 16. Wavy Bedded Tuff and Mahogany Zone, A-71, Well Log and Lithology Correlations.

Figure 17. Oil-Shale Zonation and Important Markers in the Green River Formation

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Figure 18. Rich and Lean Oil Shale Zones in the Green River Formation, Piceance Creek Basin, Colorado.

Figure 19. Detail of Mahogany Oil Shale Terminology.

Figure 20. R-5 Oil Shale, A-72, Well Log and Lithology Correlations.

Figure 21. Blue Marker, CD-I, Well Log and Lithology Correlations.

Figure 22. Cross Section, Longitudinal Section and Perspective of Microscopic Size BOTRYOCOCCUS BRAUNII.

Figure 23. Important Stratigraphic Markers in the Green River Formation, Sunnyside Tar Sands, Carbon County, Utah.

Figure 24. Well Log Shapes and Grain Size Distribution.

Figure 25. Well Log Shapes and Depositional Settings.

Figure 26. Kerogen Types: Their Origin, Chemical Character­istics and Oil Potential.

Figure 27. Highlights of Van Krevelen Diagram and Products of Kerogen Evolution.

Figure 28. Scheme of Kerogen Evolution and Petroleum Formation.

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Volume I

LIST OF TABLES

Table 1 Bruin Point Subdelta, Tar Zone Data Drill Core Data Measured Section Data

Table 2 Dry Canyon Subdelta, Tar Zone Data Drill Core Data Measured Section Data

Table 3 Whitmore Canyon Subdelta, Tar Zone Data Drill Core Data Measured Section Data

Table 4 Lithology Within Western Segment of Flexure, Sunnyside Tar Sands

Table 5 Rock Type Characteristics, Sunnyside Tar Sands

Table 6 Mean Composition of Bituminous Sandstones, Sunnyside Tar Sands

Table 7 Drill Core and Well Log Correlations, Sunnyside Tar Sands

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Volume II

scale scale scale scale scale

1 1 1 1 1

in in in in in

= = = = =

2000 1000 1000 2000 2000

ft ft ft ft ft

List of Maps

Regional Map Geology Map Tar Sand Isopach Map Base of Saturation Map Structure Contour Map of Blue Marker

List of Cross Sections (horizontal scale 1"=1000 ft, vertical scale=200 ft)

Roan Cliffs Strike Section A-A' Range Creek Strike Section B-B1

Bruin Point Dip Section C-C* South Area Dip Section D-D' North Area Dip Section E-E'

on

Volume III

Strip Logs (scale 1"=50 ft)

Drill Hole BP-1 RC-1 RCT-1 RCT-2 RCT-3A RCT-4 RCT-5 RCT-6 RCT-7 RCT-9 RCT-10 RCT-11 RCT-13

WCT-3A WCT-4 SS-NW-1 SS-NW-2 SS-NW-4 SS-NW 5 SS-NW-6 SS-NW-7 GN-13 GN-15

Measured Section 60 61

oiuo

SUMMARY AND CONCLUSIONS

The distribution of the tar sands is controlled by three factors: lithology, structural position within a segmented flexure, and stratigraphic position relative to three markers. First, the tar sands are largely confined to porous and permeable sandstones within a lacustrine delta. Second, the majority of tar sands are confined to the western segment of a northwest trending flexure. Third, major tar sands exist below the carbonate interval; minor tar sands exist between the carbonate interval and the Blue Marker; and limited tar sands exist above the Blue Marker. These relationships are visually apparent from the Tar Sand Isopach Map and the Roan Cliffs Strike Section A-A' .

The Tar Sand Isopach Map illustrates two distinct features about the Sunnyside Tar Sands. First, the thickest portion of the tar sands exists beneath Bruin Point and within the western segment of the flexure. Second, the tar sands are concentrated within a long narrow northwest trending belt that parallels the Roan Cliffs. This belt of tar sands is six to eight miles long, one to two miles wide and 300-1100 feet thick. Bitumen deceases rapidly outside this well-defined belt.

This tar sand belt is divided into north, central and south areas that represent different mega mining units. The north area is unique in three ways. First, it con­tains about ten percent more relative tar sand or pay compared to the central or south areas. Second, the north area contains about ten percent less relative shale since the Parachute Creek Member is completely eroded away. Third, depths to the base of saturation are about 125 feet shallower than in the south area and about 480 feet shallower than in the central area. These three factors are visually apparent from four cross sections (A-A', C-C, D-D' and E-E') and quantitatively apparent from Table 4.

The Mt. Bartles-Bruin Point flexure is a subtle northwest trending structure that has a significant control on the distribution of bitumen. The flexure is segmented into three parts. The western segment exists near the Roan Cliffs, has beds that dip 4-12° northeast and sandstones that contain 4-12wt% bitumen. The central segment has beds that dip 4-7° northeast and sandstones that contain 4-7wt% bitumen. The eastern segment exists in the West Tavaputs Plateau, has beds that dip 3-5° northeast and sandstones that contain 0-4wt% bitumen. These general relationships are shown on the Geology Map and cross section C-C. The locations of specific field criteria that help to define this segmented flexure are shown on the Geology Map.

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The bituminous sandstones are largely confined to fifteen number tar zones that have good lateral continuity. The majority of the tar sands are sheet sands, while a minority of the tar sands are channel sands. The sandstones are uniform in grain size and mineral composition. They are fine grained to very fine grained sandstones that are dominated by quartz (33%), feldspar (28%), and bitumen (20%). The sandstones have an average porosity of 27 percent and an average permeability of 812md (millidarcy). Minor amounts of bitumen are associated with siltstones (average porosity 22 percent and average permeability 64 md) and limestones (average porosity 18 percent and average permeability lmd). The scheme of the numbering system for the fifteen tar zones is shown in Figure 13. Almost eighty-seven percent of the bituminous sandstones exist within eleven numbered tar zones (31,32,33,35,36,37,38,41,42,43 and 45). About fifty-seven percent of the bituminous sand­stones exist within five numbered tar zones (31,35,36,37 and 38). The thickness and grade of each numbered tar zone from all logged drill holes and measured sections is listed in Tables 1, 2 and 3.

The Sunnyside Tar Sands exist within the Eocene Green River Formation which has been separated into three members. The Douglas Creek Member is at the base and is characterized by major volumes of bituminous sandstones with intervening red shales; it represents the delta facies. The Garden Gulch Member is in the middle and is characterized by major to minor volumes of bituminous sandstones with intervening green shales and limestones; it represents the shore facies. The Parachute Creek Member is at the top and is characterized by gray shales, oil shales and limited bituminous sandstones; it represents the lake facies. The stratigraphic control established in this tar sand project is based on core drill holes and measured sections completed from 1980-1989. Over 60,000 feet of core has been logged by myself from some 100 drill holes that average about 98% core recovery. Sixty-one measured sections have been completed throughout the area and encompass over 46,000 vertical feet.

Core logging and field work have defined five significant markers within the Parachute Creek Member. These are the Wavy Bedded Tuff, Mahogany oil shale, R-5 oil shale, lower tuff and Blue Marker (see Figure 15). The Wavy Bedded Tuff has an age date of 47 my, while the lower tuff has an age date of 51.5 my. The Blue Marker exists at the base of the Parachute Creek Member. The Blue Marker is readily recognized by a distinct lithology and specific gamma ray log expression.

01H2 2

The Structure Contour Map of the Blue Marker illustrates the structure in the area is a basic ramp or monoclinal dip slope that contains no closure.

The carbonate interval is 250 feet below the Blue Marker and averages seventy feet thick (see Figure 23). The carbonate interval represents an important regional Interval. It exists within the middle to lower portion of the Garden Gulch Member and encompasses Tar Zones 25 and 26. The vast majority of the tar sands in the project area exist below the carbonate interval and start with Zone 31.

The Base of Saturation Map contains a large central flat area (three miles long by two miles wide) that interrupts the uniform dip slope of the Structure Contour Map. This central flat area coincides with the vast majority of the tar sands.

The bitumen is of algal origin and Tertiary age. The bitumen is derived from Type I kerogen, is strongly bio-degraded and thermally immature.

The tar sands exist within a lacustrine delta exposed along the Roan Cliffs The Bruin Point area represents a pile of laterally continuous, stacked bituminous sand­stones alternating with red, green and gray shales. These rocks formed some 57-47 million years ago in delta-beach-nearshore environments associated with the margins of Lake Uinta. The Sunnyside delta consists of fifteen major stacked intervals of sandstone-shale-limestone-unconformity sequences. These lithologic sequences were repeated again and again. They represent cycles associated with regressions that formed the sandstones and transgressions that formed the shales and limestones. These cycles of sedimentation were associated with fluctuating lake levels caused by alternating wet and dry climatic cycles.

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3

RECOMMENDATIONS

1. An isopach map of each numbered tar zone should be generated from the computer mine model data base. These fifteen individual isopach maps will define the thickness distribution and depositional patterns of the major tar zones. These isopach maps represent a final step in comprehension of the Sunnyside Tar Sands deposit. They will be useful for mine planning and evaluation of the property.

2. The regional and engineering geology of the area from the Asphalt Mine near Bruin Point to the proposed plant site in Clark Valley should be accurately mapped. This information is needed to evaluate conveyor belt routes down from the Roan Cliffs to the Whitmore Canyon valley and through the Book Cliffs to the proposed plant site in Clark Valley.

4

01144

INTRODUCTION

This report includes the 1989 data and represents a summary of previous exploration reports. Eight photographs included in Volume I are used to highlight aspects of the Sunnyside. Tar Sands project. Volume II contains five maps and five cross sections. Volume III contains twenty-six strip logs.

Both field and drill core data were used in conjunction with gamma ray well logs to correlate and determine numbered tar zones. The use of numbered tar zones has established continuity between the field data and drill hole data through­out the entire Sunnyside Tar Sands area. The numbered tar zones and bitumen content of each drill hole and measured section completed since 1980 appear in Tables 1, 2 and 3. Table 4 is a compilation of the lithology within the western segment of the flexure. It is based on forty-nine drill holes and shows important differences exist between the north, central and south areas. Environments of deposition were determined from both core logging and field work; have been helpful in the lithologic correlations; and useful to comprehend the Sunnyside delta complex. Table 5 is a summary of the various rocks that exist within the tar sand area and includes a listing of associated bitumen content, rock type, common color, fossils, distinguighing characteristics and environments of deposition.

The 1989 field program focused on logging 11,098 feet of core from twenty-two drill holes completed by Mono Power in 1982 and 1983. Two new measured sections were also completed. Five marker units exist within the area and include the Wavy Bedded Tuff, Mahogany oil shale, R-5 oil shale, Blue Marker, and carbonate interval.

The 1989 field season extended from June 6 through September 1 and included 64.5 working days. A breakdown of these working days includes 1 day of organization; 39 days for logging core (38 days in Price and 1 day in Naperville); 11 days for field mapping and measured sections; 13 days for travel and 0.5 day for a project meeting in Naperville. The weather was abnormally dry. Water levels in creeks and springs were at their lowest levels in the past ten years.

0V\4$

5

GEOGRAPHIC SETTING

Location

The Sunnyside Tar Sands area is located in northeastern Utah about one hundred miles southeast of Salt Lake City and about thirty miles east of Price as shown in Figure 1. The Sunnyside Tar Sands area is located in the southwest portion of the Uinta Basin within Carbon County, centered near Bruin Point and located about six miles northeast of the coal mining town of Sunnyside as seen from Figure 2 and Photo 1. The principal physiographic features in the area are highlighted in Figure 2 and consist of the Book Cliffs, Roan Cliffs and West Tavaputs Plateau. The location of the newly defined Mt. Bartles-Bruin Point flexure is indicated on Figures 2 and 3. Photo 1 is an oblique aerial mosaic and provides an excellent view of the project area with names of various geographic features.

The geographic features and scale of the project require access to four separate areas - Bruin Point, Mt. Bartles, Whitmore Canyon and Clark Valley. Bruin Point is on the Roan Cliffs and contains the majority of the tar sands. Mt. Bartles is associated with the West Tavaputs Plateau and provides access to three CD drill holes and ten measured sections. The Whitmore Canyon area contains four measured sections as well as eight Mono Power and two Great National drill holes. Clark Valley contains the proposed plant site and tailings dam and is located on the west side of Book Cliffs,

Access

Access to Bruin Point is via the town of Sunnyside, up Whitmore Canyon and up Water Canyon. The last two miles to Bruin Point beyond the Asphalt Mine contain steep grades of fifteen to twenty percent. Roads to Bruin Point and Mt. Bartles are from two entirely different routes.

Access to Mt. Bartles is from Wellington via Nine Mile Canyon, across Nine Mile Creek and up Harmon Canyon (located 32.7 miles from the Wellington turnoff) or up Prickly Pear Canyon (located 8.6 miles down Nine Mile Canyon from Harmon Canyon). Within Harmon Canyon the road travels along the creek bed for half-a-mile and passage can be difficult to impossible. Two landslide areas exist in Harmon Canyon with the most danger­ous just above the half-a-mile creek passage. The BLM no longer maintains Harmon Canyon on a yearly basis. Within Prickly Pear Canyon the road is generally clear and of moderate grade as it was used between 1959-1981 to transport oil and gas drilling equipment for nine exploration holes located in the vicinity of the Stone Cabin gas field (abandoned). Most of'the oil and gas wells are within two to four miles of the

6 01146

abandoned landing strip and were drilled to depths of 5600-7200 feet. The roads up Harmon Canyon and Prickly Pear Canyon join at a stock pond above the abandoned landing strip near the top of Harmon Canyon (Figure 2). Final access to the Mt. Bartles area is controlled by a locked gate located near the "W" in West Tavaputs Plateau of Figure 2. The combination to the locked gate can be obtained at the Calder ranch located about 1.5 miles east of Harmon Canyon.

Access to the Whitmore Canyon area is via dirt roads adjacent to Grassy Trail Reservoir and up the Right Fork or Left Fork of Whitmore Canyon (Figure 2). Access to the Grassy Trail Reservoir is via the massive locked gate controlled by the coal mine at Sunnyside. Another locked gate exists up the Right Fork of Whitmore Canyon and is controlled by Harold Marston of Wellington.

Access to Clark Valley and the proposed plant site is via Sunnyside, the golf course road, and 3.7 miles on a dirt road along the base of the Book Cliffs to the mouth of B Canyon (Figure 2). Another access exists by turning north off Route 123 at 2.7 miles from Sunnyside Junction. Then, at 1.1 miles turn right and head in a northeast direction for 3.3 miles to a dirt road junction located near the proposed 5500 foot wide tailings dam between two natural abutments. Hence 3.2 miles on the right fork to the proposed plant site.

Clark Valley Geology Note: Well data from five holes that exist within an arc 4.5-7.5 miles from the proposed tailings dam indicate the depth to the top of the Ferron Sandstone Member of the Mancos Shale averages about 1200 feet. See Figure 10 for stratigraphic position of the Ferron Sandstone Member. The thickness of the Mancos Shale is an important factor to consider for design of the tailings dam.

7

01147

LAND STATUS

The land status of the area encompassing and surrounding the Sunnyside Tar Sands is shown in Figure 4 (Leasehold and Fee Ownership) and Figure 5 (Surface Ownership). The data base for both Figures 4 and 5 is Map 1-4, Sunnyside Combined Hydrocarbon Lease Conversion, draft Environmental Impact Statement, BLM, November 1983, that has been updated by APC to September 1987. Figure 4 reflects the purchase of Mono Power's interests by Amoco. Numerous leases controlled by Amoco within the Sunnyside Tar Sand area exist in a checker­board pattern and total 29.6875 sections or 19,000 acres. Amoco fee lands total 1.75 sections or 1120 acres.

Within the main portion of the Sunnyside Tar Sands deposit only three important blocks are not controlled by Amoco (Figure 4) and include: (1) fee land totalling 1.125 sections, or 720 acres, controlled by Coca Mines and commonly referred to as h Mt. Mary's Parish and h Crosby Corporation; (2) fee land of Gibbs Heirs that totals one section of 640 acres; and (3) a federal hydrocarbon lease controlled by Great National Corporation for \ section or 160 acres.

Figure 5 indicates that much of the surface ownership near Bruin Point is controlled by Amoco, Coca Mines and Gibbs Heirs. Other surface in the Sunnyside Tar Sand area is controlled by the BLM and private ownership. The road from the Asphalt Mine to Bruin Point is a county designated road with a 25-foot right-of-way.

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HISTORICAL PERSPECTIVE AND PROJECT CHRONOLOGY

1892 First small quarry operation mines 1,000 tons of tar sands for street paving in Salt Lake City. Quarry located about 500 feet southeast of drill hole location GN-4 at an elevation near 9000 feet.

1902-1903 Another 1,000 tons of rock removed from same small quarry.

1915-1917 Utah Asphalt Company opens new quarry site and ships 3,000 tons before closing operations. This new quarry site became site of Asphalt Mine located about 2000 feet south of Bruin Point at an elevation near 8900 feet. Old road to Bruin Point via Right Fork of Whitmore Canyon and South Patterfore Canyon.

1925-1927 Utah Rock Asphalt Corporation builds aerial tramway operated by gravity and opens Asphalt Mine in 1927. The aerial tramway was made by American Steel and Wire Company of New York-Chicago-Boston.

1927-1931 Utah Rock Asphalt Corporation quarries 25,000-30,000 tons from the Asphalt Mine. The rock was transported to Whitmore Canyon by the three mile long aerial tramway system (mostly still standing) and then by small trucks to the processing site located near the terminus of the present railroad spur for the coal mines at Sunnyside.

1931-1948 Rock Asphalt Company of Utah maintains yearly seasonal quarry work and removes 300,000 tons of rock which is crushed and used without further treatment for paving within Utah and Colorado. The yearly output in 1945 was 20,000-30,000 tons. Rock Asphalt Company of Utah ceases mining operations in 1948. All-time total removed from Asphalt Mine site about 335,000 tons.

1943 Road above Asphalt Mine to Bruin Point completed by Glenn Long of East Carbon. This new road re­placed the old haulage road to Bruin Point that went up via the Right Fork of Whitmore Canyon and South Patterfore Canyon.

1948 U.S. Geological Survey publishes results of ex­tensive study by Holmes, Page & Averitt and estimates reserves of 1,600,000,000 cubic yards containing 728,000,000 barrels of bitumen above grades of 9wt% bitumen,' All beds less than ten feet were excluded from estimates.

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1956 Gulf completes one core hole to depth of 2,684 feet about 4 miles northeast of the Asphalt Mine. Available data from the hole is limited.

1964 Arco contracts Himes Drilling Company of Grand Junction, Colorado and completes five core holes one to three miles northwest to northeast of the Asphalt Mine. Available data from these holes is limited.

1964-1966 Phillips Petroleum Company completes three drill holes, one each winter. The third hole is two . miles northeast of the Asphalt Mine. The first two holes are two and three miles east of Mt. Bartles. Partial drill hole data is available on these three holes within the Mono Power files stored at APCr Denver.

1964-1966 Pan American completes regional work including four measured sections and two core holes two to four miles east and southeast of the Asphalt Mine. Data from these measured sections and drill holes exists in the project files.

1963-1966 Shell Oil completes six core holes within a 16 square mile area. Data from the six core holes is in the project files and includes drill logs and core analyses. Five steam injection holes are completed with a 600 ft x 800 ft area. The in-situ steam injection tests were unsuccessful due to an extensive vertical fracture system and the inability to inject steam into the rock matrix.

The in-situ injection experiments consisted of steam soak and steam drive tests (Thurber and Welbourn, 1977). These tests were performed from a large open pad area located southeast of Bruin Point and about 1000 feet east of the current U.S. West communication tower and building. The steam soak tests were conducted during the first summer and consisted of eight day soak periods with eleven and eighteen day production cycles. The steam soak tests produced only trace amounts of viscous oil. The steam drive tests were conducted during the next two summers and were designed to close vertical fractures and induce horizontal fractures. During the steam drive tests the best well produced 0.5 BOPD.

1965 Texaco completes three core holes three to four miles north and northeast of the Asphalt Mine. Strip logs are available and within the project files.

10 01150

1965 Mountain Fuels completes one drill hole five miles north of the Asphalt Mine to a depth of 9650 feet. No lithologic data is available. Well logs exist but begin at a depth of 1020 feet. BHT @ 9650 feet is 148°F.

1965-1966 Signal Oil and Gas Company of Los Angeles, California drills core hole Sunnyside No. 1 (T.D. 1450 ft) and performs in-situ st^am injection experiments. Signal Sunnyside No. 1 was cored from 395-1450 feet. Well logs on the hole consist of one induction electric log and two formation density logs. Bitumen values were determined from an on site field test and are anomalously low by some twenty percent. Note: For the 1981 project report the limited lithologic and core analysis data was used to make a strip log; copies of any original well logs are not available.

In-situ steam injection experiments were performed in the Asphalt Mine. Three parallel horizontal wells oriented N32°W with T.D.'s of 366-390 feet exist in the northwest wall of the main pit. The purpose was to produce oil by application of steam. A five day huff and puff test on the center well injected 142,800 lbs. steam and produced no oil. From September 16 through November 1, 1966 the two outside wells were used for steam injection with the center well used as a production well. Steam was injected at 510 psi and 470°F. A total of 4.84 million pounds steam (4,671 MM Btu) was injected. Total production from the center well was 560 barrels of net crude and 10,000 barrels of water. The value BBL OIL divided by MM BTU injected is 0.12 (data from Glassett, et al, 1978).

1977-1978 Amoco Production completes five core holes in 1978 (Nos. 2, 3, 5, 6, 7) and starts holes No. 1 and No. 4. Amoco Production completed 6,304 feet of core drilling. This program was documented by a written report and maps by B.R. Wilson and G. Ziemba, March 1977, as well as memorandum FR-06-79 by T.L. Burgett and 5 maps by T.L. Burgett and D.A. Sawicki.

1979 Great National completes five core holes that totalled 2894 feet. These holes were drilled along the Bruin Point road and within the Asphalt Mine. All holes are located within fee land of St. Mary's Parish-Crosby Corp. The location of these drill holes is shown on the Geology Map (scale 1"=1000'). Pertiment saturation data from the core is shown on the Regional Map (scale 1"=2000').

11 01151

1979 Standard Oil Company of Indiana completes purchase from Kaiser Steel for NE%, SE% and NW% of Section 3 and all of Section 2, T.14S., R.14E. This was initially referred to as the Kaiser tract and later the Amoco tract.

198 0 Amoco Minerals from mid-June to early October completes six core holes (Nos. 1, 4, 8-11) near Bruin Point that total 6733 feet. Two Longyear 44 rigs were used by Longyear Drilling of Salt Lake City. All core was logged in Price with bituminous intervals marked for analysis by Core Labs in Denver. Well logs were made by Century Geophysical Corporation on Amoco Nos. 4, 5, 8-11. Six Measured sections (Nos. 1-6) were completed and total 6,437 feet. Pertinent saturation data from the core drilling and measured sections is listed on the Regional Map.

Synopsis: All results indicate the bitumen is almost solely confined to the sandstones which are localized within major channels and sheet sands of a lacustrine delta complex. The Green River Formation is divided into three members based on the presence of oil shales, limestones and three types of shales separated on the basis of color (gray, green, red). The Parachute Creek Member is characterized by oil shales, gray shales and contains 5% of the tar sands. The Garden Gulch Member is characterized by limestones, green shales and 15% of the tar sands. The Douglas Creek Member is characterized by red shales and 80% of the tar sands. For additional details, see 1980 Geologic Summary Report.

1980 Great National Corporation completes eight core holes that total 8922 feet. Six of the core holes are located near Bruin Point. Two core holes are located in the Whitmore Canyon area. The location of these eight drill holes and pertiment saturation data is shown on the Regional Map (scale 1"=2000?).

1981 Amoco Minerals from mid-June to mid-October completes fifteen core holes (Amoco Nos. 12-26) near Bruin Point that total 10,796 feet. Three Longyear 44 rigs were used by Longyear Drilling of Salt Lake City. All core was logged in Price with bituminous intervals marked for analysis by Core Labs in Denver. Well logs were made by BPB Instruments and exhibit excellent correlation between lithology and tar sands. Golder Associated of Denver initiates

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geotechnical and hydrological studies and installs piezometer strings in Amoco Nos. 16, 21 and 26. Five measured sections (7-11) were completed and total 4148 feet. Pertinent saturation data is listed on Regional Map.

Synopsis: The lithology of the lacustrine delta complex consists of well-saturated sandstones, moderately-saturated conglomerates, moderate- to weakly-saturated limestones and siltstones as well as nonsaturated shales. The tar sands are fine grained to very fine grained well-sorted sandstones with 25-30% porosity. Gases exist near the base of the tar sands. Analysis of bottled core indicates these gases contain 98.5% CO2, 1.4% CO, 0.04% methane, 0.06% other with no detectable H2S. The Parachute Creek Member is the lake facies and averages about 200 feet thick. The Garden Gulch Member is the shore facies and averages about 300 feet thick. The Douglas Creek Member is the delta facies and averages about 650 feet thick. The Bruin Point area contains eleven saturated zones that are mostly within the delta facies. The Bruin Point area averages about 500 feet of overburden and represents the main portion of the delta complex. To the north the untested Dry Canyon area contains 3-8 saturated zones that are mostly within the shore facies. The Dry Canyon area averages about 150 feet of overburden and represents the secondary portion of the delta complex. For additional details, see 1981 Geologic Summary Report.

1981 Mono Power/Phillips Petroleum drills two holes in the Mt. Bartles area. Work was completed by Berge Exploration and included drill holes Stone Cabin Draw C.H. #1 and South Ridge DH #1. Some data from these holes is in the Mono Power files stored at APC, Denver.

1982 Amoco Minerals from mid-June to mid-October com­pletes twenty-two core holes (Amoco 27-48) that total 12,300 feet within the Dry Canyon or north area. Three Longyear 44 rigs were used by Longyear Drilling of Salt Lake City. All drill core was logged in Price with bituminous intervals marked for analysis by Core Labs of Denver. Piezometer strings were installed in Amoco Nos. 4, 10 and 24. Well logs were completed by BPB Instruments and exhibit excellent correlation between lithology and tar sands. Six measured sections (12-17) were completed and total 3929 vertical feet. Pertinent saturation data from the core drilling and measured sections is listed on the Regional Map.

13 OU53

Synopsis: The essence of the Sunnyside Tar Sands deposit is a sequence of three to eleven laterally continuous stacked bituminous sandstones with inter­vening gray, green or red shales. Individual tar zones range in thickness from 10-250 feet and contain bitumen values from 5-13wt% or 12-32gpt. The Tar Sand Isopach Map shows an elongate distribut­ion of tar sands along the Roan Cliffs with the thickest portion 500 cumulative feet of tar sands near Bruin Point. The tar sand deposits represent channels, channel mouth bars and beach to beach bar deposits of a lacustrine delta. The main channels flowed N40-70°E toward the Uinta Basin. The Sunnyside delta complex is divided into three subdeltas. The Bruin Point subdelta contains about 70% of the tar sands. The Dry Canyon subdelta contains about 25% of the tar sands. The Whitmore Canyon subdelta contains about 5% of the tar sands. The sedimentary beds strike N25-40°W and dip 5-7°NE. Rock compressive strength tests of tar sands average 5000psi, limestones average 8000psi, siltstones average 9000psi and shales average 13,000psi. The gray shales average 16,000psi and were deposited in lake environments of moderate water depths. The green shales average ll,000psi and were deposited on nearshore environments of shallow water depths. The red shales average 16,000psi and were deposited in marsh environments. For additional details, see 1982 Geologic Summary Report.

1982 Mono Power in a joint venture with Phillips Petroleum drills nine holes in late summer and fall. Work was completed by Berge Exploration. Seven holes (SS-NW-1 through 7) were drilled in the Whitmore Canyon area. Two holes (RC-1 and BP-1) were drilled east of Bruin Point.

1982 Chevron enters into a joint venture with GNC Energy and drills thirteen holes that total 11,390 feet. Drilling was completed during late fall in areas along the Roan Cliffs near the Asphalt Mine. This drill core is stored in buildings near the Cowboy gilsonite vein east of Bonanza, Utah.

1983 Chevron drops the joint venture agreement with GNC Energy.

1983 Mono Power drills seventeen core holes that total 13,052 feet. Core holes RCT-1 through RCT-14 and BP-lA are in the Range Creek area. Core holes WCT-3A and WCT-4 are in the Whitmore Canyon tract. Hole locations are shown on the Regional Map along with a listing of saturation data.

1984 Amoco Minerals between mid-June to early-September completes fifteen core holes (Amoco Nos. 49-63) that total 7814 feet within the Dry Canyon area. The holes were all drilled on Federal leases. All core was logged in Price with bituminous intervals marked for analysis by Core Labs in Denver. Two Longyear 44 rigs were used by Longyear Drilling of Salt Lake City. Ten deep holes totalled 7364 feet and five shallow holes within the proposed north area pilot mine site totalled 450 feet. Well logs were completed by BPB Instruments and exhibit excellent correlation between lithology and tar sands. Nine measured sections (Nos. 18-26) were completed within the Dry Canyon area and total 6967 vertical feet. The location of the core holes and measured sections is shown on the Regional Map along with a listing of saturation data.

Synopsis: Tar zone numbers utilized in mine modelling are incorporated into strip logs of drill holes and measured sections. Tar zone numbers first utilized on outcrops along Roan Cliffs. Repetitious cycles of sedimentation re­presented by: unconformity; sandstone deposition; shale deposition; limestone deposition followed by another unconformity. Indirect methods of tar sand analysis have ±15% error compared to direct core analysis. Thus drill core and direct methods of bitumen analysis are the most reliable. Average porosity and permeability of bituminous rock types differ markedly: sandstones <j>=27%, K=812md; siltstones <j>=22%, K=64md; limestones <f>=18%, K=lmd. Detailed composition of tar sands based on twenty thin section analyses by Remy (1984) is: pore space 20%; quartz 34%; feldspar 29%; rock fragments 8%; matrix 5%; carbonate cement 3%; mica and accessory minerals 1%. The 29% feldspar content consists of orthoclase 10%, microcline 3% and plagioclase 16%. Grinding and crushing of these partially weathered feldspar minerals, which also have two perfect cleavages, increases the fines content (i.e., minus 325 mesh screen or less than 44 microns) by some 25-150%. On the average the tar sands con­tain a natural 5% "fines" content. For additional details, see 1984 Geologic Summary Report.

1985 Amoco Corporation completes two weeks reconnaissance field work in the Mt. Bartles area during early August to evaluate the outlying hydrocarbon leases north of Dry Creek Canyon. Access to the Mt. Bartles area is via Nine Mile Canyon then up Prickly Pear Canyon (reliable and good) or up Harmon Canyon (hazardous portions).

15 oU**

1986 In June Amoco Corporation acquires Mono Power hydro­carbon leases along with all drill core and drill hole data from the Range Creek tract (RCT holes), Bruin Point area (BP holes) and Whitmore Canyon tract (SS-NW holes). From mid-June to mid-September Amoco Corporation completes three months of field work in the Mt. Bartles and Whitmore Canyon areas. Eighteen measured sections (MS-27 through 44) total 12,365 vertical feet.

Synopsis: These measured sections indicate no significant tar sands exist within the peripheral hydrocarbon leases in the Mt. Bartles area. Portions of the Whitmore Canyon area contain relatively small volumes of good tar sands along ridge tops. Surface gamma ray data from portable mini-spectrometer first utilized as part of measured section methodology. The surface gamma ray anomalies are definitive and along with stratigraphy take the guesswork out of establishing tar zone numbers noted on the strip logs. Field work partially defines segmented northwest trending flexure system and three oil shale intervals. Railroad shipment of 1000 tons of tar sands from Zone 43 in the north quarry of the Asphalt Mine to Chicago. Note: 800 tons from north quarry and 200 tons from Great National stockpile of tar sands from north quarry. Stockpile was located about two miles west of Dragerton along dirt road to local airstrip. For additional details, see 1986 Geologic Summary Report.

1987 Amoco Corporation completes 3% months of summer field work which is largely confined to the newly acquired South area. Work includes twelve new measured sections (MS-45 through 56) that total 8391 vertical feet as well as relogging 4624 feet of core from five Mono Power holes. This core had been stored in Price and was relogged to establish correct lithology, stratigraphic intervals and reliable bitumen values for mine modelling.

Synopsis: Three important markers were established and include Mahogany Ledge (R-7 oil shale interval), Blue Marker (R-2 oil shale interval) and carbonate interval (encompasses Zones 25 and 26) . Field work pinpoints Blue Marker and associated 0.5" coal seam. Wavy Bedded Tuff first noticed near top of MS-56. Location of segmented flexure firmly established within large monocline that slopes into Uinta Basin. The western segment is the most significant, exists along the Roan Cliffs and is characterized by 4-12wt% bitumen in beds that dip 4-12° northeast. For additional details, see 1987 Geologic Summary Report. ^

1988 Amoco Corporation completes extensive drilling program during Ah month field season. Twelve holes (A-64 through A-72 and CD-I, 2, 3) total 11,858 feet. Three drill rigs were used by Boyles Bros. Drilling of Golden, Colorado. Three measured sections (MS-57, 58 and 59) were com­pleted and total 1533 vertical feet. All core was logged in Price with bituminous intervals marked for analysis by Core Labs in Denver.

Synopsis; Correlation of drill hole data and measured section data finalized recognition of five marker beds within the Parachute Creek Member (i.e., Blue Marker; oil shale intervals R-3, R-5, R-7; and Wavy Bedded Tuff) as well as the regional significance of the seventy foot thick carbonate interval that is located just above Zone 31. Tar Zone 31 marks the beginning of the most important concentration of tar sands. Structure Contour Map of Blue Marker shows basic ramp structure with no closure over Bruin Point. Base of Saturation Map shows dip slope ramp with large central swale that is two miles wide and three miles long. This swale or central flat area coincides with the location of the vast majority of the tar sands. For additional details, see 19 88 Geologic Summary Report.

1989 Amoco Corporation completes three month summer field season. Relogged core from twenty-two Mono Power drill holes that were stored in Price. Total relogged footage was 11,098 feet with 70% from the South area, 20% from the Whitmore Canyon area and 5% from the Bruin Point area. All core was logged in Price with bituminous intervals marked for analysis by Core Labs in Denver. Measured sections 60 and 61 completed and total 2316 vertical feet.

Synopsis; Distribution of bituminous sandstones related to vertical position relative to Blue Marker and carbonate interval. Major tar sands exist below carbonate interval. Minor tar sands exist between carbonate interval and Blue Marker. Minimal tar sands exist above Blue Marker. Half-inch coal seam of Blue Marker is algal derived coal. Core in oil shale intervals contain algal structures. Oil shale in area represents algal derived kerogen (i.e., Type I kerogen). Extent of Wavy Bedded Tuff and R-5 oil shale determined in project area. For additional details, see this 1989 Geologic Summary Report.

17 o i i^

REGIONAL SETTING

Geology

The late Cretaceous and early Tertiary geology of north­eastern Utah is discussed to present the structural setting and regional framework associated with the Sunnyside Tar Sands. The structural setting forms the basis to understand the north­west trending Mt. Bartles-Bruin Point flexure. The regional framework forms the basis to understand paleodrainage and deposition of the Sunnyside delta complex in ancestral Lake Uinta.

The Sunnyside Tar Sands area is located about eighty miles east of the Cordilleran overthrust belt, about sixty miles northeast of the center of the San Rafael Swell and within the southwestern portion of the Uinta Basin. The Cordilleran overthrust belt complex is a major tectonic element in North America and was caused by compression of the westward-moving subducted Pacific plate during the late Cretaceous to Eocene time. That portion of the Cordilleran overthrust belt in Utah is variously known as the Sevier overthrust belt, Wasatch Line or Cordilleran hingeline.

Structural Setting

Northwest trending structures dominate the regional fabric of eastern Utah and represent ancestral zones of crustal weakness established in basement complexes during Precambrian time. These zones of crustal weakness have repeatedly been reactivated throughout different portions of geologic time and frequently control regional fabric as seen in Figure 6 and various geological maps of the State of Utah. The right half of Figure 6 shows this northwest trending structural element. In the lower right portion both the Moab fault zone and the Paradox fold and fault belt have a northwest trend. In the upper right portion south of Vernal numerous gilsonite veins have a northwest trend. The Book Cliffs between Sunnyside and Price have a northwest trend. This northwest trend is a dominant topographic and geologic feature that is related to Precambrian basement control and the late Paleozoic Uncompahgre Uplift. The location of the Uncompahgre Uplift is shown in Figures 8 and 9.

Regional Framework

Some 15,000 feet of sediments accumulated in northeastern Utah between late Cretaceous (70Ma) and late Eocene (35Ma). These sedimentary rocks are now exposed near the project area within the Book Cliffs, Roan Cliffs and West Tavaputs Plateau. After the eastward retreat of the late Cretaceous seaway, different lake centers formed within structural depressions. Lake Flagstaff formed during the Paleocene in the structural basin between the Sevier Orogenic Belt and the San Rafael

ov^s

Swell. Lacustrine sediments accumulated to form the Flagstaff Formation whose distribution is seen in Figure 7. The Flagstaff Formation underlies the Colton Formation but not the Wasatch Formation as shown in Figure 12. Lake Uinta formed during the Eocene in the structural basin between the San Rafael Swell, Uinta Uplift and Uncompahgre Uplift. Lacustrine sediments accumulated to form the Green River Formation whose distribu­tion is seen in Figure 8. The bituminous sandstones within the Sunnyside Tar Sands area are confined to the Green River Formation. The stratigraphic position of the Flagstaff and Green River Formations are illustrated in Figure 9. A correlation chart of Cretaceous and Tertiary formations in northeastern Utah is shown in Figure 10. In middle Eocene during the maximum extent of Lake Uinta numerous intervals of oil shale were formed and include the Mahogany oil shale. During late Eocene Lake Uinta regressed and at the end of Eocene time Lake Uinta dried up. Within the Uinta Basin sandstones derived from the Uinta Uplift are dominated by quartz, while those sandstones derived from the Uncompahgre Uplift are dominated by quartz and feldspar (Dickinson, Lawton and Inman, 1986).

Geophysics

In northeastern Utah regional geophysical data (aero-magnetics, gravity and seismic) indicate a dominant northwestern structural trend in the Sunnyside area. Two separate authors suggest a major subsurface fault in the vicinity of Sunnyside. The surface expression of this fault is suggested to represent the Mt. Bartles-Bruin Point flexure first recognized and mapped by Calkin and Grette during the 1986 and 1987 field seasons.

Interpretation of the geophysical data was enhanced by four maps (geology, aeromagnetics, basement and gravity) enlarged to the same scale which appear in the 1987 Exploration Report. The buried Uncompahgre Uplift exists within the southern portion of the Uinta Basin (Figure 9) and has a significant in­fluence on the overlying strata.

Aeromagnetics

In northeastern Utah the broad features of the aeromag-netic map indicate northwest trends and east-west trends. The northwest trends exist within the central portion and southwest margin of the Uinta Basin and coincide with the Uncompahgre structural trend of intermediate Laramide age. The east-west trends exist on the southern and northern margins of the Uinta Basin and correspond to the Uinta Mountain structural trend of youngest Laramide age.

An aeormagnetic high of 11,480 gammas is centered in a valley one to two miles south of Sunnyside. This valley is at the base of the Book Cliffs and near the town of Columbia.

«W**

Correlation of this aeromagnetic high at Sunnyside with the basement map indicates that the Sunnyside high is near the structural intersection of a basement complex that plunges northward from the San Rafael Swell and a basement complex that plunges northwestward from the Uncompahgre Uplift. Smith and Cook (1985) state that from an area ten miles south of Price hence eastward toward Sunnyside the basement rises about 7500 feet within twenty-four miles. This is equivalent to an average grade of six percent for twenty-four miles. The presence of a shallow basement complex near Sunnyside explains this prominent aeromagnetic high.

Gravity

The Bouguer Gravity Map of northeastern Utah was compiled and interpreted by Smith and Cook (1985). A major northwest trending subsurface fault is associated with a gravity low in the area of the Sunnyside Tar Sands. The gravity map of northeastern Utah is characterized by northwest and east-west trends with three significant highs and two prominent lows. The northwest trend contains the Sunnyside Tar Sands area and extends from north of Sunnyside to southeast of Crescent Junction. The east-west trend coincides with the Uinta Mountains.

The three significant highs include: a broad area south of Price associated with the large anticlinal system of the San Rafael Swell; the elongated high associated with the Uinta Mountains; and a high near Cisco that is part of the plunging nose of the Uncompahgre Uplift.

The two prominent lows include: the elongated low south­east of Crescent Junction which represents the Salt Valley gravity low caused by the low density evaporites in the core of the Salt Valley anticline; and the prominent Sunnyside low centered on Bruin Point and the Sunnyside Tar Sands area. This gravity low near Sunnyside contains a zone of subsurface faulting with up to 6000 feet of vertical displacement. The Uinta Basin is on the downthrown side. This fault lies east of Sunnyside and extends for ten miles to the northwest and about sixteen miles to the southeast.

Seismic

The seismic data in the Sunnyside area is from Tibbetts, et al (1966) and includes the following four points: (1) a northwest trending fault exists in the Sunnyside area and has a stratigraphic separation of about 2500 feet with relative movement up on the San Rafael side and down on the Uinta Basin side; (2) when extended to the southeast, along the northwestern regional structural trend, the trace of the fault passes into the area of Turtle Canyon (located off the lower portion of Range Creek in Sections 32 and 33, T17S, R16E) where there is

subsurface evidence of major faulting; (3) on Range Creek at the abandoned pump station (located about four miles east of the Sunnyside coal mine at an elevation of 7850 feet and 1500 feet upstream from Amoco Production Kaiser Steel No. 1, see Regional Map) the depth to the Paleozoic carbonates is about 12,000 feet and regional dip is about 4° NE into the Uinta Basin; and (4) the thickness of the sediments that overlie the Paleozoic carbonate reflector ranges from 4000 feet in Clark Valley to 12,000 feet in Range Creek. Clark Valley and Range Creek are about eleven miles apart. This difference in the depth to the Paleozoic carbonate reflector is equivalent to an average grade of fourteen percent for eleven miles.

, ^

21

GEOLOGY OF PROJECT AREA

Rocks in the Sunnyside Tar Sands area are well exposed along the 1000-1500 foot high Roan Cliffs. The tar sands are localized within a delta complex that formed near the shoreline of Lake Uinta during early to middle Eocene time, some 55-47 million years ago. The bitumen is mainly confined to multiple stacked intervals of sheet sands and channel sands that exist within the Green River Formation. These sandstones are quartz-feldspar rich and were derived by erosion of the Uncompahgre Uplift. The Sunnyside Tar Sands area contains an important northwest trending segmented flexure (Figures 2 and 3). The flexure and sandstone reservoir rocks have localized the distribution of the bitumen.

Structure

The Mt. Bartles-Bruin-Point area contains a segmented flexure associated with a large monoclinal dip slope. There is no structural closure in the project area. The flexure has divided the Sunnyside Tar Sands area into three different segments. The flexure has a subtle surface expression with specific structural evidence in limited and remote areas. The dips in the Bruin Point area of the Roan Cliffs are commonly 4-12°NE, while dips in the West Tavaputs Plateau are commonly 3-4°NE. The change in these dips was first documented during the 1986 field season while measuring sections in the West Tavaputs Plateau.

Mt. Bartles-Bruin Point Flexure

The structural evidence for this flexure can be separated into two parts: general and specific. The general evidence includes: northwest trending drainages and lineaments that parallel the regional northwest structural fabric as well as gradual changes in northeast dips associated with different segments of the flexure. The specific evidence includes: chaotic slump blocks, mini-anticlines, isolated linear troughs, anomalous dips, slickensides and pyrite veinlets.

General evidence: In late August, 1986 views from north of Mt. Bartles in Measured Section 37 located a distinct linea­ment in Sheep Canyon. This lineament with associated landslides was examined on foot in June, 1987. The area is characterized by anomalously high 30-90° dips within numerous large masses of chaotic blocks. These chaotic slump blocks represent debris that moved downslope. The area also contains multiple en-echelon 20-30 foot deep troughs elongated parallel to the trend of the flexure. This Sheep Canyon area represents the northern part of the flexure as shown in Figure 3, Regional Map and Geology Map. The southern part of the flexure follows the pronounced topographic lineament associated with the upper portion of Range Creek (see Photo 1, 1986 Geologic Summary Report)

22 >0V

Specific evidence: Six separate and isolated locations contain detailed structural evidence used to define the Mt. Bartles-Bruin Point segmented flexure. This evidence includes: chaotic slump blocks and associated linear troughs; mini-anticlines; isolated linear troughs; anomalous dips along the main axis of the flexure; slickensides; and northwest trend­ing pyrite veinlets. The subtle changes in dips of the flexure are best seen in views perpendicular to dip that look parallel to the axis of the northwest-southeast trending flexure. Without a near-perpendicular view the subtle changes in true dip merge almost imperceptibly into a continuous monocline with low apparent dip (see Photo 2, 1987 Geologic Summary Report) . This detailed field evidence of the flexure is noted in five places on the Geology Map. All but one are within T13S, R14E. In section 7, NE/4 two mini-anticlines exist and one is shown in Photo. 4 of the 1988 Geologic Summary Report. In section 17, NW/4 multiple thin northwest trending pyrite veinlets are exposed along a pronounced curvature of a creek bed. In section 20, NW/4 excellent slickensides were found along the base of a massive northwest trending joint (see Photo 8, 1987 Geologic Summary Report). In section 28, SE/4 anomalous dips (i.e., 8°W and SE instead of 4-7°NE) were mapped along poorly accessible exposures adjacent to creek bottoms. In section 1 (T13S, R13E) and section 36 (T12S, R13E) chaotic slump blocks and linear troughs are abundant with a 0.5 square mile area of Sheep Canyon.

The Mt. Bartles-Bruin Point flexure has divided the Sunnyside Tar Sands area into three different segments. Each segment is characterized by different dips and bitumen content (see Figure 3 and the Bruin Point Dip Section C-C. The eastern segment exists in the West Tavaputs Plateau and is characterized by 3-5° northeast dips and sandstones that con­tain 0-4wt% bitumen. The central segment is characterized by 4-7° northeast dips and sandstones that contain 4-7wt% bitumen. The western segment exists along the Roan Cliffs and is characterized by 4-12 northeast dips with sandstones that contain 4-12wt% bitumen. Thus, this northwest trending Mt. Bartles-Bruin Point flexure has gentle dips of 3-4° NE on the downthrown side and steeper dips of 4-12 NE on the up-thrown side. In addition tar sands with 4-12wt% bitumen persist in the upthrown side, while tar sands with 0-4wt% bitumen persist in the downthrown side. Clearly, the flexure has an important influence on the distribution of the bitumen content.

Structure Contour Map of Blue Marker

The segmented flexure is associated with a monoclinal dip slope or ramp that contains no closure as determined by the Structure Contour Map of the Blue Marker. The Blue Marker is the distinct marker horizon at the base of the Parachute Creek Member. Elevations of the Blue Marker from drill holes and

23 01163

measured sections were carefully tabulated to construct the Structure Contour Map of the Blue Marker. Data points from drill holes are considered accurate to within 1-2 feet. Data points from measured sections are considered accurate to within 5-10 feet.

The Structure Contour Map of the Blue Marker illustrates three important factors: (1) basic ramp structure with no closure (2) change in strike near Bruin Point (3) most drastic changes in dip coincide with area of mapped Mt. Bartles-Bruin Point flexure. Factor (1): A basic ramp structure is established by the uniform dips of the Blue Marker. The dip direction slopes downdip toward the Uinta Basin and updip toward the Roan Cliffs. The uniform spacing of the structure contours in the northeast portion of the Structure Contour Map indicate uniform dips of 3-4 degrees that steepen to uniform dips of 6-8 degrees toward the Roan Cliffs. Regional dips of the Blue Marker within the West Tavaputs Plateau and toward Nine Mile Canyon are N54°W, 2°NE. These more gentle dips toward the Uinta Basin were determined by a three point problem of the Blue Marker from outcrops in MS-29, upper Harmon Canyon and upper Prickly Pear Canyon. These three Blue Marker outcrops are essentially 26,000, 36,000 and 38,000 feet apart with a maximum elevation difference of 1155 feet for the Blue Marker. Factor (2): There is a noticeable change in strike of the structure contour lines near Bruin Point. From Bruin Point to Mt. Bartles the strike is N40°W. From Bruin Point to South Knoll the strike is N20°W. This change in strike is associated with a pivot area near Bruin Point and the thickest accumulation of tar sands (see Tar Sand Isopach Map). Factor (3): As an afterthought the location of the mapped Mt. Bartles-Bruin Point flexure was added to the Structure Contour Map. It is apparent that the distance between the 100 foot structure contour lines decreases (i.e., dip increases) as one approaches Bruin Point and Mt. Bartles from the Uinta Basin to the northeast. The area of most significant changes in dip (i.e., closer spaced contour lines) coincides with mapped portions of the flexure.

The Structure Contour Map vividly illustrates the lack of any closure centered on Bruin Point. Some closure was initially suggested by cross sections and eyeballing in the field. The Blue Marker in the Bruin Point area is near 10080 feet in elevation. The Blue Marker in the Mt. Bartles area (5 miles northwest of Bruin Point) and the South Knoll area (2 miles southeast of Bruin Point) are both near 9780 feet in elevation. This 300 foot difference in elevation is explained by the fact that the Blue Marker near Bruin Point is some 2500 feet updip from the Blue Marker at Mt. Bartles and South Knoll; this data equates to a dip of seven degrees that is characteristic of the western segment of the flexure.

24 c\\&\

Green River Formation

The area of the Sunnyside Tar Sands is confined to rocks within the Green River Formation and its three members that from top to bottom consist of the Parachute Creek Member, Garden Gulch Member and Douglas Creek Member (see Photo 2, 1981 Geologic Summary Report). These sediments formed early in the history of Lake Uinta. Their distribution within the Uinta and Piceance Creek Basins is shown in Figure 11. The sediments that formed late in the history of Lake Uinta belong to the Uinta Formation and saline facies (see Figure 11). The area of the Sunnyside Tar Sands has been projected twenty miles downdip to show its relative stratigraphic position within the Uinta Basin (see Figure 12).

In Figure 12 the cross section of the Uinta Basin illustrates that the stratigraphic terminology commonly used east and west of the Green River is different. The Green River has eroded a formidable canyon that geographically separates the Uinta Basin into a western and eastern portion (see Figures 11 and 12). The eastern Uinta Basin and the Piceance Creek Basin are locally grouped together, and the stratigraphic terminology for the Green River Formation developed by Bradley (1931) has been used throughout this eastern portion. Here the Green River Formation was separated into three members consisting of the Parachute, Garden Gulch and Douglas Creek Members. The rock units in the western Uinta Basin have two different sets of stratigraphic terminology for most of the Green River Formation. Figures 11-14 along with the following discussion help to clarify the somewhat confusing differences in the two sets of terminology that exist for the western Uinta Basin.

The first set of stratigraphic terminology in the western Uinta Basin was developed in the oil fields and includes the green shale facies, delta facies and black shale facies. The green shale facies roughly equates to the Garden Gulch Member. The delta and black shale facies roughly equate to the Douglas Creek Member. Carbonates dominated by micrites and biomicrites are scattered throughout the Green River Formation and help to differentiate the Green River Formation from the underlying Wasatch or Colton Formations that contain no carbonates (Picard, et al, 1973). The second set of terminology developed in the western Uinta Basin was introduced by Fouch (1975) and Ryer, Fouch and Elison (1976) . They define the stratigraphic units on the basis of open lacustrine, marginal lacustrine and alluvial lithologic assemblages with no reference to the Parachute Creek, Garden Gulch or Douglas Creek Members. The open lacustrine rocks were deposited in open lake environments and consist of organic rich claystones and carbonates. The marginal lacustrine rocks were deposited in deltaic, interdeltaic and lake-margin carbonate-flat environments and consist of sandstones, clay-stones and weakly indurated clay carbonates. The alluvial rocks were deposited peripheral to the marginal lacustrine environments.

25 01165

Within The Sunnyside Tar Sands area geological mapping in 1980 separated the rocks into the Parachute Creek, Garden Gulch and Douglas creek Members of the Green River Formation. Specific field criteria were used to distinguish these three members. After the Green River Formation was separated into these three members, it was realized that the Parachute Creek Member represents the lake or gray shale facies, the Garden Gulch Member represents the shore or green shale facies, and the Douglas Creek Member represents the delta or red shale facies. Once these three dominant facies were recognized, it became much easier to conceptualize the Sunnyside delta complex. These relationships are shown in Figures 13 and 14. Within the Sunnyside Tar Sands area the stratigraphic terminology has combined the two sets of different terminology in the western Uinta Basin with the standard terminology of the eastern Uinta Basin.

Parachute Creek Member

The Parachute Creek Member is insignificant as a reservoir for tar sands and contains less than five percent of the bituminous sandstones in the entire Sunnyside Tar Sands area. However, the Parachute Creek Member is the most important member for stratigraphic correlation within the project area. It contains five significant markers which are the Wavy Bedded Tuff, Mahogany oil shale, R-5 oil shale, lower tuff and Blue Marker. Since the beginning of the project in 1980 the Parachute Creek Member was recognized and mapped on the basis of undifferentiated oil shale units and thin laminated buff to olive gray shales. For many years the Parachute Creek Member continued to receive little attention since it contained in­significant quantities of bituminous sandstones. However, five significant markers within the Parachute Creek Member have now been established due to extensive field mapping on peripheral hydrocarbon leases in the West Tavaputs Plateau during 1986 and 1987 as well as from detailed logging of about 4000 feet of Parachute core from eleven drill holes during the 1988 drilling season. The consistent stratigraphic position of these five markers is shown in Figure 15. The distribution of the Wavy Bedded Tuff, Mahogany oil shale (R-7), R-5 oil shale and Blue Marker (R-2) are noted on the Geology Map and five cross sections.

The thickness of the Parachute Creek Member depends on its location in the Sunnyside Tar Sands area. Along the Roan cliffs within the Dry Canyon and Whitmore Canyon areas the Parachute Creek Member is eroded away. Along the Roan Cliffs south of Bruin Point the Parachute Creek Member averages about 100 feet thick, while just east of Range Creek it averages about 400 feet thick. In areas of the West Tavaputs Plateau it is 300-700 feet thick. The maximum drilled thickness of the Parachute is 677 feet in RCT-13. The true thickness of the

26

Parachute Creek Member is not known, as the Horse Bench Sandstone which exists above the top of the Parachute Creek Member has not been defined in the Sunnyside Tar Sands area. Excellent and almost continuous exposures of the Parachute Creek Member exist in a minor drainage about 1700 feet northeast of drill hole CD-2.

Wavy Bedded Tuff

Numerous scattered outcrops of the two foot thick Wavy Bedded Tuff exist in the West Tavaputs Plateau and occur near the upper topographic limits of the Parachute Creek Member. Good exposures are located at the vehicle accessible drill pad of Pan American Nutter Corporation No. 1 (Photo 3, 1988 Geologic Summary Report), Numerous outcrops also exist along the top of the cliff face near MS-56 and MS-53 (see Photo 4 of this report). The Wavy Bedded Tuff was first recognized in the project area at the end of the 1987 field season within MS-56. At the beginning of the 1988 field season it was recognized in MS-57 and later in numerous locations throughout the Mt. Barties area and the Bruin Point area east of Range Creek. During the 1989 field season extensive outcrops of the Wavy Bedded Tuff were easily recognized and mapped in the West Tavaputs Plateau (see Geology Map).

The Wavy Bedded Tuff outcrops as a resistant volcanic air fall tuff within the open lacustrine shales of the Parachute Creek Member. Outcrops are scarce but resistant rock frag­ments of the tuff commonly exist on gentle slopes that mantle the Wavy Bedded Tuff. The resistant volcanic rock fragments have a distinct red to orange color and a unique physical characteristic. Thumb sized cavities of weathered out ash fragments range in size from 0.6-1.0 inches in diameter (see Photo 4 of this report). The weathered rock has a color of grayish orange (10YR 7/4) to grayish yellowish orange (10YR 8/2) to yellowish gray (5Y 8/1). Within the lower six inches of the tuff bed fresh biotite grains make up 10-15% of the rock. The black medium sized grains (range fU-cL) of biotite are readily apparent. Once the field criteria for recognition were established, the Wavy Bedded Tuff became relatively easy to locate but still requires knowledge of its stratigraphic position and careful scrutiny. The Wavy Bedded Tuff exists 35 feet above the Mahogany oil shale (see Figure 15) and its presence is critical for the positive field identification of the Mahogany oil shale. The Wavy Bedded Tuff is easily recognized in outcrop or drill core, but has a weak to indistinguishable gamma ray and density log response.

01167 27

Three samples of the Wavy Bedded Tuff have an average age date of 47.0 ± 1.8my (see 1988 Geologic Summary Report for details) . The source area for the Wavy Bedded Tuff is some 350 miles to the north within the Absaroka Mountains, near Yellowstone National Park, Wyoming.

Mahogany Oil Shale (R-7)

The Mahogany oil shale crops out in numerous locations to the east of the main axis of the Mt. Bartles-Bruin Point flexure. The twenty foot thick Mahogany oil shale exists thirty-five feet below the Wavy Bedded Tuff and outcrops as an oil shale doublet with paper shale textures immediately above the brown cliff in the distal portions of the Sunnyside delta complex. Six drill holes east of Range Creek and three drill holes near Mt. Bartles firmly establish its vertical. position thirty-five feet below the Wavy Bedded Tuff. The density well log of the Mahogany oil shale has a characteristic pattern of three nearly equal prongs that from peak to peak form a nearly vertical line with a steep positive slope as seen in Figure 16, The low density prongs are caused by intervals of rich oil shale. The Mahogany oil shale is recog­nized in six measured sections and forms an important marker in the West Tavaputs Plateau.

The oil shales in the Sunnyside Tar Sands area represent a compressed version of the oil shales in the Piceance Creek Basin by a magnitude of four. In the Sunnyside Tar Sands area the oil shales from the Mahogany (R-7) to the Blue Marker (R-2) encompass a vertical distance of nearly 300 feet (see Figure 15). In the Piceance Creek basin 100 miles to the east of Bruin Point (see Figure 11) the oil shales from the Mahogany (R-7) to the Blue Marker (R-2) encompass a vertical distance of nearly 1200 feet (see Figures 17 and 18). In the Piceance Creek Basin the Green River Formation contains alternating rich and lean oil shale units that are largely confined to the Parachute Creek Member and have been used for stratigraphic correlation (Ziemba, 1974, and Figure 17). The various rich (R) and lean (L) zones of oil shales are noted in Figures 17 and 18. The rich and lean zones were defined on the basis of oil shale assay histograms and no field criteria are recognized to distinguish any particular rich and lean zone (personal communication, Bill Cashion, November 1987). The detail of the R-l through R-6 oil shale intervals is given in Figure 18; R-7 corresponds to the Mahogany zone and R-8 refers to the multiple thin oil shale intervals in the upper oil shale zone above the Mahogany zone (Figure 19). The Mahogany oil shale formed -48 my ago as determined by sedimentation rates calculated between the Wavy Bedded Tuff (47 my) and the lower tuff (51.45 my) as noted in the Lower Tuff Section, Parachute Creek Member. Mauger (1977) indicates the Mahogany oil shale formed between 45-46 million years ago.

28 01168

The richness of oil shale can be determined qualitatively by a kerogen color index or quantitatively by density well logs. Oil shale content increases with the intensity of brown color as determined by detailed core logging and use of the GSA Rock Color Chart (Goddard, et al, 1963). The re­sults are as follows:

Color ___ Hue and chroma Kerogen content

very pale orange 10YR 8/2 very lean pale yellowish brown 10YR 6/2 lean dark yellowish brown 10YR 4/2 moderate disky yellowish brown 10YR 2/2 rich

Some of these color distinctions are shown in Photos 5 and 7. Quantitatively increased kerogen content is reflected by decreased formation density. Density log values were related to assay yields by Tixier and Curtis (1967) with the linear equation:

yield(gpt) - 154.81-59.43 x log density(g/cc)

With this equation a density of 2.0 = 36gpt; 2.1 = 30gpt and 2.2 = 24gpt. Using this equation and density values from drill logs in the Sunnyside Tar Sands area the twenty foot thick Mahogany zone averages lOgpt with maximum values near 15gpt.

The purpose of this paragraph is to clarify Mahogany oil shale terminology of the Piceance Creek Basin as summarized from Donnell (1961), Cashion (1967), Dyni (1974), and Stanfield, et al (1960). The Mahogany name is derived from the fact that polished surfaces of dark gray oil shale resemble old mahogany wood. The Mahogany ledge is a 2-60 foot thick outcrop of rich oil shale beds that commonly form a cliff. The top and bottom of the Mahogany ledge are bounded by lean oil shale which weather more rapidly than rich oil shales. These lean oil shales create weathered indentations or grooves into the cliff and gave rise to the terminology of A-groove (top weathered groove) and B-groove (bottom weathered groove). The subsurface equivalent of the Mahogany ledge is the Mahogany zone. Resistivity well logs through the Mahogany zone show that low resistivity values are characteristic of lean oil shale while high resistivity values are associated with rich oil shales. Thus, within the Piceance Creek Basin the A-groove and B-groove patterns have an expression in both the surface and subsurface.

In the Sunnyside Tar Sand area weathered outcrops of the Mahogany ledge do not express A- and B-grooves. The ten drill holes that cored through the Mahogany zone had fluid levels below the Mahogany so resistivity data is not available. Drill core does show that the top and bottom of R-7 as well as R-5 oil shale intervals are characterized by lean oil shale and/or marlstone IFC's.

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R-5 Oil Shale

The R-5 oil shale is an important local marker within the Sunnyside Tar Sands area and has more extensive exposures and drill core/well log intercepts than the R-7 oil shale. The R-5 oil shale is located 145 feet below the Wavy Bedded Tuff, 90 feet below the Mahogany oil shale and 190 feet above the Blue Marker as shown in Figure 15. Numerous exposures of the R-5 oil shale exist some 1000 feet downdip from Bruin Point in the road above drill hole A--42 and also near the road between drill holes A-ll and A-8.

The R-5 oil shale zone is commonly twenty feet thick and outcrops as an oil shale doublet. This doublet can readily be confused with the doublet of the Mahogany R-7 oil shale unless stratigraphic position or well log criteria are applied. The density well log of the R-5 oil shale has a characteristic pattern of three unequal prongs that from peak to peak form a line with a moderate negative slope as seen in Figure 20. The density well log pattern of the R-5 oil shale (Figure 20) is distinct from the density well log pattern of the Mahogany R-7 oil shale (Figure 16). Prior to the definitive data from the 1988 drilling program the R-7 (Mahogany) and R-5 oil shales were often mistakenly .identified. For example, Photo 4 (1986 Geologic Summary Report) illustrates the R-5 oil shale, not the Mahogany as stated in the 1986 Report. Also in Figure 22 (1987 Report) the indicated Mahogany intervals in MS-32 and Amoco No. 63 both represent the R-5 oil shale.

The R-5 and R-7 oil shale intervals have some common characteristics. They both outcrop as an oil shale doublet. Drill core from moderate to rich oil shales in both the R-5 and R-7 intervals often contain wiggly vertical patterns 0.1" in diameter that have been squeezed and compacted by soft sediment deformation. These wiggly vertical patterns represent either distorted vertical worm burrows or deformed sediment-filled syneresis cracks (i.e., intrastratal shrinkage cracks). The R-5 oil shale has A- and B-groove patterns in resistivity logs within drill hole CD-I. Thus the A- and B-groove concept is not unique to the R-7 oil shale and may be common to various oil shale intervals.

At high elevations in the Sunnyside Tar Sands area the various springs are confined to the Parachute Creek Member and commonly associated with oil shale intervals. The location of these springs is important as they represent the only source of water for drilling. Springs are often located just above oil shale intervals (Ertl, 1967) The oil shale commonly serves as a confining bed or aquiclude. Near Bruin Point the olive gray shales above and below oil shale intervals are generally well jointed and, therefore, permeable. The ground­water preferentially passes through these well jointed beds

30

until it reaches a confining bed and then passes downslope or upslope under pressure until it reaches a topographic outlet to form a spring. In the Mt. Bartles area the Stone Cabin Spring ("15,000 gpd) is located slightly above the R-5 oil shale. In the Bruin Point area the North Spring (-15,000 gpd) and the South Spring (~125,000 gpd) are both located some 50 feet above the R-2 oil shale. In drill hole A-14 significant artesian flow was encountered just above the R-2 oil shale.

Lower Tuff

This biotite-rich tuff is 0-16 inches thick, sometimes found in drill core and rarely found in outcrop. The lower tuff is located 215 feet below the Wavy Bedded Tuff, 50 feet below the base of the R-5 oil shale and 140 feet above the Blue Marker (R-2) as seen in Figure 15. The initial position of this lower tuff was established in drill holes BP-lA and RCT-12 by detailed logging of core which located this one inch thick biotite-rich tuff. When MS-29 was re-examined shallow digging 50-60 feet below the base of the uppermost oil shale (R-5) located a one foot thick biotite-rich tuff.

Age dates from the fresh biotite in the lower tuff are 51.5±2.0 my from MS-29 and 51.4±2.0 my from BP-lA (see 1988 Geologic Summary Report for additional details). The lower tuff (51.45 my) is separated from the Wavy Bedded Tuff (47.0 my) by 215 feet of sediments, chiefly shales. Both these biotite-rich tuffs represent time-stratigraphic units. Thus between these two tuffs 215 feet of sediments were deposited in 4,450,000 years. Average rates of sedimentation are equivalent to almost 5 feet per 100,000 years, 1 ft per 20,000 years, 6" per 10,000 years, 3" per 5000 years or 0.06" per 100 years (i.e., 1.5mm per 100 years).

Blue Marker

The Blue Marker is the most distinctive, widespread and useful marker in the project area and consists of two important parts: oil shale and algal coal. In outcrop the Blue Marker is recognized by a 1-3 foot thick oil shale interval (R-2) that weathers into thin slabs which are frequently located slightly downslope from the outcrop and are called dinner plates. The weathered surface of these dinner plate slabs highlights numerous small disarticulated fossil fish fragments. This is the only oil shale interval that contains abundant fossil fish fragments. In addition one to two feet below the dinner plate oil shale there is a 0.5-1.5 inch thick coal seam of algal origin. The dinner plate oil shale and algal coal seam are part of the Blue Marker that is widely recognized in both outcrop and core. Photo 6 shows the Blue Marker in outcrop, while Photo 7 shows the Blue Marker in core. The Blue Marker is easily recognized in downhole gamma ray logs as seen in Figure 21 and also in surface gamma ray logs as seen in the strip log of MS-59 (see 1988 Geologic Summary Report, Volume III).

31 01171

During the 1980's this distinctive Blue Marker was recog­nized under different names by various geologists involved with the project. Initially it was an unnamed marker near the base of the Parachute Creek Member and utilized by John Rozelle in correlation of well logs for mine modelling. Drill hole data of Mono Power recognized this distinctive marker as the RC marker noted in numerous RCT (Range Creek tract) drill holes. Amoco's field mapping and drill hole data all recognize the same marker at the base of the Parachute Creek Member. The regional significance of the distinctive marker and its equivalence to the Blue Marker in the Piceance Creek Basin were first recognized after integration of data from the 1987 field season.

Comparisons of well logs from Amoco's Sunnyside Tar Sands project and Amoco"s Rio Blanco Tract C-l project show nearly identical doublet patterns of gamma rays near the base of the Parachute Creek Member (Figure 21, 1987 Geologic Summary Report). This doublet pattern has the same characteristic peaks and troughs in the log pattern over tens of miles of separation. The characteristic configuration and position of this doublet pattern relative to the Blue Marker is shown in Figure 21, this report. This widely recognized marker in the Sunnyside Tar Sands area is equivalent to the Blue Marker as used by Dyni (1969) and Ziemba (1974) within the Piceance Creek Basin. The Blue Marker has been utilized to establish the stratigraphic position of the Sunnyside Tar Sands within the Uinta Basin as shown in Figures 11 and 12.

The Blue Marker is found near the characteristic color change in shales of the Parachute Creek and Garden Gulch Members. The shales of the Parachute Creek Member are dominantly light olive gray with a rock-color designation (Goddard, 1963) of 5Y 6/1 to 6/2. The shales of the Garden Gulch Member are dominantly greenish gray with a rock-color designation of 5GY 6/1. These color differences are recognizable in outcrops and drill core.

The base of the Blue Marker contains a nearly ubiquitos 0.5-1.5" coal seam that is readily recognized in drill core and measured sections. When this thin coal seam does not outcrop, shallow digging usually does not locate it. Fossil rootlets have not been seen near this thin coal seam, but live roots from present vegetation are common and often grow abundantly within this thin coal seam. This thin coal seam is a unique part of a distinctive marker and has been selected as the finite limit of the Blue Marker. Knowledge about the coal from the Blue Marker would greatly enhance environmental interpretations of conditions that prevailed during early Parachute Creek time.

01H2 32

Five thin sections were made of the coal from the Blue Marker in three widely spaced drill holes of the 1988 explora­tion program (i.e., CD-2, A-64 and A-68). Microscopic algal structures exist within the coal seam of the Blue Marker. Algal structures associated with coal are best seen with a petrographic microscope using converging light and magnifica­tion of 100-450 times on thin sections that are cut across bedding planes. Thin sections cut parallel to bedding planes have revealed nothing. Crossed nicols are helpful to see algal layering that is commonly 0.01-0.125mm thick. In thin section algal laminae are 0.01-0.02mm high, while algal pods are commonly 0.2-0.3mm in diameter. The color of the algal material is between light brown (5YR 5/6) and dark yellowish orange . (10YR 6/6). The coal laminae are commonly 0.02-0.03mm thick. Most of the coal is amorphous and contains no particles with structure. Microscopic sized pyrite and fine aggregates of calcite are often associated with the coal.

Thin section CD-2-BM (Blue Marker @ 448.3 ft) contains algal laminae with micro stromatolitic growth layers 0.01mm high that exist within coal laminae 0.01-0.03mm thick. There are numerous cross sections of singular circular pods that are 0.125mm in diameter. One oval shaped calcite-rich pod (0.75mm x 1.66mm) contains concentric growth layers 0.01mm thick. Thin section A-64-BM (Blue Marker @ 570.5 ft) contains a cluster of four large and four small circular to elliptical pods up to 0.4mm diameter with concentric growth layers 0.01mm thick; the 0.1-0.2mm center is commonly replaced by minute calcite crystals. The thin section views of these various pods are cup-like and similar to those shown in Figure 22. This thin section data suggest the algae within the Blue Marker is BOTRYOCCUS BRAUNII. The latter is a green algae which has a green growing stage with an orange resting stage; it is high in waxy hydrocarbons typical of boghead coals (Swain, 1981).

The coal from the Blue Marker contains numerous algal struc­tures, is of algal origin and represents a boghead coal. Stack, et al (1982) indicate that two types of coal exist and are either humic (herbaceous and wood derived) or sapropelic (algal or spore derived). Algal coal is known as boghead coal while coal derived from spore is known as cannel coal (Theissen, 1925). The thin coal seam of the Blue Marker formed in shallow shoreline lacustrine or algal marsh environments that existed during the beginning of a major transgressive event (i.e., expansion of Lake Uinta) in early Parachute Creek time. The vertical proximity of the algal coal and R-2 oil shale also suggests the oil shale was formed in shallow water.

01173 33

Garden Gulch Member

The Garden Gulch Member contains: (1) roughly forty percent of the tar sands; (2) the carbonate interval; and (3) an abundant fossil assemblage. The Garden Gulch Member represents a shore facies that formed in marginal lacustrine environments. This member is characterized by numerous bituminous sandstones, abundant fossiliferous limestones, massive poorly bedded greenish gray shales and thinly bedded mixed colored shales.

The carbonate interval averages seventy feet thick and can be divided into an upper, middle and lower part (see Figure 23). The upper part consists of the twenty-five foot thick Zone 25 that is ostracod-rich. The top of Zone 25 is characterized by a prominent gamma ray peak of 500-600 API units. A one to six inch carbonaceous interval commonly exists above the top of Zone 25 and may be the cause of this prominent gamma ray kick. The twenty foot thick middle part is dominated by light greenish gray shales that are partly bio-turbated. The lower part consists of the twenty-five foot thick ostracod-rich Zone 26 and contains no prominent gamma ray peaks. Near the Roan Cliffs the carbonate interval is 50-60 feet thick. In the West Tavaputs Plateau the carbonate interval is 70-120 feet thick. The carbonate interval is a biostratigraphic unit and persists with good definition through­out the entire Sunnyside Tar Sands area. It can be used to determine stratigraphic position in both the surface and sub­surface. The vast majority of the tar sands exist below this carbonate interval (see Figure 13).

The limestones within the carbonate interval weather to a characteristic light brown (5YR hue-5/6chroma) to grayish orange (10YR-7/4) to color and are recognizable from a distance (see Photo 8). The term micrite is used for a carbonate mud, while the term biomicrite represents a carbonate mud with ten to seventy-five percent biota. The volume of limestones are about half micrite and half biomicrite. Limestone intervals commonly have the biomicrite on top and the micrite on the bottom. The biomicrite contains intervals with abundant algal stromatolites and massive ostracod beds. Beds with more than seventy-five percent ostracods are coquina-like and represent grainstones. Some algal-rich beds are boundstones and consist of thin multiple algal laminae or thick masses of spherical algal heads. The flat laminated micrite zones are locally cracked, curled or buckled and form tepee-like structures. Tepee structures were classically interpreted to have formed in peritidal marine environments (Asserato and Kendall, 1977).

The top of the carbonate interval, or top of zone 25, is commonly located 250 feet below the Blue Marker (see Figure 23). No oil shales have been located within the

34 on™

Garden Gulch Member. The Orange Marker that exists below the Blue Marker in Figure 17 has not been recognized in the project area. The Orange Marker roughly correlates with the widespread Carbonate Marker of the Uinta Basin (Johnson, 1985, and Fouch, et al, 1976). In the Sunnyside Tar Sands area the Orange Marker/Carbonate Marker may be equivalent to the prominent gamma ray kick at the top of Zone 25.

The Garden Gulch Member contains the most significant fossil assemblages within the Sunnyside delta complex. The limestones contain numerous intervals of ostracods, algal laminated sediments and algal heads. The most prominent algal head zone exists in MS-41 at the base of Zone 32. Here a three foot interval with large algal heads is well-exposed along the jeep road that follows the crest of ridge to the west of the upper drainage of the Right Fork of Whitmore Canyon (see Geology Map). Black garpike fish scales and turtle bone fragments are common in local intervals. Rare occurrences of gastropods, turtle plates and flora (mainly palm fronds and woody fragments) occur in the Garden Gulch Member.

Ostracods are the most abundant biota within the lime­stones of the carbonate interval as well as in the limestones below the base of nearly every bituminous sandstone. Ostracods are abundant in sublittoral environments and commonly indicate paleoshorelines.

Ostracods are microscopic benthic crustaceans that moult their bivalve shells eight times during their lifetime and each time a larger carapace replaces the previous one (DeDeckker and Forester, 1988). In Zones 25 and 26 the largest ostracods are commonly 0.5-1.Omm in length and 0.25mm wide. Detailed examination with a ten power hand lens indicates there is a normal distribution of population sizes from juvenile to adult ostracods whose bivalves have remained mostly articulated. This type of population distribution indicates no winnowing or redistribution of shell sizes and suggests low energy conditions prevailed in both life and death assemblages (Whatley, 1988). Within Zones 25 and 26 numerous ostracod coquina beds are frequently 1-3 feet thick and almost wholly composed of ostracod shells (see Photo 8). Aspects of moulting and population distribution make one realize that the ideal population is only a small fraction (i.e., 1/8) of the number of ostracod shells The ostracod shell repre­sents a thick carapace of low Mg calcite that consists of a laminated chitin-protein complex; analysis of these shells and the Sr/Ca ratio can be used to determine paleosalinity and paleotemperatures (Neale, 1988) . Ostracod populations are greatly affected by changes in water level (i.e., multiple transgressions and regressions of Lake Uinta), salinity, water composition and temperature (DeDeckker and Forester, 1988).

35 on

Ostracods can be separated into marine, brackish and fresh water taxa. Swain (1964) has described six fresh water ostracod zones (plus a barren zone) within the Uinta and Piceance Creek basin. The barren zone commonly exists between the Mahogany oil shale and the Blue Marker. Within the Sunnyside Tar Sands area no ostracods are found within the Parachute Creek Member. Within the Uinta Basin Hemicryprinotus watsonensis is the most abundant ostracod species and frequently forms coquinas several feet thick (Swain, 1964). Based on index photographs of catalogued ostracods, the ostracods in the coquina beds of Zones 25 and 26 are suggested to be Hemicryprinotus watsonensis. Knowledge of ostracod paleo-ecology also helps to understand the nature of the cyclic deposition of limestones.

The colored shales associated with the Garden Gulch Member are distinctive. The abundant massive green shales have a distinct greenish gray (5GY 6/1) color and are readily apparent in the field. The greenish gray shales were deposited in shallow oxygenated waters. The mixed colored shales include shales of purple, olive gray, greenish gray and reddish brown colors and were deposited under alternating wet and dry condi­tions associated with shallow water bay-like environments. The colors formed during long time intervals after deposition. The transitional contact between the base of the Garden Gulch and the top of the Douglas Creek is usually near Zone 35 (see Figure 13). This Tgg/Tgd transitional contact exists between mixed colored shales (bay environments) and red shales (marsh environments).

The true thickness of the Garden Gulch Member depends on its location in the Sunnyside delta complex. Proximal portions near the Roan Cliffs are commonly 200-400 feet thick. Distal portions in the West Tavaputs Plateau near Dry Creek Canyon and South Ridge are commonly 600-800 feet thick. As seen from Figure 13 and Table 4 the average thickness of the Garden Gulch Member along the Roan Cliffs is roughly 500 feet.

Douglas Creek Member

The Douglas Creek Member contains roughly sixty percent of the tar sands in the entire Sunnyside deposit. This member represents the delta facies and is dominated by red shales, thick bituminous sandstones and thin limestones below the base of most sandstones. This member contains thick bituminous sandstones along the Roan Cliffs that thin downdip toward the West Tavaputs Plateau.

The red shales and limestones within the Douglas Creek Member are important lithologic factors and help to define marsh and near-shore environments. Red shales coupled with carbonized and pyritized plant fragments help define the marsh

36 01176

environment. Thin coal lenses and rare log fragments exist within portions of this member and are exposed in the north pit of the Asphalt Mine. The coal formed in transitional areas between marsh and distributary channel environments. The limestones consist of algal and ostracodal zones. The algal zones range from one to three feet thick with single algal heads one to two feet across. These thin but prominent algal stromatolite zones attest to minor lake transgressions. Zones of ostracodal limestones one to five feet thick exist within all portions of the Douglas Creek Member. On the surface these ostracod zones have a white oolitic texture caused by combinations of wave agitation at the lake shore­line, carbonate overgrowths and weathering. Swain (1964) noted that calcite overgrowths are present on some ostracod bivalves and form oolitic textures. The lower ostracod zones help to establish control on the lower limits of the Douglas Creek Member.

The Wasatch and Colton Formations are stratigraphically below the Green River Formation (see Figures 9 and 10). The Colton Formation is used in areas that are underlain by the Flagstaff Limestone (see Figures 10 and 12). The Wasatch Formation is of continental origin. The Green River Formation is of lacustrine origin. The placement of the Green River/ Wasatch conformable contact differs among geologists. In the Sunnyside Tar Sands area Holmes, et al (1948) placed this contact at the beginning of the red beds near 9600 feet in elevation adjacent to drill hole GN-3 and the top of MS-45 (see Geology Map). Many other geologists have followed the format of Holmes, et al (1948) and place the tar sands within the Wasatch Formation. I believe the contact near 9600 feet represents the Garden Gulch/Douglas Creek contact not the Green River/Wasatch contact. Murany (1964) states that ostracodal-oolitic limestones are a characteristic of the lower black shale facies and all limestones that outcrop in the Sunnyside Tar Sands area are part of the Green River Formation. In Water Canyon, below the Asphalt Mine, various limestone units exist down to elevations of some 8400 feet. The limestones are of lacustrine origin and are considered part of the Green River Formation. The Douglas Creek Member exists between elevations of 9600-8400 feet and is 1200 feet thick. The bituminous sandstones stop at about 8800 feet in the vicinity of the Asphalt Mine. The upper 800 feet of the Douglas Creek Member is bituminous and the lower 400 feet is nonbituminous. In the middle portions of Water Canyon exposures of the Wasatch Formation are roughly 800 feet thick and exist at elevations between 7600-8400 feet. In the eastern portion of the Uinta Basin at Raven Ridge (Figure 11) the Wasatch Formation is 850 feet thick (Murany, 1964) .

on71

37

All tar sands in the Bruin Point area are located within the Green River Formation and mainly confined to the upper half of the Douglas Creek Member and the Garden Gulch Member. In distal portions of the Sunnyside delta complex tar sands within the Douglas Creek Member are limited. In the West Tavaputs Plateau the Douglas Creek Member commonly exists below the base of saturation and thus contains only non-bituminous sandstones.

Sunnyside Delta Complex

The Sunnyside lacustrine delta is a sequence of laterally continuous, vertically stacked bituminous sandstones alter­nating with red, green and gray shales of the Green River Formation. The delta complex contains three subdeltas and consists of fluvial, deltaic, marsh, bay, beach and nearshore deposits that formed at the margin of ancient Lake Uinta. The delta system is well-exposed along the Roan Cliffs over heights of 500-1500 feet for distances of 7-9 miles along depositional strike. The delta system is partially exposed within Range Creek and Dry Creek Canyon for distances of 2-5 miles down depositional dip. These extensive exposures offer an excellent opportunity to examine a lacustrine delta complex.

The arbitrary limits of the Sunnyside delta complex are confined to the distribution of tar sands. Its boundaries are defined by tar sands with MSAT's totalling at least 50 feet. MSAT represents the total footage of main saturated zones that are at least ten feet thick and contain at least ten gallons of bitumen per ton. The numerous bituminous sandstone deposits represent distributary channel, distributary mouth bar and beach deposits that form relatively continuous sheets of bituminous sandstones. The lateral continuity of these sandstone deposits is caused by a combination of factors that include: (1) bifurcating distributary channel deposits, (2) shoaled distributary mouth bars and (3) reworking of the distributary mouth bars by waves and longshore currents to form beach and nearshore sandstone deposits.

The Sunnyside delta complex has been divided into three subdeltas that include the Bruin Point, Dry Canyon and Whitmore Canyon subdeltas (see Tar Sand Isopach Map). The Sunnyside delta has been separated into these three subdeltas on the basis of field expression, lithology, tar sand distribu­tion and environments of deposition. An understanding of this delta complex and its subdeltas helps to comprehend the distribution of the tar sands.

The Sunnyside delta complex was formed in river-delta-beach-nearshore environments associated with the margins of Lake Uinta during Eocene time some 57-47 million years ago. The shoreline or depositional strike was parallel to the

38 oO-

Roan Cliffs and oriented N40-50°W. The tar sands are distributed along depositional strike for seven to nine miles and along depositional dip for two to five miles. The main drainage that formed the delta complex flowed northeast into Lake Uinta.

During its development the Sunnyside delta complex experienced two major prograding phases and one major trans-gressive phase in addition to multiple minor regressions (low lake-level stage) and transgressions (high lake-level stage). The first major prograding phase occurred in Douglas Creek time when massive volumes of fine grained sand slowly prograded into Lake Uinta; this phase was largely confined to the Bruin Point subdelta. The second major pro-grading phase occurred during Garden Gulch time when massive volumes of fine grained sand again slowly prograded into Lake Uinta; this phase was largely confined to the Dry Canyon and Whitmore Canyon subdeltas. The major transgressive phase occurred during Parachute Creek time when Lake Uinta continued to grow in size and advanced over the entire Sunnyside delta complex.

Numerous minor transgressions and regressions formed cyclic deposition throughout the history of the Sunnyside delta complex. At least eleven to fifteen cycles exist and consist of repetitions of sandstone-shale-limestone-unconformity sequences. Each cycle begins with sandstone deposition, is followed by shale deposition, then limestone deposition and ends with an unconformity. From sandstone to shale to lime­stone each cycle represents a fining upward sequence. The sandstones and shales are relatively thick units, while the limestones are thin units. The contacts of sandstone-shale and shale-limestone intervals are normally gradational but can be abrupt. A relatively flat unconformity (erosion surface) exists on top of the limestone units. These repeated cycles formed from alternating wet and dry climatic cycles and resulted in multi-stacked lithologic sequences in the vicinity of Bruin Point. Each cycle has a combined thickness of some fifty to one hundred-fifty feet. The sandstones formed during rela­tively wet conditions, and the limestones formed during relatively dry conditions.

The lithology of the Sunnyside delta is based on detailed compilations of 41,947 feet of logged core from 49 drill holes located in the western segment of the flexure (see Table 4). The totals are: 36.2% sandstone, 10.5% siltstone, 44.8% shale; 6.9% limestone; 1.6% conglomerate; and trace volcanics.

Within the Sunnyside delta complex the stratigraphic position of large volumes of sandstones suggests that the Bruin Point subdelta is the oldest and the Whitmore Canyon

39 oi^ 9

subdelta is the youngest. In the Bruin Point subdelta the bituminous sandstones are largely confined to the Douglas Creek Member. In the Dry Canyon and the Whitmore Canyon subdeltas the bituminous sandstones are largely confined to the Garden Gulch Member.

Bruin Point Subdelta

The Bruin Point subdelta is characterized by four to fifteen zones of bituminous sandstones with consistent bitumen content and represents the primary center of deposition. The tar sands are localized within a 600-800 foot thick zone near the Roan Cliff face that thins over a distance of two miles to a 200 foot thick zone in the vicinity of Range Creek (see Roan Cliffs Strike Section A-A' and Range Creek Strike Section B-B1). The Bruin Point subdelta contains about seventy percent of the total mineable tar sands. The tar sands are associated with distributary channels, distributary mouth bars and beach-bar deposits (see Figure 13). The thickest tar sands exist beneath Bruin Point (see Tar Sand Isopach Map). Large areas of cumulative MSAT's (main saturated zones) up to 300-700 feet thick are localized in the area between the Roan Cliffs and Range Creek. The Bruin Point subdelta was the area of principal investigation in 1978, 1980, 1981 and part of 1988. Twenty-one measured sections have been completed in proximal, medial and distal portions of the Bruin Point subdelta. Thirty-three of sixty deep (i.e., those that penetrate base of saturation) Amoco drill holes and fourteen deep Mono Power drill holes (relogged in 1987 and 1989) have been completed in the Bruin Point subdelta.

The Bruin Point subdelta has a large arcuate or lobate shape as seen on the Tar Sand Isopach Map. The cause of this lobate shape is suggested to be from extensive sediment influx and partial modification by waves in the shore margin of Lake Uinta. The Bruin Point subdelta is considered to be fifty to seventy-five percent fluvial-dominated and twenty-five to fifty percent wave-influenced.

The overall lithology of the Bruin Point subdelta was completed to determine trends of lithology within the subdelta. It is based on 30,397 feet of Amoco drill core (1980-1988 data base that combines all data without distinction of flexure position or mining areas). The overall lithology is: 30.7% sandstone; 11.0% siltstone; 50.0% shale, 6.7% limestone; 1.5% conglomerate; and trace amounts of volcanic tuffs (see Table 4, 1988 Geologic Summary Report). The siltstones and conglomerates are commonly associated with the sandstones. If the lithology is tabulated by delta, shore and lake facies, changes in the percent sandstone, shale, limestone and siltstone-conglomerate are dramatic as listed below:

01180 40

Bruin Point Subdelta (All Segments of Flexure)

Lithology Delta Shore Lake (Tgd) (Tgg) (Tgp)

%SS 53.8 24.9 6.7 %SH 27.9 52.5 83.7 %LS 1.6 11.0 2.3

%SL & %CG 16.7 11.6 7.1

The Bruin Point subdelta can also be examined by separating it into a central area and a south area as well as confining it to the western segment of the flexure (i.e., that area that will be mined between the Roan Cliffs and Range Creek). The Bruin Point subdelta was separated in this manner to determine trends of lithology for mining and project evaluation (see Table 4, this report).

Central Area, Western Segment of Flexure Bruin Point Subdelta

Lithology Delta Shore Lake (Tgd) (Tgg) (Tgp)

%SS 54.1 23.9 2.0 %SH 27.6 52.7 87.5 %LS 1.7 11.3 3.4

%SL & %CG 16.6 12.1 7.1

South Area, Western Segment of Flexure Bruin Point Subdelta

Lithology Delta "Shore Lake (Tgd) (Tgg) (Tgp)

%SS 55.2 30.7 12.9 %SH 28.0 49.2 72.7 %LS 2.0 11.2 6.8

%SL & &CG 14.8 8.9 6.8+0.8 vole.

The trends of these three short tables are the same. The sandstone content decreases rapidly from delta to shore to lake. The shale content increases rapidly from delta to shore to lake. Limestone content increases significantly in shore environments The siltstone-conglomerate content decreases gradually from delta to shore to lake. Comparison of the central and south areas shows limited differences in most lithology but some differences do exist between the lake (Tgp) and shore (Tgg). However, these differences exist primarily above the carbonate interval and are, therefore, relatively insignificant to mining since the vast majority

41

of tar sands exist below the carbonate interval. The details of the lithology indicate that the Garden Gulch Member (lake facies) is 2-3 times richer in carbonates than the Parachute Creek Member (lake facies) and 5-6 times richer in carbonates than the Douglas Creek Member (delta facies). In addition within the central and south areas the delta facies is almost twice as rich in sandstones and half as rich in shale as the shore facies.

Dry Canyon Subdelta

The Dry Canyon subdelta is characterized by three to seven zones of bituminous sandstone with consistent bitumen content, and it represents the secondary center of deposition. The major tar sands are localized within a 400-600 foot thick zone on the Roan Cliff face that thins downdip over a distance of one mile to a two hundred foot thick zone beneath the Dry Canyon ridge road (see Roan Cliffs Strike Section A-A' and North Area Dip Section E-E'). This subdelta contains about thirty percent of the total mineable tar sands. The tar sands are primarily contained within distributary channels, distributary mouth bars and beach bar deposits (see Figure 14). The Dry Canyon subdelta contains elongated areas of cumulative MSAT's up to 200-400 feet thick (see Tar Sand Isopach Map). The Dry Canyon subdelta was the principal area of investiga­tion in 1982, 1984, 1986 and 1987. Thirty-one measured sections have been completed in proximal, medial and distal portions of the Dry Canyon subdelta. Twenty-seven of sixty deep Amoco drill holes have been completed in the Dry Canyon subdelta.

The Dry Canyon subdelta is a fluvial-dominated elongated delta system as suggested by the three mile long Dry Canyon distributary-like ridge that extends northeast from the Arco water tank. The elongated type delta system is characterized by fluvial dominance and weak wave energy. Within the well-dissected Dry Canyon subdelta much of the present topographic expression reflects paleogeomorphology. Present topographic ridges and bulges are underlain by tar sands as determined by both field work and drill hole information

The overall lithology of the Dry Canyon subdelta was completed to determine trends of lithology within the subdelta. It is based on 16,291 feet of Amoco drill core (1980-1988 data base that combines all data without distinction of flexure position or mining areas). The overall lithology is: 37.3% sandstone; 9.8% siltstone; 44.1% shale; 7.1% limestone; 1.7% conglomerate; and trace amounts of volcanic tuffs (see Table 4, 1988 Geologic Summary Report). If the lithology is tabulated by delta, shore and lake facies changes in percent sandstone, shale, limestone and siltstone-conglomerate are significant as listed below:

42 01182

Dry Canyon Subdelta (All Segments of Flexure)

Lithology Delta Shore Lake J (Tgd) (Tgg) (Tgp)

%SS 36.1 40.0 8.6 %SH 44.2 40.6 84.7 %LS 3.3 8.2 0.5

%SL & %CG 16.4 11.2 5,9+0.3volc.

The Dry Canyon subdelta encompasses a large area north of Bruin Point toward Mt. Bartles and extends down Dry Canyon toward the Uinta Basin (see Tar Sand Isopach Map). That area of the Dry Canyon subdelta which is considered for mining is the north area and is confined to the western segment of the flexure. The lithology of the north area from Table 4 (this report) is:

North Area, Western Segment of Flexure Dry

Lithology

%SS %SH %LS

%SL & %CG

Canyon

Delta (Tgd)

39.7 41.6 3.9

14.8

Subdelta

Shore (Tgg)

44.6 37.5 6.1

11.8

Lake (Tgp) e r o d e d

The trends of these two short tables from delta to shore to lake are essentially the same as in the Bruin Point sub-delta. However, within the north area the lake facies (i.e., Parachute Creek Member) has been completely eroded away. This has a significant influence on the lithology within the north area. Comparisons of the north, central and south areas in Table 4 of this report indicate a ten percent in­crease in bituminous sandstone with a ten percent decrease in shale for the north area. This is an important factor to consider in selection of a place to start mining operations, i.e., south area versus north area.

Whitmore Canyon Subdelta

The Whitmore Canyon subdelta is characterized by four to six zones of bituminous sandstones with variable bitumen content, and it represents the third and smallest center of deposition. The area contains isolated portions of tar sands with one continuous strip (see Tar Sand Isopach Map). This elongated strip is some two miles long by some 1500 feet wide by 100-400 feet thick and contains cumulative MSAT's up to

oU 43

100-200 feet thick. This subdelta is suggested to contain some five percent of the total tar sands within the entire Sunnyside delta complex. No mine model data exists within this subdelta, and it is currently not considered favorable for mining.

The area contains eleven holes drilled by Mono Power and GNC as well as nine measured sections, all noted on the Geology Map. Pertinent tar sand data is listed on the Regional Map. The core from eight Mono Power holes was relogged in Price during the summer of 1989 and these eight strip logs are included in this report. Hole SS-NW-3 was a rotary hole and no core is available. Strip logs were made for GN-13 and GN-15 from lithology logs and bitumen data of GNC within the Mono Power files. The strip logs of GN-13 and GN-15 are included in this report to complete the data base within the Whitmore Canyon subdelta.

The Whitmore Canyon subdelta represents the wanning stages of deltaic deposition within the Sunnyside delta complex. The principal portion of the tar sands are localized in the Garden Gulch Member. The Parachute Creek Member has been eroded away except in distal portions northeast of Mt. Bartles. The Whitmore Canyon subdelta represents a lower delta plain to delta fringe sequence of distributary channel, distributary mouth bar, and beach deposits that are dominated by inter­vening mixed color shales and algal-ostracodal limestones formed in interdistributary bays. Red shales of the lower delta plain environments exist near the oil/water contact shown on the extreme left side of the Geology Map in sections 23 and 14 of T13S, R13E.

Shales and Limestones

Shales

Red, green, gray and mixed colored shales have been utilized in field mapping to help distinguish the three separate members of the Green River Formation. The red shales are a characteristic feature of the Douglas Creek Member. The green shales are a characteristic feature of the Garden Gulch Member. The mixed colored shales are transitional to both the Garden Gulch and Douglas Creek members. The gray shales are a characteristic feature of the Parachute Creek Member. These four types of shales represent half the rocks in the area (see Table 4, 1988 Geologic Summary Report).

The most obvious feature of any shale is its color, and these colors are the best guide for stratigraphic subdivision and correlation of shales (Potter, Maynard and Pryor, 1980). Shale color or pigmentation is controlled by the oxidation

44 on84

state of iron and carbon content. The color of shales can be separated into two trends as summarized from Potter, Maynard and Pryor (1980), Braunagel and Stanley (1977), McBride (1974) :

Trend I:

GREENISH GRAY grades to PURPLE grades to RED

increasing Fe and decreasing free iron

decreasing Fe and decreasing carbon content

Trend II:

GREENISH GRAY grades to GRAY grades to BLACK.

increasing carbon content

The oxidation state of iron has a controlling influence on the color of the shales as determined by MacCarthy (1926). Purely ferric colors are red, orange and yellow. Purely ferrous colors are blue or colorless. Purple colors are mixtures of reds and blues. Green colors are mixtures of blues and yellows:

"Red and purple rocks owe their color to perva­sive hematite grain coatings and crystals intergrown with clay; brown rocks owe their color to faint or localized iron-oxide grain coatings; and gray rocks to organic matter and authigenic iron sulfide. Green rocks owe their color to chlorite and illite and to the absence of hematite, organic matter and sulfides. Olive and yellow claystone colors are imparted by color mixing of green clay and black organic matter." (McBride, 1974, p. 760).

The greenish gray color of the two shale color trends is represented by the 5GY (hue) - 6/1 (chroma) color designation of the Geological Society of America rock color chart (Goddard, et al, 1963). Based on field relationships and information from the literature the red, green, mixed colored and gray shales within the Sunnyside delta complex are inter­preted to represent distinct environmental conditions.

45 0

The gray shales of the Parachute Creek Member are light olive gray with a 5Y-7/2 to 5Y-5/2 rock color designation. Oil shales are associated with these gray colored shales. Catfish-like and herring-like fish fossils are found within the dinner plate oil shale of the Blue Marker at the base of the Parachute Creek Member. The gray shales were deposited in shallow to moderate water depths under low to very low oxygenated conditions. Dirt roads containing gray shales are extremely slippery after significant precipitation and create mobility problems for all vehicles.

The greenish gray shales of the Garden Gulch Member are one of its most characteristic features and have the same color designation (5GY-6/1) as noted in the two shale color trends. Both micrites and biomicrites are associated with the green shales. The green shales readily crumble to form small cube-like fragments. Turtle fossils are found within the green shales of the Garden Gulch Member and indicate burial before the bone material was completely oxidized. The green shales of the Garden Gulch Member are calcareous and were deposited in shallow water environments under moderate oxygenated conditions in nearshore margins of Lake Uinta. Dirt roads containing green shales remain well-drained even after considerable precipitation.

The mixed colored shales are characteristic of transitional environments associated with both the Garden Gulch and Douglas Creek Members. These mixed colored shales contain different proportions of red, green, olive, yellow, brown and purple colors. The purple color represents grayish red purple with a rock color designation of 5RP-4/2. These mixed colored shales are calcareous and were deposited in interdistributary bays and inlets or lagoons that experienced alternate wetting and drying. This resulted in complex reducing and oxidizing conditions that formed the variegated colors.

The red shales of the Douglas Creek Member are grayish red (5R-4/2 to 10R-4/2) to dark reddish brown (10R-3/4). The red shales are slightly more resistant to weathering than the green shales. Dirt roads containing red shales do not drain well and often are slippery. The red shales are non-calcareous and were deposited in marsh environments under dominantly oxidizing conditions. Thin discontinuous pods/ seams/seamlets of coal are localized within the red shales of the Douglas Creek Member. The small to moderate volumes of green shales that exist beneath the massive sandstones in the north and south pits of the Asphalt Mine probably formed as the result of groundwater seepage from the overlying sand­stones. This groundwater seepage forms green shales from red shales by reduction of the ferric iron content.

46

Additional supporting evidence on the color of shales and their environmental interpretation exists from China, England, Louisiana and Mexico. In northeast China a middle Cretaceous lacustrine delta complex formed in the Songliao basin. As described by Shice and Hengjian (1981) , red shales developed mainly in the floor plain facies; gray and green shales developed mainly in the deltaic distributary plain; grayish black shales developed mainly in the delta front facies; and black shales developed mainly in the semi-deep to deep lake facies. In England the greenish gray (5GY-6/1) to olive gray (5Y-4/1) clays of the Cretaceous Weald Clay of south­eastern England were deposited in shallow oxygenated brackish water marine environments; ostracods are commonly associated with the greenish gray (5GY-4/1) or light olive gray (5Y-6/1) clay as noted by MacDougall and Prentice (1964). In Louisiana within the modern Mississippi River delta color laminations are considered to be the result of alternate wetting and drying of muds deposited in brackish and saline marshes (Saxena, 1976) . In northeastern Mexico near Monterrey and Saltillo late Cretaceous to Paleocene delta plain deposits are characterized by an eighty percent abundance of red beds. Green colored shales often underlie massive sandstone beds; groundwater seepage out of these overlying massive sandstone beds formed the green colored shales by reduction of the ferric iron content in red shales (McBride, 1974). Red to purple colors develop in delta plain facies and gray colors develop in prodelta and shelf facies. Development of color within sediments is a post-depositional feature requiring hundreds to thousands of years (McBride, 1974).

Limestones

Limestones represent a significant and repeated minor lithologic component of the Sunnyside delta complex (see Table 4). Almost seven percent of all the rocks in the delta complex are limestones. Limestones are the most prevalant carbonate. Thin limestones two to five feet thick commonly exist at the eroded top of each lithologic sequence containing sandstone-shale-limestone. Limestones exist within all three members of the Green River Formation but are most abundant within Zones 25 and 26 (carbonate interval) of the Garden Gulch Member. The carbonate interval is discussed in more detail within the Garden Gulch Member portion of the test.

The relatively thin limestones consist of micrites and biomicrites. Thin intervals of laminated algal mats often cap micrite intervals. The biomicrites contain laminated algal mats, algal stromatolites, ostracods, turtle fragments, fish scales and biota trash. The biota-rich biomicrites represent grainstones (ostracod coquina) or boundstones (algal mats and algal stromatolites). Ostracod coquinas are

47 0

more abundant and laterally persistant than zones of algal mats or algal stromatolites. In this lacustrine delta complex ostracods are by far the most abundant fossil fauna, while blue-green algal types are by far the most abundant fossil flora. Local intervals of whole and broken algal stromatolites with cabbage head-like shapes are well exposed in the upper portion of MS-41 and the lower portion of MS-3. Cycles of limestone deposition are five to fifteen feet thick with a range of one to thirty feet. Thin intercalated shales often exist within the thicker limestone intervals.

Sedimentary structures associated with the limestones include small scale trough cross bedding, planar bedding, mudcracks and tepee structures. The latter are localized within algal laminated beds or the upper portions of micrites. These small pseudo-anticlinal features have cross sections that look like American Indian tents, hence the name tepee. Buckling of carbonate sediments forms the tepee structure and is caused by expansion of carbonate-rich material. The expansion is the result of carbonate crystallization and cementation processes associated with repeated drying and wetting conditions that persist in peritidal areas of lagoonal and back-barrier environments (Assereto and Kendall, 1977). Tepee structures were recorded in MS-38 and MS-44, which are both located in the Whitmore Canyon subdelta. These tepee structures formed within lacustrine carbonate mud flats that experienced subaerial exposure.

Field examples indicate the presence of minor cycles of carbonate deposition. When two types of limestones are present there commonly is a lower micrite interval overlain by a biomicrite interval as in MS-51 below Zone 32 at -210' and -220'. A six foot cyclic interval of micrite-biomicrite-micrite-biomicrite exists in MS-56 below Zone 23. These minor cyclic sequences are evident within some limestones and in­dicate rhythmic changes associated with fluctuating lake levels during semi-arid conditions. In MS-47 Zone 26 contains a five foot thick basal micrite, a five foot thick biomicrite in the middle and a one foot thick algal-rich limestone at the top. This eleven foot thick interval is interpreted as a shallowing upward cycle and developed under conditions that changed from nearshore to shoreline to lagoonal marsh and were caused by a lowering of the lake level. In MS-56 at the top of the Garden Gulch Member there is a seven foot thick micrite-rich interval just below the Blue Marker that contains a six inch thick brown to black shale with plant debris and thin coal seam-lets (1.0" and 0.5" thick) at the base and in the middle. The presence of coal within limestones indicates that lagoonal to marsh type vegetation existed during periods of carbonate deposition. These lagoonal to coastal marsh conditions existed adjacent to shoreline environments.

on88

48

Rock Data

Porosity and Permeability

Bitumen is associated with sandstones, siltstones and limestones and each of these lithologic types has distinct porosity/permeability characteristics. Twenty-seven NQ core samples were analyzed by Core Labs, Inc. of Denver. The values are listed below:

Sample Number Porosity Permeability tested

Range Average Range Average

Bituminous sandstone 18 23.8-29.1 27.0 37 -3300 812

Bituminous siltstone 4 17.7-25.7 21.8 0.51- 187 63.7

Bituminous limestone 5 14.8-24.5 18.0 0.14- 1.4 0.6

The porosity/permeability values are different for each of the three lithologic types. The sandstones (bitumen removed) have average values of <t>=27%, K=812md. Porosity values of the sandstones commonly range from 24-29%, while permeability values of the sandstones commonly range from 400-800md (milli-darcy). Siltstones (bitumen removed) have average values of <f>=22%, K=64md. Limestones (bitumen removed) have average values of <t>=18%, K=0.6md.

Additional analytical data on the Sunnyside Tar Sands is from four sources. First, Pan American-Preston Nutter CH-1 data base contains eight analyses of tar sands that show the following: average porosity of 24.3 (range 24.0-26.9); average permeability of 398md (range 173-491); average oil saturation of 42.8% (range 35.2-59.0); average water saturation of 16.9% (range 11.0-27.8). Second,the Sunnyside Tar Sands have porosities of 25-30% and permeabilities of 154-677md (Wells, 1958). Third, the Sunnyside crude oil has a viscosity of 60cp at 340°F with no natural mobility at original reservoir conditions (Thurber and Welbourn, 1977). Fourth, Amoco Production data from Amoco Nos. 2, 3, 5, 6 and 7 shows the following: eleven analyses with average API gravity of 9.2 (range 6.8-12.3); eight analyses with average C content of 85.3 (range 82.45-87.23); eight analyses with average H content of 10.4 (range 7.69-11.18); and N content of 0.84wt% and S content of 0.30wt% (one reported value).

01189

49

Compressive Strength

Compressive strength values are related to lithologic types and bitumen values. The tests were made on NQ core (1.87" diameter) by Core Labs, Inc. of Denver during the 1980, 1981, 1982 and 1984 exploration programs. The values associated with the four lithologic types are given below:

Sample Number Compressive strength Average tested in psi wt% bitumen

Range Average

sandstone 87 2,857-17,196 5,165 7.2 siltstone 35 4,918-22,482 9,642 2.9 limestone 47 3,334-26,002 8,795 3.5 shale 55 6,247-20,448 12,360 0.02

Based on this data three distinct categories exist: sand­stones with average values near 5,000 psi; siltstones and limestones with average values near 9,000 psi; and shales with average values near 12,000 psi.

Within the sandstones a plot of the bitumen content versus compressive strength values indicates a linear relation­ship between bitumen content and compressive strength. Increased bitumen content decreases the compressive strength (see Figure 14, 1984 Geologic Summary Report). The bituminous sandstones have a compressive strength that commonly ranges between 3500-6000 psi.

Shales within the tar sand deposit are separated into four distinct color groups: gray, green, mixed and red. Compilation of compressive strength values by shale color indicates that the gray, green, mixed and red shales have distinct average values as listed below;

Shale Member - facies Samples Compressive strength tested in psi

Range Average

gray Parachute - lake 6 12,592-20,448 15,511 green Garden Gulch - shore 36 6,247-17,111 10,986 mixed Garden Gulch - shore 5 7,824-17,096 12,601 red Douglas Creek - delta 8 13,929-18,032 16,031

This data clearly separates the shales into two groups based on different compressive strength values. The gray and red shales can be grouped together with values near 16,000 psi. The green and mixed shales can be grouped together with values near 11,000 psi. The green and mixed shales are

oi l* 0

50

definitely an order of magnitude lower in value than the gray and red shales. Significant differences exist between the two shale groups and may be important in mining the shale interburden. The north area is dominated by the shale group with lower compressive strength values. The central and south areas are associated with shales from both groups.

51

OH

TAR SANDS

Over ninety-five percent of the bitumen in the Sunnyside delta complex is associated with porous and permeable sandstones. These reservoir rocks are separated into sheet sands and channel sands. The fifteen major bituminous zones have designated numbers (see Figures 13 and 14) and are largely confined to the Douglas Creek and Garden Gulch Members in the western segment of the flexure. These tar zone numbers were estab­lished in 1982 and determined on the basis of downhole gamma ray logs since 1986. Surface gamma ray logs have been used along measured sections to identify the outcrops of numbered tar zones. The bituminous sandstones are remarkably uniform in texture, grain size and mineral composition. The bituminous sandstones are well sorted, fine and very fine grained and dominated by grains of quartz and feldspars. Both the sheet sands and channel sands contain less than five percent silt and clay.

In the Sunnyside Tar Sands deposit numbered tar zones were established by use of geophysical and geological data. Gamma ray well logs, frequency and thickness of intercepts in drill holes and assay data were compiled on a hole by hole basis by John Rozelle. Initially some thirty-five specific tar sand intervals were defined. These intervals were then correlated with detailed lithology and depositional environments of core logs to establish numbered tar zones. From this investiga­tion fifteen tar zones were selected and represent the major mineable tar zones. These tar zones were numbered according to their stratigraphic position by a two digit number code. The first digit applies to the member (i.e., 1 for Tgp, 2 for Tgg and 3 and 4 for Tgd) and the second digit applies to its vertical position with number 1 at the highest elevation. These major numbered tar zones include Zones 21, 22, 23, 25, 26, 31, 33, 35, 36, 37, 38, 41, 42, 42, 45. Zones 25 and 26 are bituminous limestones and all the other zones are bituminous sandstones. When the gamma ray well log, density well log, lithology and environments of deposition are used in combination, numbered tar zones can readily be determined for the drill core data.

Table 4 was compiled to determine the lithology in the western segment and to quantify any differences of percent sandstone (i.e., tar sand). The percent sandstone represents a relative figure of percent pay as the lithology figures are based on total depth not base of saturation. The vast majority of the tar sands are localized within the western segment of the flexure along the trends of the Roan Cliffs (see Tar Sand Isopach Map). This fairway can readily be divided into north, central and south areas (see Roan Cliffs Strike Section A-A1). These three areas also represent mega mining units. Drill holes were always drilled past the tar

52 oU9*

sands to the first clean sandstone to accurately determine the base of saturation. Data in Table 4 shows that the north area is unique in three ways. First, it contains about ten percent more tar sand and ten percent less shale than the south area. Second, the Parachute Creek Member has been completely eroded away, and this creates conditions that will require much less overburden removal than in the south or central areas. Third, the average depth to the base of saturation in the north area is 109 feet shallower than in the south area and 500 feet shallower than in the central area (see average BSAT depths in Table 4). Thus depths of mining in the north area would average 109 feet less than in the south area.

These three geological factors are important considera­tions for the evaluation of where to begin mining within the Sunnyside Tar Sands deposit. These three geological factors are quantitatively shown in Table 4 and visually apparent from the five cross sections.

Maps and Cross Sections

Tar Sand Isopach Map

The Tar Sand Isopach Map shows three distinct factors about the Sunnyside Tar Sands deposit. First, the thickest portion of the tar sands exist near Bruin Point in the western segment of the flexure. These tar sands are concen­trated in areas updip from the main axis of the Mt. Bartles-Bruin Point flexure and located in the highest topographic areas. Tar sands in the central segment are diminished in areal extent and concentration. Tar sands in the eastern segment are even further diminished in areal extent and concentration. Second/ the tar sands are concentrated within a long and narrow northwest trending belt. This long seven to nine mile belt corresponds to the depositional strike of the sediments, while the narrow one to four mile wide portion corresponds to the depositional dip. Most of the major (400-700 feet of cumulative MSAT) and minor (100-400 feet of cumulative MSAT) tar sands are confined to this long narrow belt. Two isolated areas of minor tar sands exist along the ridge tops in the Whitmore Canyon subdelta area. Two isolated areas of minor tar sands exist east of the main axis of the flexure. Areas of limited (0-100 feet of cumulative MSAT) tar sands exist adjacent to areas of minor tar sands. Third, in the subsurface a C02~rich gas zone exists above the base of the tar sands in the area between Range Creek and Bruin Point outlined on the Tar Sand Isopach Map. These gases are commonly entrapped in weak to poorly saturated sands slightly above the barren sands. These gases average (N=2) 98.5% CO2, 1.4% CO, 0.04% methane and 0.06% other gases with no detectable H~S.

53

Base of Saturation Map

A five square mile area with a nearly flat gradient exists in the central portion of the map and interrupts the trend of the northeast dip slope. This five square mile area contains the majority of the tar sands as seen by overlaying the Base of Saturation Map on the Tar Sand Isopach Map. This five square mile flat area (3.4 mi L x 1.5 mi W) is centered near Bruin Point and the change in strike of the Blue Marker (i.e., N40°W to the north of Bruin Point and N20°W southeast of Bruin Point). The Mt. Bartles-Bruin Point flexure is superimposed on this BSAT Map. It is evident that this five square mile area is immediately updip from the main. axis of the flexure. It appears as though the flexure was the main avenue for oil migration and the hydrocarbons collected in porous and permeable sandstones within the flat catchment area immediately updip from the flexure. In the Whitmore Canyon area the dip of BSAT flattens out again and tar sands are again concentrated. The nearly horizontal base of saturation slopes at an average rate of 30 ft/1000 ft, while the beds dip at an average rate of 120 ft/1000 ft. This difference in slope causes the base of saturation to rise relative to the tar zones in downdip directions.

This five square mile nearly flat area contains two large depressions, one in the northwest and one in the southeast. The northwest depression is associated with the area of thick­est tar sands below Bruin Point. This northwest depression consists of two adjacent depressions that collectively are four thousand feet long by two thousand feet wide. The southeast depression is located near drill holes A-70 and A-69 and is part of the conduit system shown in the far right portion of the Roan Cliffs Section A-A'. This southeast depression is some thirty-five hundred feet long by one thousand feet wide and is one to three hundred feet lower in elevation than the northwest depression. This southeast depression is near the structural intersection of the mapped Mt. Bartles-Bruin Point flexure in Range Creek and an unmapped cross structure in the saddle or sag near drill hole RCT-14. This southeast depression may be part of a conduit system which serves as an avenue for emplacement of oil which was later degraded to bitumen.

Roan Cliff Strike Section A-A'

This cross section illustrates the extent and shape of the Sunnyside Tar Sands deposit along the Roan Cliffs. It also illustrates the distribution of numbered tar zones and their relationship to members of the Green River Formation. The distribution of the tar sands has been separated into north, central and south areas. The north area contains the Dry Canyon subdelta. The central area contains the

54

thickest portion of tar sands and is part of the Bruin Point subdelta. The south area contains the South Knoll and a major portion of the property purchased from Mono Power. The south area exists within the Sunnyside Municipal Watershed that was so designated by an Act of Congress in 1926 or 1927. The salient points of Section A-A* are listed below:

1. This cross section illustrates the distribution of the bituminous sandstones along the Roan Cliffs. The highest concentrations of tar sands exist in the central area, the second highest concentrations of tar sands appear to exist in the north area and the lower concentra­tions of tar sands appear to exist in the south are.

2. The major concentration of tar sands begins below the carbonate interval with Zone 31. The fifty foot carbonate interval exists through­out the Roan Cliff face except where removed by erosion. Minor concentrations of tar sands exist above the carbonate interval and below the Blue Marker. Very limited amounts of tar sands exist above the Blue Marker. The carbonate interval may have acted as a partial seal. The Parachute Creek Member contains lacustrine clays of montmorillonite composition and acted as the final seal.

3. The base of saturation is deepest in the central portion and exists some 1200 feet below Bruin Point. This base of saturation gradually climbs some 200 feet to the northwest over a horizontal dis­tance of 12,000 feet. To the southeast the base of saturation climbs more irregularly some 200-300 feet over a horizontal distance of 17,000 feet.

4. To the right of Bruin Point the beds have a slight slope as the cross section is diagonally oriented to the N20°W strike of the structure contours of the Blue Marker. To the left of Bruin Point the beds are nearly horizontal as the section is nearly parallel to the N40°W strike of the structure contours of the Blue Marker.

5. Beneath the South Knoll a narrow vertical conduit containing some bituminous intervals exists. This South Knoll area is located near the Mt. Bartles-Bruin Point flexure and a probable cross structure in the sag where drill hole

55 o ifl

RCT-14 is located. The 63 foot thick collivium at drill hole RCT-14 is highly anomalous and exists in the saddle that separates the central area from the south area.

6. The Parachute Creek Member is eroded away in the north area and is between 50-150 feet thick in the central and south areas. The Garden Gulch Member is commonly five hundred feet thick.

Range Creek Strike Section B-B'

This section shows the limited distribution of tar sands located 6000 feet downdip from Section A-A1. This section also shows the detailed stratigraphic continuity established by four markers and the carbonate interval. The salient features of Section B-B1 are listed below:

1. Stratigraphic continuity is readily established by the carbonate interval of the Garden Gulch Member and four markers in the Parachute Creek Member which are the Wavy Bedded Tuff, Mahogany oil shale, R-5 oil shale, and Blue Marker.

2. The distal portion of the Bruin Point subdelta is characterized by relatively thin tar zones that contain an irregular distribution of bitumen.

3. Tar Zones 10, 22, 31, 35 have the best strati­graphic continuity. The twenty foot thick Zone 31 has the highest and most consistent bitumen values of 17-22gpt. Zones 10, 22, 35 all contain irregular grades of 6-18gpt. See data/from Table 1 for more detail of zone thickness and grade.

4. Tar Zones 36, 37, 38, 41 are mostly barren as they exist below the base of saturation.

5. Member thickness: Tpg 300-700 feet thick Tgg 500-550 feet thick Tgd unknown as top nearly

coincides with base of saturation (BSAT)

Comparisons of equivalent portions of Roan Cliff strike Section A-A' and Range Creek strike Section B-B1 show significant thinning of the tar sands in going downdip some 600 feet from the Roan Cliffs. These and other differences are listed below:

56

V96

Category Roan Cliffs Range Creek

Tar Sands

Tgp Blue Marker Carbonate interval BSAT

major volumes in ten tar zones ~150 feet thick ~150 feet deep ~400 feet deep *1200 feet deep

minor volumes in four tar zones ~500 feet thick ~500 feet deep ~750 feet deep ~1000 feet deep

Bruin Point Dip Section C-C'

This section illustrates the concentration of tar sands within the western segment of the flexure, the sequence of numbered tar zones, and the stratigraphic position all five important markers. The salient features are listed below:

1. The three segments of the Mt. Bartles-Bruin Point flexure each contain some dominant and unique characteristics. western segment: 4-12°NE dips & 4-12wt% bitumen central segment: 4-7°NE dips & 4-7wt% bitumen eastern segment: 3-5°NE dips & 0-4wt% bitumen

2. Vividly illustrates the concentration of ten major tar zones in the western segment beneath Bruin Point. This is the result of two factors. First, the maximum distribution of porous and permeable sandstones exists beneath Bruin Point as this area represents the primary deposition center of the delta complex. Second, there is an anomalous flattening of the base of saturation beneath Bruin Point that exists immediately updip from the main axis of the flexure.

3. Illustrates the vertical position and persistence of all marker beds including the Wavy Bedded Tuff, Mahogany oil shale, R-5 oil shale, Blue Marker and carbonate interval.

4. Member thickness

South Area Dip Section D-D'

Tgp 100-450 feet (top eroded) Tgg 450-500 feet (consistent) Tgd 100-800 feet (base not drilled)

This section is about 12,000 feet southeast of Section C-C as shown on the Geology Map. The thickness of the tar sands below the carbonate interval has decreased from some 800 feet in Section C-C to some 200 feet in Section D-D'. The details of this decrease are seen in Section A-A1 between drill hole A-12 and drill hole RCT-3A. The salient features of Section D-D' are listed below:

57 oW*'

1. The bitumen is concentrated within four Tar Zones 31, 32, 35 and 36.

2. The numbered tar zones in the western segment con­tain 4-12wt% bitumen, while the numbered tar zones in the eastern segment contain 4-6wt% bitumen (data obtained from Table 1).

3. The base of saturation is associated with Zones 36 and 35. In Section C-C' the base of saturation is associated with Zones 43 and 45.

4. The persistent carbonate interval may have acted as a partial seal for the hydrocarbons. The Blue Marker and overlying Parachute Creek Member acted as an additional seal for the hydrocarbons.

5. Member thickness: Tgp 100-370 feet (top eroded) Tgg 400-500 feet Tgd 50-200 feet (base not drilled)

6. Different dips are associated with different seg­ments of the flexure. After plotting drill hole data and connecting designated intervals the western segment has dips of 7°, while the eastern segment has dips of 5°. The central segment is about 1100 feet wide and contains no drill hole data, so dip values could not be determined.

7. Erosion has removed an additional 250 feet from the western segment compared to the eastern segment as determined from heights above the Blue Marker.

North Area Dip Section E-E'

Section E-E' is located about 6500 feet northwest of Section C-C' as shown on the Geology Map. The salient features of Section C-C' are listed below:

1. Seven thick tar zones from Zone 31 to Zone 41 exist beneath the main ridge of the Roan Cliffs.

2. All marker beds including the carbonate interval have been removed by erosion.

3. The western segment contains thick concentrations of tar zones within a 600 foot interval that dips 6-7°NE and has a base of saturation with a rela­tively flat but undulatory configuration.

o v ^ 58

4. The eastern segment contains thin concentrations of tar zones that dip 4-5°NE and have a base of saturation that dips nearly 6°NE.

Comparison of the North Area Dip Section E-E' with the South Area Dip Section D-D' quickly reveals that the north area appears to contain larger volumes of tar sands with lower overburden and shallower depths to the base of saturation. These are important factors to utilize in selection of the area to begin mining operations. Some of these significant differences are listed below:

Category North Area E-E' South Area D-D'

Tar Sands

Tgp (avg, thickness)

Blue Marker (avg. depth)

Carbonate interval (avg. depth to top)

BSAT (avg. depth)

6-7 tar zones (No.31-41)

eroded

eroded

eroded

571 feet

3-4 tar zones (No.31-16) 105 feet

105 feet

325 feet

680 feet

Sheet Sands and Channel Sands

The geometry of outcrops indicates the tar sands can be separated into sheet sands and channel sands. The channel sands represent some twenty-five percent of the bituminous sand­stones and are preferentially found in the lower part of the tar sands package. The sheet sands represent some seventy-five percent of the bituminous sandstones and are found throughout the tar sands package.

The sheet sands, as the name implies, are relatively thin laterally continuous sand bodies that represent reworked deltaic sands or shoreline sands. The sheet sands frequently rest unconformably on limestones. The sheet sands are tens of feet thick with an average thickness of 30-40 feet. The dominant sheet-like nature of the bituminous sandstone is well-illustrated in Photos 3 and 4 (1987 Geologic Summary Report) and partially illustrated in Photos 2 and 3 of this report. The sheet sands are laterally continuous for hundreds to thousands of feet as determined by drill holes at spacings of 1000-1500 feet, measured sections at spacings of 1000-3000 feet, and views of outcrops along the Roan Cliffs.

The channel sands have a distinct basal scour and contain a thick central body of sandstone that may abruptly terminate laterally or extend as thin lateral wings of sandstone. The channel sands have 5-50 foot deep basal scours with 5-15 feet

59 (^ \99

as a common range of scour. The most extensive mapped basal scour of 48 feet is associated with Zone 35 in MS-3. The channel sands are tens to a few hundreds of feet thick with an average thickness approaching 70-80 feet. The channel sands contain numerous stacked sets of sandstone intervals. Clay plugs and swales are not common in the channel sands but a shale-filled swale is well-exposed in the north pit of the Asphalt Mine. Some channel sands cut into delta plain sediments (north pit of the Asphalt Mine and on the road to Bruin Point near the 9000 foot elevation contour below the major switchback at drill hole location GN-4). Some channel sands cut into the lacustrine shoreline sediments (MS-3, Zone 35) . The channel sands often grade laterally into sheet sands.

The geometry of the sandstone reservoirs is critical to the evaluation of the Sunnyside Tar Sands project. The Roan Cliffs represent a stacked sequence of shorelines from ancient Lake Uinta. Channel sands are more dominant landward of the shoreline, and sheet sands are more prevalent lakeward of the shoreline. In the immediate vicinity of the shoreline the sheet sands and channel sands merge and the sheet-like nature dominates. The major tar sands are concentrated in the immediate vicinity of the ancient shorelines over distances of 7-9 miles along depositional strike and over distances of 1000-10,000 feet along depositional dip (see Tar Sand Isopach Map, Roan Cliffs Strike Section A-A' and Bruin Point Dip Section C-C) .

The lateral continuity of the numbered tar zones along depositional strike is pronounced with minimal thickening or thinning. The lateral continuity of the numbered tar zones along depositional dip shows marked thinning in a downdip direction. The individual numbered tar zones are commonly 40-150 feet thick in the Roan Cliffs (proximal part of delta) and commonly 10-30 feet thick east of Range Creek (distal part of delta). The thinning of tar sands from proximal to medial areas is seventy percent. The thinning of tar sands from medial to distal areas is eighty-five percent. This data indicates there is pronounced thinning of tar sands toward the Uinta Basin.

Depositional Environments

Field studies indicate that the bituminous sandstones formed in four principal environments of deposition: distributary channels (DC) ; distributary mouth bars (DMB) ; beaches (B) and beach-bar (BB) deposits. The characteristics of the different rock types in the Sunnyside Tar Sands area are summarized in Table 5.

60

The four environments of sandstone deposition were determined from the following five items:

Item (1); shales and limestones. The color of the adjacent shale is indicative of particular environments such as gray (lake), green (nearshore), red (marsh) or mixed color (bay). The laterally or vertically adjacent shales and lacustrine limestones bracket the sandstone location and serve as a guide to determination of sandstone depositional environments. The sandstones frequently exist unconformably above a partially eroded 2-10 foot thick limestone interval and indicate progradation of sands across subaerially exposed carbonate mud flats or nearshore environments. In some locations the middle portions of certain massive sandstone bodies contain isolated internal limestone pods (2-5 feet long x 1 foot thick) or disseminated concentrations of 5-20% ostracods. These internal complexities indicate aqueous conditions and suggest DMB environments.

Item (2): sedimentary structures. A characteristic pattern of sedimentary structures is indicative of channel, mouth bar or beach deposition. This and minor occurrences of bioturbation are discussed in more detail separately.

Item (3): lag deposits. The types and position of lag deposits is a helpful guide in determining sandstone deposi­tional environments and is discussed in more detail separately.

Item (4): grain size. The fine to very fine grain size of the tar sands is so uniformly consistent that megascopic differences in grain size are difficult to ascertain in the field even with a ten power hand lens. Grain size changes within the bituminous sandstones and resulting fining upward or coarsening upward cycles are not well defined.

Item (5): associated biota. The presence of biota trash is a helpful criteria for a beach (B) deposit. Plants and wood fragments are rare but helpful criteria for deposits of distributary channels (DC). Disseminations of ostracods within tar sands are helpful criteria for a B, BB or DMB deposits.

Sedimentary Structures

The dominant sedimentary structures in the tar sands include trough cross bedding, horizontal (planar) bedding and ripple laminations. Planar cross bedding is usually limited and often represents a phase of trough cross bedding due to the angle of view. Distorted/contorted bedding caused by liquefaction in water saturated sediments exists in portions of massive sandstone units. Hummocky cross stratification is rare in the Roan Cliffs but has been observed

61

a number of times in the West Tavaputs Plateau. Epsilon cross bedding is essentially absent. The vertical succession of sedimentary structures or bedforms is a significant criteria to help determine sandstone depositional environments.

During the deposition of sand the sedimentary structures that form reflect the bedforms that develop during two types of flow regimes. The lower flow regime is characterized by tranquil to low flow, and the sand grains are influenced primarily by forces of gravity and secondarily by forces of inertia. The tranquil or lower flow regime is characterized by bedforms of plane beds that form without water movement, ripples, dunes and transitions to rapid flow bedforms. The upper flow regime is characterized by turbulent to high flow and the sand grains are influenced primarily by forces of inertia and secondarily by forces of gravity. The rapid, turbulent or upper flow regime is characterized by plane beds that form with water movement, standing sand waves and anti-dunes. The median grain size in the Sunnyside Tar sands is 0.20mm. Bedforms of the lower flow regime dominate the Sunnyside tar sands.

During deposition the vertical sequence of sedimentary structures represents the bedforms that develop during rela­tively decreasing or relatively increasing flow regime con­ditions. At the Sunnyside Tar Sands area the most prevalent vertical sequence of sedimentary structures is basal scour •*• trough cross bedding -*• planar bedding -*• ripple laminations. The DC deposits are characterized by a basal scour, trough cross bedding in the lower portion, planar bedding in the middle and ripple laminations in the upper portion. The second most prevalent vertical sequence of sedimentary structures is basal planar bedding •*• trough cross bedding. B and BB deposits are dominated by trough cross bedding near the base and horizontal (planar) bedding at the top. The DMB deposits contain the most complex and variable sets of sedimentary structures but are dominated by trough cross bedding and planar bedding as well as limited bedforms caused by liquefaction.

Hummocky cross stratification is a bedform associated with storm waves. In July or August of 1987 a major storm on Great Salt Lake caused eight to ten foot waves and waves of these heights or greater do occur on other large lakes. In the Great Lakes high winds cause storm surges that represent an abnormal sudden rise of the lake level; these storm surges average about 1.7 feet and range from 0.47-4.7 feet (Murty and Polavarapu, 1975). Storm waves and storm surges existed in ancient Lake Uinta and help to explain the presence of hummocky cross stratification in sandstones.

62

The average paleocurrents flowed northeast. Eighty-eight paleocurrent measurements by Banks (1981) have a vector re­sultant of N45°E with the main grouping between N30-60°E. The second grouping is between N60-90°E. The third grouping is between N to N60°W.

Epsilon bedding is well-recognized as a characteristic feature of a channel meander belt and is formed by lateral accretion of point bars. The Sunnyside Tar Sand area lacks any significant volumes of epsilon cross bedding, and upward increases of silt and shale partings or drapes are not characteristic of the bituminous sandstones.

Diagnostic sequences of sedimentary structures are helpful criteria in the evaluation of sandstone depositional environments but are not solely unique to a single or specific environment. The classical vertical sequence of point bars formed at river bends in meandering streams is trough cross bedding -*• horizontal bedding -*• ripple laminations (Visher, 1965 and Stear, 1983) or channel floor erosion and lag deposits -*• plane beds -*• large ripples -*• small ripples -*• overbank flooding (Allen, 1963). These point bar systems often contain fully developed fining upward sequences of sedimentary structures. The vertical sequence of estuary (that part of a river affected by tides) deposits progress from lag deposits to predominantly crossbedded deposits to predominantly horizontally bedded deposits at the top. Klein (1963) noted that the vertical sequence of sedimentary structures in channel deposits and estuarine deposits is essentially the same and that the only major difference is in the type of basal lag deposit.

Three types of minor occurrences of bioturbation (churning of sediments by organisms) are found within sediments of the Sunnyside delta complex and are usually of a weak to moderate intensity. Three types of burrows occur within bioturbated intervals and include: (1) deformed; (2) small size; and (3) moderate size. (1) The deformed burrows are only associated with oil shale intervals in the Parachute Creek Member, were made in a soupy mud and later deformed or distorted by soft sediment deformation. The majority of these deformed burrows are of a vertical nature, while a minority is of a horizontal nature. Jordan (1985), p. 288, photo D) has an excellent photo that depicts this type of deformed bioturbation. (2) the small size burrows (X - 0.1" D, range 0.05-0.2" D) are vertical and associated with greenish gray and mixed colored shales in the Garden Gulch Member. (3) the moderate size burrows (X = 0.25, range 0.2-0.5" D) are vertical and associated with siltstones and some sandstones in the Garden Gulch and Douglas Creek Members.

Lag Deposits

Numerous thin intraformational conglomerates (IFC's) are associated with all three members of the Green River Formation and represent lag deposits. IFC's commonly occur at or near the base of tar sands but also occur within middle portions of tar sands. In outcrop and core these IFC's are commonly 1-5 feet thick. In outcrop the IFC's are tens to a ' few hundreds of feet long and can thin rapidly in lateral directions. The change in grain size at the tops and bottoms of these IFC's is abrupt. These IFC'S contain rip-up clasts from nearby or adjacent environments and represent intrabasinal clasts. Extrabasinal clasts of igneous and metamorphic rock fragments are not megascopically present. The composition of these IFC's is shale-rich; limestone-rich; biota-rich (fish scales, ostracods, turtle bone fragments or algal stromatolites); or combinations of these three.

The composition of the lag deposit is an important factor that helps to interpret sandstone depositional environments. Klein (1967) noted that tidal channel deposits are almost exclusively floored by shell lag deposits; estuarine channels are floored by a mixture of shell lag and clay chips; and fluvial channels are floored by gravel, clay pebbles and logs. The most common lag deposits in the Sunnyside Tar Sands area are mixtures of shale, shale-limestone-biota and limestone-biota. These latter two mixtures are similar to those of estuarine channels but may also represent shore lag deposits formed by storm surges, storm waves or transgressive high stand lake levels. The 1-3" thick shale-limestone IFC's within the shales and oil shales of the Parachute Creek Member represent storm lag deposits.

Microtides can be a minor factor in the development of lag deposits. Microtides probably existed in ancient Lake Uinta with normal magnitudes of 2-4 inches. Microtidal data for large lakes has not been found in the literature. Lake Michigan supposedly has microtides in the range of 3-4 inches.

Textures

Grain size, shape and sorting of the individual sand-size particles were determined from thin sections by Banks (1981) and Remy (1984) . The grain size of the bituminous sandstones is relatively uniform from tar zone to tar zone. The average grain size based on sixty-one samples is:

18% medium sand 54% fine sand 23% very fine sand 5% silt and clay

100%

(0.5-0.25mm or 500-250 microns) (0.25-0.125mm or 250-125 microns) (0.125-0,0625mm or 125-62 microns) (<0.0625mm or <62 microns)

o \tf>

No reliable standard grain size analyses are available within the bituminous sandstones to determine vertical changes in grain size (i.e., fining upward or coarsening upward). The common cylinder shape of the gamma ray well logs within sand­stones also suggests uniform grain size. In outcrop the relatively uniform megascopic grain size masks any definite upward fining or coarsening upward sequence. Nevertheless, a subtle upward fining trend is suggested to exist within the bituminous sandstones near the Roan Cliffs. Coarsening upward trends within the tar sands are rarely apparent but exist in the West Tavaputs Plateau. The overall sandstone-shale-limestone cycles certainly indicate a fining upward sequence.

The degree of sorting based on fifty-five surface samples of Banks (1981) is: 37% well sorted, 53% moderately well sorted, 2% moderately sorted and 8% poorly sorted. The distribution of grain shapes based on fifty-five surface samples of Banks (1981) is:

shape

angular subangular subrounded rounded well rounded

fine sand

39% 29% 19% 10% 3%

very fine sand

49% 26% 16% 7% 2%

100% 100%

Mineral Composition

The Sunnyside bituminous sandstones are feldspathic arenites as determined by petrographic studies of Banks (1981) and Remy (1984). The detailed results of thin section investigations are listed in Table 6 and indicate the following compositions: 70% major framework grains; 3% minor framework grains; 7% cement and matrix; and 20% voids (porosity and/or bitumen).

The major framework grains represent 70% of the sand­stones and consist of 33% quartz, 20% feldspars and 8% rock fragments. The feldspars consist of 17% plagioclase and 12% K-feldspar (orthoclase 9%, microcline 3%). All the feldspar grains are partially weathered and have undergone some degree of in-situ dissolution. This weakened state coupled with the multiple pronounced feldspar cleavages makes all the feldspar grains (29% of the rock) highly susceptible to mechanical breakdown by grinding. The natural "fines" con­tent of these bituminous sandstones is 5% (i.e., silt and clay sized particles less than 44 microns in diameter and those that pass through a 325 mesh screen). However, the "fines" content can easily be increased to 20% by grinding.

0 65

\Z&

The minor framework grains represent 3% of the sandstones and consist of 9.5% mica, 0.4% accessory minerals and 2.1% allochems. Mica is a principal minor framework mineral. The mica group consists of 75% muscovite, 20% biotite and 5% chlorite (Remy, 1984). Medium to fine grained muscovite is the only readily distinguishable megascopic minor framework mineral and has been used as a partial guide to help distinguish DC deposits (<1% muscovite) from DMB deposits (1-3% muscovite). Commonly the muscovite is crinkled. Thin section work by Remy (1984) indicates this crinkled texture is caused by compaction,

The cementing agents for the bituminous sandstones consist of roughly 1% calcite, 2% dolomite and 2% hematite. The 3.8% hematite cement in surface samples of Banks (1981) is much higher than the 1.0% of hematite in core samples of Remy (1984) and reflects the oxidation differences between the surface and subsurface samples. Detailed petrographic work by Remy (1984) indicates that carbonate cements are the most abundant cement in all sandstones, make up 3.2% of the rock and consist of 1.2% calcite and 2% iron-rich dolomites. Calcite cement is more abundant in the beach to beach bar deposits. Iron-rich dolomite cement is more abundant in the distributary mouth bar and distributary channel deposits. Muller, et al (1972) state that within lake deposits calcite is a primary carbonate and dolomite is a secondary carbonate. In the Sunnyside Tar Sands area carbonate grains are localized within beach to beach-bar sandstone deposits and contain an average of 6.4% ostracods, 5.8% carbonate intraclasts and trace oolites (Remy, 1984). Carbonate grains are not common in distributary channel and distributary mouth bar deposits.

Within the northern and southern margins of the Uinta Basin the bituminous sandstones of the Green River Formation have different mineral compositions. In the southern margins the bituminous sandstones are of a feldspathic petrofacies while those in the northern margins are of a quartzolithic petrofacies (Dickinson, Lawton and Inman, 1986). The feldspar-rich bituminous sandstones of Sunnyside and P.R. Spring (Figures 1 and 11) were derived from a source area to the south in the Uncompahgre Uplift. The quartz-rich bituminous sandstones of Raven Ridge were derived from a source area to the north in the Uinta Mountains. The tar sands at Whiterocks and Asphalt Ridge (Figures 1 and 11) do not exist within the Green River Formation.

Interpretation

In the Sunnyside delta complex the bituminous sandstones can readily be separated into sheet sands and channel sands on .the basis of basal scour and sheet-like geometry. Separation of sheet sands and channel sands into specific sandstone

66

depositional environments is more difficult and more subjective. The rocks of this lacustrine delta complex contain a multiplicity of sedimentology characteristics. Based on specific multiple criteria the sandstone depositional environments are interpreted to represent distributary channels (DC), distributary mouth bars (DMB) and beach (B) to beach bar (BB) deposits. The specific multiple criteria are based on sedimentary structures, biota and lithology that have developed while logging core and measuring sections. Grain size is not a diagnostic feature as all the sandstones are megascopically similar. Distributary channels (DC) and beach (B)/beach bar (BB) deposits can be considered as the two end members with distributary mouth bars (DMB) transitional to both. DMB's can fan out and split into an upper and lower BB deposit.

Distributary channels (DC) are distinguished by the following criteria: basal scours; channel lag deposits or IFC's (intraformational conglomerates) with nonbituminous shale and siltstone intraclasts; sedimentary structures that are largely trough cross bedding at the base and planar bedded at the top; one precent muscovite content; no or very limited bioturbation; and an association with red shales. DCs are shoestring-like with abrupt lateral changes and are often 30-250 feet thick. DC's exist in the basal portions of the tar sands.

Distributary mouth bars (DMB) are distinguished by the following criteria: basal and internal IFC's with limestone intraclasts including transported algal stromatolites; sedimentary structures that include flip-flops of either planar beds or trough cross bedding at the base and the other at the top; an upward fining sequence of sedimentary structures with trough cross bedding -»• horizontal bedding -*• ripple laminations; high concentrations of 2-3% muscovite and muscovite laminae; internal distorted bedding caused by liquefaction; local rich bitumen content that is sap-like and often oozes from outcrops with southern exposures; local fish scales; occasional zones a few inches thick with numerous ostracods in a sand matrix; bioturbation near the top; an association with green or mixed colored shales, and internal limestone-rich pods. These lime­stone pods have a distinct light brownish color 5YR 6/4 to 5/6 and are weakly bituminous. The limestone pods are of secondary origin as deformed bedding extends through these pods in MS-61, top Zone 38 at -835 feet (see MS-61 strip log). DMB's range in thickness from some 30-220 feet and are abundant in the middle portion of the tar sands. In MS-54 Zones 37 and 38 have a combined thickness of 222 feet and represent continuous deposition associated with a DMB.

Beach (B) to beach bar (BB) deposits are distinguished by the following criteria: predominance of planar bedding with some trough cross bedding; algal limestones unconformably

67

below the base; thin internal biota trash zones; nearby mud-cracks; adjacent green, gray or mixed colored shales. These deposits are thin laterally continuous sheets often 5-15 feet thick. B to BB deposits represent a continuum of the sub-aerial beach to subaqueous shoreface to nearshore deposits. In addition the beach bar deposits may grade laterally into shoaled areas of distributary mouth bar deposits. B and BB deposits are more prevalent in the upper portions of the tar sands and distal portions of the delta complex.

A lacustrine delta complex existed in the Bruin Point area during Green River time and was determined from the following criteria: gray, green, red and mixed colored shales; cyclic sequences of sandstone-shale-limestone-unconformity; textural and biological compositional features of the lime­stones; distribution and thickness of sandstones; types of lag deposits; sedimentary structures; texture; and mineral composition. The sandstones were deposited as distributary channels, distributary mouth bars and beach to beach bar deposits in areas near the lake shoreline.

A key task in regard to the numbered tar zones is to determine the sandstone geometry and establish the environment of deposition. Where is this tar sand outcrop located relative to land, shoreline or lake in Green River time? Answers to this question help in the continuing evaluation of the bitumin­ous sandstones at Sunnyside. The interpretation of field data is enhanced by application of thoughts from other authors. First, "The most favorable environmental setting for oil-productive sheet sandstones is marginal marine" (Campbell, 1976, p. 1018). This quotation may be applied to the Sunnyside Tar Sands area by using marginal lacustrine instead of marginal marine. Second, the principal of lateral migration or lateral accumulation is one of the single most important concepts associated with deltaic sandstone deposition (Weimer, 1976) . Third, sheet sands as described by Stear (1983) are products of lateral channel migration and the bulk of sedimentary structures include trough cross bedding and horizontal bedding. Lateral migration is a significant factor in the development of sheet sands in the Sunnyside Tar Sands area, Fourth, Dean and Fouch (1983) show some excellent colored photographs of lacustrine environments. In their Figure 66 (p. 126), which is located in Nine Mile Canyon of the West Tavaputs Plateau, channel-formed sandstones in a marginal lacustrine facies overlie and locally scour stromatolitic algal boundstone; the sandstones represent fluvial deposition on top of a carbonate-: complex that formed in shallow waters of Lake Uinta. Similar cycles of deposition are frequent in the Sunnyside delta complex.

Field and literature studies indicate that the depositional environments of the Athabasca Oil Sands are distinctly different than those of the Sunnyside Tar Sands. The Athabasca Oil Sands

68

were formed from a mega-scale meandering channel deposit near an estuary and are characterized by a consistent vertical sequence of sedimentary structures in four distinct facies associated with the McMurray Formation. As described by Mossop (1980), Mossop and Flach (1982 and 1983) and Flach (1984) these four distinct facies from bottom to top are: (1) a locally developed basal scour with lag deposits 0-30 feet thick; (2) a lower member of thick bedded sand 3-24 feet meters thick with trough cross bedding; (3) a 17-22 meter thick middle member with thick sets of solitary epsilon cross strata. The epsilon cross strata are very large scale uniformly dipping planar-like beds with average dips of 10-12 degrees; and (4) a 15 meter thick upper member with horizontal bedding. The key characteristics of a meandering channel deposit as stated by Mossop and Flach (1982, p. 12) are a well defined scour base; upward fining in the sand fraction with an upward increase in the proportion of shale; diminishing flow regime upward in the sequence; and unidirectional paleocurrents essentially parallel to the strike of the epsilon cross strata. The fining upward trend of grain size in the oil sands was determined by standard grain size analysis and is due largely to an upward increase in the proportion of silt and shale partings associated with clay drapes (Mossop and Flach, 1982).

69

DRILL HOLE AND MEASURED SECTION SYNTHESIS

Since 1980 over 63,000 feet of project drill core have been logged and over 46,000 feet of measured sections have been completed. This combination of outcrop and drill core has been an indispensable aid to define the geology and numbered tar zones in the project area. Field work associated with measured sections in peripheral areas has located the Mt. Bartles-Bruin Point segmented flexure. Both field work and drill core have established important markers within the Parachute Creek Member. These important markers permit distinct correlations to be made with the established geological framework of the Uinta Basin shown in Figure 12.

Repeated cycles of sandstone -*• shale •*• limestone •*• erosion exist in all drill holes and measured sections. These cycles end with an unconformity at the top of a limestone interval. Next a sandstone interval is deposited which grades upward into a shale interval that in turn grades upward into a lime­stone interval which is followed by another erosion interval. Then the sandstone-shale-limestone-erosion cycle is repeated. At least fifteen major and eleven minor cycles of these repeated intervals exist in the Sunnyside Tar Sands area.

The explanation for these repeated cycles is either structural or climatic. Structural evidence of intermittent and repeated uplift is not evident. The repetition of these sandstone-shale-limestone-erosion cycles is caused by climatic cycles. Influxes of sand are associated with wet conditions and high lake levels. The limestones developed during dry conditions and low lake levels. Milankovitch climatic cycles of roughly 100,000, 40,000 and 20,000 years are caused by changes in the earth's orbital geometry (Berger, A., et al, 1984 and Hays, et al, 1976). Milankovitch climatic cycles are the most probable cause of the repeated sandstone-shale-limestone-erosion cycles that exist within the Green River Formation. The terminal Eocene event was a major decrease in temperature of 10-12°C within one to two million years (Wolfe, 1978). For the Bruin Point area paleolatitudes of 23°-30°N are inferred from flora evidence by MacGinitie (1969), while maps by Habicht (1979) indicate paleolatitudes near 40°N.

A brief geological story describes the conditions associated with Milankovitch climatic cycles that helped to form the Sunnyside delta complex. At the time of an uncon­formity the lake level was low and erosion occurred to form minor scours in the limestones. Then the wet portion of the climatic cycle began and caused the lake water levels to rise with an influx of fluvial-deltaic sands. The rising lake level helped to spread the shoreline deltaic sands into sheet sands. Then as the lake level continued to rise shales

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were deposited. Later as the dry portion of the climatic cycle began to dominate, sediment influx decreased and the limestones started to form in shallow clear waters. As the dry climatic cycle continued, the lake level continued to drop. Then carbonate mud flats formed and eventually were exposed to erosion to form an unconformity. Then the depositional sequence of sandstone-shale-limestone-erosion was repeated again.

These repeated cycles of deposition accumulated to form a repetitious vertical succession of sedimentary units. Vertical profile refers to the vertical stratigraphic succession of sedimentary structures and depositional environments. Sedimentary environments that are areally and laterally adjacent to each other succeed each other vertically and form a vertical sequence that defines depositional sequences (Visher, 1965 and Reineck and Singh, 1980) . In the Sunnyside Tar Sands area the deposi­tional sequence is sandstone-shale-limestone-erosion. This vertical profile represents a large scale fining upward sequence indicative of transgressive environments. Within this overall transgressive system the sandstones represent a fluvial-deltaic regressive system. Thus the vertical profile contains an early regressive part and a later transgressive part followed by an unconformity. This vertical profile oscillated back and forth at least fifteen times in the Bruin Point area to form a stacked sequence of channel sands and sheet sands at the shoreline of ancient Lake Uinta.

Drill Hole Data

Over 47,000 feet of Amoco drill core has been logged during five drilling seasons, and preservation of this data is important for continued synthesis and mine model studies. Data from these yearly records has been used to determine the lithology of the Sunnyside Tar Sands area (see Table 4). The yearly totals of the five Amoco drilling seasons along with the relogging of drill core from Mono Power drill seasons of 1982 and 1983 are tabulated below:

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Logged Amoco Drill Holes Total Year • Footage

1980 1981 1982 1984 1988

1,4,8-11* 12,13,14,16,17,21,22,24,26** 31-48*** 49-54 and 60-63**** 64-72 and CD-I,2,3

Mono Power Drill Holes

7268 9208 11720 7364 11858 47418 feet

1987& relogged BP-l,BP-lA,RC-l 13063 1989 RCT 1-14

19 8 9 relogged WCT-3A,WC-3,WCT-4A, SS-NW-1 through 7 2659

15722 feet

Grand Total 63140 feet

Notes: * drill holes 2,3,5-7 were drilled by Amoco Production in 1978 and not included

** drill holes 15,18,20,23 are shallow pilot mine holes in the central area and not included. Drill hole 25 is an angle hole drilled beneath Range Creek and is not included.

*** drill holes 27-30 are"shallow pilot mine holes in the central area and not in­cluded

**** drill holes 55-59 are shallow pilot mine holes in the north area and not included

The status of each drill hole is listed in the yearly report that it was completed and summarized in the 1984 Geologic Summary Report. All holes are securely capped, and the only ones that have open downhole conditions exist on Amoco fee lands. All locks on the property have a common key (Master No. 2405) . In 1980 and 1981 drill holes were secured with either a screw cap or locked cap at surface levels. Since 1982 all holes with two exceptions have been plugged with cement, Shur-gel or Hole Plug and are secured with a labelled screw cap. The two exceptions are drill holes A-71 (dry to 760 ft, open to 1228 ft) and A-72 (open and dry to 612 ft) that exist on Amoco fee land and were left open for possible seismic research. Both these holes have substantial screw caps on 10-20 feet of surface casing. The screw caps require two 2-3 foot pipe wrenches for removal. Six holes contain multiple piezometers that have a 2-3 foot high metal case with a locked cap. The piezometers exist

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in Amoco drill holes A-4, A-10, A-16, A-21, A-24 and A-26 as noted on the Regional Map. Drill hole A-17 (full of water and open downhole to 1015 ft) is an excellent hole for well log research as it is the only drill hole full of water. In drill hole A-17 nonartesian water levels have remained near the top of the 30 foot casing that is tightly sealed with a screw cap. The hole was tested in 1981 and retested in 1984. For ready reference the status of the Amoco drill holes is listed in the following tables:

1980 Exploration Report, 19 81 Exploration Report, 19 82 Exploration Report, 1984 Exploration Report,

1988 Exploration Report,

Table 9 Table 9 Tables 8A & 8B Tables 5A, 5B & 5C (list of all holes to date) Table 2

The location of all drill holes is shown on both the Regional Map and Geology Map. General data on the saturation, elevations and depths of all drill holes is tabulated on the Regional Map. Specific data on numbered tar zones from all project drill holes has been carefully updated and compiled for reference in Tables 1, 2 and 3.

1989 Core Logging

Almost 8,000 feet of Mono Power core from the south area and 2700 feet of core from the Whitmore Canyon area was relogged to establish numbered tar zones and bitumen content. In 1987 core from five Mono Power drill holes was relogged and totalled 4624 feet. The old Mono Power core data base was not equatable to the Amoco data base that is used for computer modeling. Therefore, it was necessary to relog the Mono Power core to equate the two data bases, to properly examine the "hot spot" in the south area, and to evaluate the Whitmore Canyon area.

Of the twenty-two Mono Power drill holes relogged in 1989 twelve are located in the south area, one is located in the central area and nine are located in the Whitmore Canyon area. The south area is located about two miles southeast of Bruin Point, while the Whitmore Canyon area is located about four miles northwest of Bruin Point. The twenty-two drill holes are grouped below by area.

Location

south area central Whitmore Canyon

Number of

holes

12 1 9

Footage

7877 562 2659

11098

Percent of total footage

71 5 24

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Lithology logs at at scale of 1"=10 ft were carefully made from the core of each drill hole in the core shack located in Price. Core logging proceeded at an average rate of 292 feet per day. Later these lithology logs were condensed to form strip logs at a scale of 1"=50 ft. The strip logs for all twenty-two holes are found in Volume III.

Highlights of 1989 Drill Hole Strip Logs

The strip logs represent a synthesis and quick look at the geological data available from each drill hole. The strip logs illustrate the vertical position of the numbered tar zones along with their bitumen content as well as various lithologic data. After completion of the strip logs the high­lights or salient observations were recorded at the base of each strip log. For convenience the highlights of each drill hole strip log by area (central, south or Whitmore Canyon) are listed below.

Central Area (1 hole)

BP-1: Highlights

1. TSAT 131' DSAT >562' MSAT 30' BSAT unk

2. Three thin tar zones (10,21,22) exist within upper portion of hole that was not drilled to base of saturation.

3. Four oil shale zones (R-5,R-4,R-3,R-2) and lower tuff located in 298 ft. thick Parachute Creek Member.

4. Well defined Blue Marker and top of carbonate interval separated by 235 ft.

5. Zone 25 is 24 ft. thick. 6. Hole terminated within carbonate interval

and above major tar zones.

South Area (12 holes)

RC-1: Highlights

1. TSAT 103' DSAT >542' MSAT 42' BSAT unk

2. Three tar zones (10,21,22) within hole that was not drilled to base of saturation.

3. Five oil shale zones (R-7,R-5,R-4,R-3,R-2), Wavy Bedded Tuff and lower tuff all located within 397 ft. thick Parachute Creek Member.

4. Well defined Blue Marker with 0.3" thick coal seam 1 ft. below base of three foot thick R-2 oil shale,

5. Hole stopped about 100 ft. above top of carbonate interval.

74

RCT-1; Highlights

1. TSAT 0 DSAT above collar MSAT 0 BSAT above 9680 ft.

2. All sandstones are nonbituminous. 3. No marker beds within core. 4. The nonbituminous ostracodal packstone to grain-

stone at collar may represent base of carbonate interval,

RCT-2: Highlights

1. TSAT 162' DSAT 10* MSAT 136' BSAT 288'

2. Five tar zones exist between the surface and base of saturation at 288 ft.

3. Zones 31 and 32 represent the "hot spot". 4. Zone 31 averages 20.1gpt over 41.2 ft. and

contains 26.2 ft. of 25.1gpt. 5. Zone 32 averages 18.0gpt over 29.8 ft. and

contains 17.8 ft. of 24.4gpt. 6. No marker beds exist within this drill hole.

RCT-3A: Highlights

1. TSAT 212• DSAT 445' MSAT 130' BSAT 704'

2. Hole contains five numbered tar zones within an upper (205-234'), middle (445-538') and lower (670-685') levels.

3. The 54 ft. thick carbonate interval (382-436') contains Zones 25 & 26, and lies above the most important numbered tar zones (31,32,33).

4. Both the lower tuff and Blue Marker represent distinct marker beds within the Parachute Creek Member.

5. Three oil shale zones exist and represent R-4, R-3 and R-2.

RCT-4: Highlights

1. TSAT 612' DSAT 460' MSAT 97' BSAT 610'

2. Three MSAT's in upper (Zone 21); middle (Zones 31 & 32) and lower (Zone 35) levels.

3. Richest tar zone is 47.5 ft. thick from 460-507 ft. with an average grade of 20.7gpt. This represents the "hot spot" and exists within Zones 31 & 32.

4. Important markers within hole include lower tuff, Blue Marker and carbonate interval.

5. Oil shale intervals include R-3, L-3 and R-2.

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01215

RCT-5: Highlights

1. TSAT 142' DSAT 455' MSAT 93' BSAT 581'

2. Hole contains three major tar zones (21,31,33) with Zone 33 (26.0gpt) within the "hot spot".

3. Blue Marker (at 150 ft.) and 52 ft. thick carbonate interval (378-430 ft.) are the only reliable markers.

4. Oil shale zones cannot be established due to core loss in critical intervals.

RCT-6: Highlights

1. TSAT 292' DSAT 417' MSAT 101' BSAT unk

2. Seven major and one minor tar zones exist within upper, middle and lower levels of the hole. The upper level contains tar zones 21, 22, 23 above the carbonate interval. The middle level, just below the carbonate interval, contains tar zone 31. Tar zones 34, 35, 36, 37 exist in the lower level. Zone 34 is only 7.2 ft. thick but averages 21.2gpt.

3. Important markers include the Blue Marker (coal seam below base of R-2 oil shale) and the 51 ft. thick carbonate interval (356-407 ft.) .

4. Oil shale intervals include R-3 (3.5 ft. thick) and R-2 (5 ft. thick). Within R-3 oil shale two separate algal units (3" algal stromatolite and 4" algal mat) are encased within oil shale intervals.

5. Thin carbonaceous/coal units exist at the top of specific limestones, such as the 6" carbonaceous/ coal unit at 356 ft, (at the top of the carbonate interval) as well as the 0.8" coal at 559 ft. above the top of a nonbituminous ostracodal grainstone.

RCT-7: Highlights

1. TSAT 249' DSAT 444' MSAT 156' BSAT 710'

2. Five major tar zones (11,21,31,33,35) exist and can be divided into four stratigraphic levels: I Above the Blue Marker - Zone 11. II Between the Blue Marker & carbonate interval -

Zone 21. Ill Just below carbonate interval - Zone 31. IV Far below carbonate interval - Zones 33,35.

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76

3. The base of saturation concept is clearly illustrated near a depth of 700 ft. where bituminous sandstones prevail above and non-bituminous sandstones exist below.

4. Marker beds include the Blue Marker at the base of the Parachute Creek Member and the 55.5 ft. thick carbonate interval within the Garden Gulch Member.

5. Oil shale zones include the R-3 {4 ft. thick) and R-2 (4 ft. thick) intervals.

RCT-9: Highlights

1. TSAT 516' DSAT 423' MSAT 356' BSAT 1068'

2. Eight major tar zones of substantial grade exist. below the carbonate interval, and five major tar zones of minimal grade exist above the carbonate interval. Hole is outside of "hot spot" or on northwest perimeter.

3. Marker beds include the Blue Marker at the base of Tgp and the 40.5 ft. thick carbonate interval 240 ft. below the Blue Marker.

4. The Parachute Creek Member contains 24% limestone and two oil shale zones. The R-3 interval is 4 ft. thick and the R-2 interval is 3 ft. thick.

RCT-10; Highlights

1. TSAT 181' DSAT 101» MSAT 62' BSAT 390'

2. Hole contains three major tar zones (31,32&36). Zone 31 is 37.6 ft. thick with 18.3gpt. Zone 32 is 14 ft. thick with 16.6gpt. Zone 36 contains 40 ft. that averages 10,7gpt.

3. This hole is south of and near the periphery of the "hot spot". Zone 31 does contain 22.5 ft. with lO.Ogpt. This 22.5 ft. contains four parts: 6.9 ft. of 23.5gpt; 3.1 ft. of 0.6gpt; 6.5 ft. of 23.0gpt; and 6 ft. of 22.2gpt.

4. The 49 ft. thick carbonate interval (37-86 ft.) is the only marker unit.

RCT-11; Highlights

1. TSAT 208' DSAT 7 21' MSAT 109' BSAT 911'?

2. Five major tar zones are located within the upper, middle and lower portions of the hole. All are of weak to moderate grade.

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77

Zone Thickness Depth Grade in gpt

10 21 22 31 35

33.8 14.0 27.0 33.7 17.2

92 413. 481 721 894

-125.8 3-427.3 -508 -754.7 -911.2

13.1 11.6 16.1 16.4 9.3

3. The hole contains four excellent markers. The 2 ft. thick Wavy Bedded tuff (26.4-28.4) and the 3 ft. thick lower tuff (256-259) are well defined. The Blue Marker @ 401 ft. and the 70 ft. thick carbonate interval (640-710) are also well defined. A six inch carbonaceous unit exists at the top of the carbonate interval.

4. Oil shale units are present and represent the lower portion of the R-8 (upper oil shale zone) ; R-7 (17 ft. thick Mahogany zone); R-5 (17 ft. thick)? R-4 (3 ft. thick); R-3 (4 ft. thick); and R-2 (4 ft. thick Blue Marker). Within R-8 oil shale there is a shale IFC that contains numerous clasts of a soft (hardness=l), grayish to moderate brown colored organic mineral.

RCT-13: Highlights

1. TSAT 269' DSAT 950" MSAT 147' BSAT 1204'?

2. Nine tar sand zones exist but all are of moderate to low grade. Six are major MSAT's (zones 11,21, 22,26,31&32) . Three are minor MSAT's (zones 10, 33,35) .

3. The nine tar sand zones can be divided into three groups. An upper group (Zones 10&11) above the Blue Marker. A middle group (Zones 21&22) below the Blue Marker and above the carbonate interval. A lower group (Zones 26 31,34,33,35) below the carbonate interval.

4. Zone 26 is a beach sand interval instead of the normal lower half of the carbonate interval. Zone 31 is 29.3 ft. thick, averages 17.2gpt and is the richest tar sand zone in RCT-13.

5. The hole is east of Range Creek and does not con­tain any significant volumes of tar sands with grades above 17gpt.

6. The hole contains three important markers - Lower Tuff, Blue Marker and upper half of carbonate interval.

7. The four oil shale zones include the 18 ft. thick Mahogany zone (R-7) , the 25 ft. thick R-5 zone, the 3.5 ft. thick R-3 zone, and the 3.5 ft. thick R-2 zone. The latter is part of the Blue Marker at the base of the 677 ft. thick Parachute Creek Member.

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Whitmore Canyon Area (11 holes)

SS-NW-1: Highlights

1. TSAT 0 DSAT unk MSAT 0 BSAT unk

2. Hole contains three nonbituminous sandstone zones. 3. No marker beds exist.

SS-NW-2t Highlights

1. TSAT 19 8' DSAT 51' MSAT 94' BSAT 383'

2. Hole contains four major tar zones (31,32,35,36). Zone 36 contains the only significant tar sands. The four zones can be separated into upper, middle and lower levels: a) The upper level contains Zone 31 which

is 51.4 ft. thick and averages 7.3gpt. A 10.6 ft. interval averages 12.1gpt.

b) The middle level contains Zones 32,33&35. Zone 32 is 17.7 ft. thick and averages 10.4gpt. Zone 33 is 11.6 ft. thick and averages 6.2gpt. Zone 35 is 9.3 ft. thick and averages 16.8gpt.

c) The lower level contains Zone 36 which is 65.8 ft. thick and averages 17.3gpt. Zone 36 contains a basal portion that is 20.1 ft. thick and averages 25.1gpt.

3. No marker beds exist within the hole. 4. Rare excellent rootlets exist at the top of a

3.5 ft. thick ostracodal packstone/grainstone unit below Zone 36 at depth of 357 ft.

SS-NW-3; Rotary hole, no core

SS-NW-4: Highlights

1. TSAT 143' DSAT 220' MSAT 31' BSAT 372'

2. Hole contains two major tar zones of low grade. Zone 99 (lower part of Zone 36) is 48.9 ft. thick (66.8-115.7) but averages only 3.8gpt. Zone 37 encompasses 89.9 ft. (173.3-263.2) and averages 8.9gpt. Zone 37 contains a 31 ft. thick interval (220-251) that averages 13.7gpt.

3. No marker beds exist. An 18 ft. thick carbonate unit (338.5-356.5 ft.) may have value for local correlation within the Whitmore Canyon area.

01219

79

SS-NW-5: Highlights

1. TSAT 115' DSAT 21' MSAT 82' BSAT 202'?

2. Hole has two major tar zones (99&37) of low grade. Zone 99 is 38.2 ft. thick and averages lO.lgpt with two intervals containing 10.3gpt (12.3 ft. thick) and 12.7gpt (18.2 ft. thick). Zone 37 is 99.9 ft. thick and averages 9.4gpt with two intervals containing 10.2gpt (21.4 ft. thick) and 11.5gpt (30.5 ft. thick).

3. No marker beds exist.

SS-NW-6; Highlights

1. TSAT 0 DSAT n/a MSAT 0 BSAT above collar

2. Hole has no bituminous sandstones. Zone 41 is nonbituminous with analyzed values of 0.0 to 0.1wt% bitumen.

3. No established marker beds exist. The local 20 ft. thick limestone unit in the Whitmore Canyon area exists near the top of the hole.

SS-NW-7: Highlights

1. TSAT 157' DSAT 49' MSAT 39' BSAT 109'?

2. Hole has two major tar zones (99&37) that both contain subgrade bitumen values. Zone 99 is 91.2 ft. thick and averages 6.7gpt. Zone 99 contains one 10 ft. interval of 10.6gpt. Zone 37 is 57.8 ft. thick and averages 8.9gpt. Zone 37 contains a 28.6 ft. interval of 10.2gpt.

3. No marker beds exist.

WCT-3A: Highlights

1. TSAT 173' DSAT 18' MSAT 99' BSAT 278'

2. Two thick tar sand zones exist in the upper portion of the hole. Zones 36&99 combined are 109,5 ft. thick (18-127.5) and average 13.5gpt. Zone 37 is 93.3 ft. thick (168.4-261.7) and averages 5.3gpt with the upper 46.6 ft. averaging 6.2gpt and the lower 26.7 ft. averaging 7.5gpt.

3. No marker beds exist in the hole. 4. The middle and lower portions of the hole contain

two separate 20-30 ft. thick carbonate units. 5. Within the lower carbonate unit near 530 ft. a

0.5" lean oil shale exists above a nonbituminous ostracod grainstone. Did an algal bloom kill off the ostracods and oil shale form from the algal ooze?

80 012

WCT-4; Highlights

1. TSAT 50' DSAT >145' MSAT 0 BSAT >145'

2. Hole contains portions of three tar sand zones. All tar zones are either too thin (<10 ft. thick) or too low in grade (<10gpt) to constitute an MSAT.

3. No marker bed exists,

GN-13; Highlights (no core available, based on GN lithology log in Mono Power files)

1. TSAT 226' DSAT 71' MSAT 181' BSAT 372'

2. Four tar zones (31,35 36,99) exist bewteen 46-372 ft. Some 25 ft. of Zone 31 averages about 8wt% bitumen or 19gpt. Some 50 ft. of Zone 35 averages about 7wt% bitumen or 17gpt. Some 30 ft. of Zone 36 averages about 12wt% bitumen or 28gpt. Some 15 ft. of zone 99 averages about 10wt% bitumen or 24gpt.

3. The lower portion of the hole contains two thick nonbituminous sandstone intervals of Zones 37&41.

4. No marker beds exist within the hole. 5. Original logs show a 60.5 ft. thick limestone from

570.5-631. This is a thicker limestone than exists anywhere in the entire project area and must be incorrectly logged. Stratigraphically this poorly logged interval cannot be the 70 ft. thick carbonate interval located 250 ft. below the Blue Marker as no portion of the Parachute Creek Member exists in the drill hole.

6. Sandstone environments estimated as no sedimentary structures included in original log.

GN-14; Highlights (no core available, based on GN lithology log in Mono Power files)

1. TSAT 278' DSAT 38' MSAT 167' BSAT 484' or 9236'

2. Four major tar zones (31,32,35,36) which each average about 8wt% bitumen or 19gpt. All exist within the first 400 ft. Tar zone 37 exists between 435-484 ft. and averages about 2wt% bitumen or 5gpt. Note: Zones 36&99 were combined.

3. Below 484 ft. numerous nonbituminous sandstones exist.

4. No marker beds exist within the hole.

81 01221

5. Original logs show a 49 ft. thick limestone from 775-824 ft. Since limestones are not this thick anywhere in the entire project area, the lithology was reinterpreted from scanty lithology data as interbedded limestones and shales. This 49 ft. interval does not represent the carbonate interval located 250 ft, below the Blue Marker as no portion of the Parachute Creek Member exists in the hole.

6. Sandstone environments estimated as very limited sedimentary structures included in original logs.

Measured Section Data

Over 46/000 feet of measured sections have been completed during eight field seasons. This outcrop information has been vital to the geological interpretation of the Sunnyside Tar Sands deposit. The yearly total of completed measured sections is listed below:

Year Measured Section Vertical Height

1980 1981 1982 1984 1986 1987 1988 1989

1- 6 7-11

12-17 18-26 27-44 45-56 57-59 60-61

6437 4105 3930 6966

12365 8391 1533 2316

Total 46043 feet

Measured sections are completed in a two step process with a 100 foot nylon cord. First, the geometry of the slope and vertical height of each interval is determined with a clinometer and plotted on graph paper. The interval measured is commonly 100 slope feet unless interrupted by a vertical cliff. The entire measured section is continuous and made up of some ten to thirty recorded intervals. Second, the lithology is easily recorded on the graph paper by notation of the single foot marks on the 100 foot tape. The surface gamma ray readings are taken at regular painted intervals on the 100 foot tape and recorded in a separate book. The lithology and gamma ray readings are completed before the 100 foot tape is removed for the next upslope interval. The top or bottom of each section is preferably tied to an established topographic feature or drill hole. This project improvised method of measuring sections is both accurate and time effective. Measured sections can be completed in one to three days.

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The cumulative thickness of MSAT's (main saturated zones) differs within different portions of the Sunnyside delta complex. The locations of all measured sections were categorized by proximal, medial and distal positions within the Bruin Point, Dry Canyon and Whitmore Canyon subdeltas. Proximal portions are within ±0.5 miles of the Roan Cliff face. Medial portions are within 0.5-1.5 miles downdip of the Roan Cliff face. Totals of cumulative MSAT thickness by proximal, medial and distal position through 1988 are listed below:

Cumulative MSAT Thickness

Subdelta Proximal Medial Distal

Bruin Point 342 109 39 Dry Canyon 231 81 6 Whitmore Canyon 122 21 0

This data shows dramatic differences of MSAT thickness by subdelta position. Clearly the proximal portions near the Roan Cliffs contain the thickest accumulations of saturated sandstones. The decreases from proximal to medial to distal are pronounced.

The Bruin Point subdelta contains the largest volumes of saturated sandstones. The Dry Canyon subdelta contains about thirty percent less than the Bruin Point subdelta. The Whitmore Canyon subdelta contains almost sixty-five percent less than the Bruin Point subdelta. The proximal, medial and distal positions of the subdeltas also roughly correspond to the western, central and eastern segments of the flexure. Both the proximal deltaic position and the western segment of the flexure contain the highest concentrations of bitumen (see Tar Sand Isopach Map).

Thickness values of numbered tar zones within proximal, medial and distal portions of three subdeltas through 1988 are listed below:

Average Thickness of Numbered Tar Zones

-Subdelta Proximal Medial Distal

Bruin Point 43 27 22 Dry Canyon 44 23 17 Whitmore Canyon 30 25 17

This data indicates definite thinning of the numbered tar zones from proximal to medial to distal portions of the subdeltas.

83

01223

Highlights of 1989 Measured Section Strip Logs

The two measured sections completed in 1989 illustrate significant contrasts based on deltaic and structural positions. MS-60 is located in a distal portion of the delta within the West Tavaputs Plateau and exists in the eastern segment of the flexure. MS-61 is located in a proximal portion of the delta along the Roan Cliffs and exists in the western segment of the flexure.

After the completion of each measured section field high­lights were noted. After completion of the strip log these field highlights and other salient data were recorded at the bottom of each strip log (see Volume III). For convenience these highlights are listed below.

MS-60; Highlights

1. TSAT 159' DSAT n/a MSAT 0 BSAT 897'

2. Four tar zones exist but none qualify as an MSAT (i.e., at least 10 ft. thick with lOgpt) as they are all well below grade.

3. Base of saturation established within tar zone 35. 4. Oil shale zones R-7, R-5 and R-2 located within

349 ft. thick Parachute Creek Member. 5. Blue Marker well defined at base of Parachute

Creek Member. 6. Carbonate interval well defined with top located

256 ft. below Blue Marker and within the 769 ft. thick Garden Gulch Member.

MS-61; Highlights

1. TSAT 448' DSAT 396' MSAT 336' BSAT 1068'

2. Eight major tar sands exist. Zones 21&25 exist between the Blue Marker and the carbonate interval. Six major tar zones (31,33,36 37,38&41) exist below the carbonate interval and are 25-73 ft. thick with outcrop grades of ll-17gpt. zone 35 is 9 ft. thick and averages 14gpt.

3. Carbonate interval is poorly exposed and lacks the characteristic orange color so readily apparent in West Tavaputs Plateau. In MS-61 carbonate Zone 25 is a sandstone beach.

4. R-5 and R-2 oil shale zones located. The lower oil shale zone contains outcrops of the dinner plate oil shale (R 2) associated with the Blue Marker. The upper oil shale zone in the road is R-5 based on the following:

01224 84

a) 140 ft. above Blue Marker. b) Oil shale in road is some 600 ft. downdip

from R-2 outcrop. c) 140' separation plus 60' dip compensation =

200 ft. as stratigraphic difference between these two oil shales.

The numerous oil shale outcrops adjacent to the flat road between drill holes A-11, A-8 and top of MS-61 are R-5 oil shale beds since vertical stratigraphic separation between R-2 and R-5 oil shale zones averages 190 ft. (note: check with Figure 15).

85

01225

WELL LOGS

Whenever possible three well logs were run on each drill hole to obtain data for identification and correlation. The three desired logs include gamma-density-caliper, focused electric and multi-channel sonic. Attempts to complete the three logs were dependent on downhole conditions and fluid levels. The gamma-density-caliper log can be made in either air or fluid filled holes. But the focused electric and multi­channel sonic logs must have fluid in the hole for the sonde to function. The gamma log has proved to be the most beneficial log for geological investigations within the Sunnyside Tar Sands deposit. A summary of the core and well log responses is listed in Table 7.

Since 1981 the well logs have been completed by BPB Instruments, Inc. of Grand Jucntion, Colorado. Mono Power also utilized BPB Instruments. These logs are of excellent quality and have single print-out sheets for each log. The BPB logs were initially run at a scale of 1"=10' to correspond to the scale of the detailed core logs completed on each drill hole. The logs were also reduced to a scale of 1"=50' to correspond to the scale of all strip logs. Copies of the 1"=50' well logs and strip logs were supplied to the BLM as required by the hydrocarbon lease.

Gamma-Density-Caliper

The gamma-density-caliper log is obtained from one tool and utilized to test natural radioactivity levels, determine differences in rock density and check the uniformity in hole size. This tool or sonde operates effectively in cased or uncased holes and in air or fluid media.

The gamma log reflects natural radioactivity which is usually low in sandstones and limestones but higher in shales. Within the Sunnyside Tar Sands area the gamma responses commonly range between 100-200 API units with local kicks in the range of 400-800 and sometimes up to 1,000. Correlations of high gamma responses with the core logs indicate high responses are usually related to biota concentrations of black fish scales, bone fragments and/or ostracods.

The gamma log is often used as a sand and shale indicator. Bituminous sandstones have distinct gamma ray responses of 100±30 API units. These values form an identifiable bulge at sandstone intervals. Gamma responses in shales range from 70-170±20 API units (see Table 7). Correlation of the different colored shales (gray, green, mixed and red) with gamma responses shows that each colored shale type has a distinct set of values (see Table 7). When core is not available, specific shale identification is possible. Knowledge of different colored shales is important for stratigraphic correlation.

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The density log is a reflection of the electron density of the rock material. Density values can be read directly from the log and are relative in an air filled hole but absolute in a water filled hole. Typical density values are listed in Table 7. The low density values of oil shale and their patterns are particularly helpful for identification and correlation. The density patterns of the R-7 oil shale (see Figure 16) and the R-5 oil shale (see Figure 20) are uniquely different and can be used for identification as discussed separately in the Parachute Creek Member portion of this report.

The caliper log indicates the size of the drill hole. All holes are NX size and 2.980 inches in diameter. With few exceptions the three inch hole diameter remains constant and open. The exceptions are caused by minor caving and voids associated with the Parachute Creek Member.

Multi-Channel Sonic

The sonic log represents a recording of the time re­quired for a sound/acoustic wave to travel through typically one foot of rock formation. This internal transit time is given in microseconds per foot. The transit time is a function of the lithology, porosity and type of fluid in the pore space; if the lithology is known, good porosity values can be obtained by utilizing the sonic log (Schlumberger, 197 2).

Within the Sunnyside Tar Sands area the interval transit time has a range from 65-100 microseconds per foot (see Table 7). The sonic log has been utilized to obtain primary porosity values. Primary porosity values of bituminous sandstones and limestones were determined by (1) obtaining the interval transit time in microseconds per foot from the sonic log, (2) determining the litholoqy from the drill hole core logs and (3) utilizing the log interpretation charts from Schlumberger (1972) . Porosity values determined -from sonic logs are considered by the well logging industry to be better and more specific than porbsity values determined from density logs. The bituminous sandstones have a porosity range between 20-34% with 25-27% porosity as the most prevalent. The higher porosity values appear near the top of distributary mouth bar deposits, wnile some of the lower porosity values are associated with beach to nearshore bar deposits. The bituminous limestones have porosities that range from 15-26*. Porosities of 20-26% are commonly associated with ostracodai limestones, coquinas or biomicrites. Porosities of 15-20% are commonly associated with the more dense limestones or micrites. The various porosity values are essentially the same as porosity values determined by Core Labs.

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Focused Electric

Resistivity logs are obtained by passing a current through the rocks, measuring the voltages and determining the resistivity values. Conventional electric logs are greatly affected by conditions in the borehole and adjacent formations. These variable conditions can be minimized by the use of focusing currents to control the path taken by the measured current (Schlumberger, 1972). The focused-electric logs must be completed with fluid in the hole and represent a calibrated resistivity of the rock units. Impermeable beds such as a shale are electrically conductive due to the presence of ion-bearing water and have low resistivity values; permeable beds are less electrically conductive and have higher resistivity values (Merkel, 1979) . Within the Sunnyside Tar Sands area shales tend to have low resistivity values that range from 40-300 ohm/meters (see Table 7). The presence of hydrocarbons causes higher resistivity values since hydro­carbons are normally insulators (Schlumberger, 1972). Within the Sunnyside Tar Sands area bituminous zones cause resistivity values to increase dramatically with values up to 10,000 ohm/meters for bituminous limestones (see Table 7).

Tar Sand Analysis

The bitumen content of tar sands can be done by direct and indirect methods. Direct analysis of core provides the best measurements of bitumen content and has been the only method utilized for the Sunnyside Tar Sands project. The indirect method utilizes the focused-electric, neutron and density logs with a computer program to determine the grade of bitumen. Drill holes within the Sunnyside Tar Sands deposit are rarely full of water after the drilling is terminated. The indirect method was first attempted in 1984 but the low fluid level in many drill holes presented so many problems all attempts to fully investigate the indirect method were terminated. During the 1988 drilling program fluid levels in twelve drill holes ranged from -92 ft to -1179 ft with an average fluid level of -538 ft. Drill core and direct core analysis will always be necessary for reliable results of bitumen content.

Well Log Interpretation

In a clastic sequence well log patterns often reflect changes in the grain size distribution of sand-silt-clay content. The well logs that best reflect the sand-silt-clay content are the gamma ray (GR) and spontaneous potential (SP). The GR and SP log curves are controlled by grain size distribution, have been recognized as sedimentation curves and can be used for sedimentological analysis to determine depositional settings (Serra and Sulpice, 1975; Merkel,

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1979; and Cant, 1984). The GR log has been used through­out the Sunnyside Tar Sands project as it requires no fluid in the hole. The SP log requires fluid in the hole.

In both the GR and SP logs the so-called shale line is nearest the hole, while the so-called sand line is further away from the hole. Thus portions of the curve nearest the hole represent a high shale content and portions of the curve away from the hole represent a high sandstone content (see Figure 24). Deflections in the curve represent changes in energy conditions and grain size. Abrupt or large deflections in the curve indicate rapid changes in energy levels during deposition that result in rapid grain size changes. Small deflections indicate small changes in the energy conditions that result in gradual changes in grain size. Smooth patterns indicate homogeneity and relatively constant energy levels with limited change in grain size. Serrated patterns indicate heterogeneity and fluctuating energy levels with frequent changes in grain size (see Figure 24).

The GR or SP log curves have three fundamental shapes: (1) bell; (2) cylinder; and (3) funnel. Each shape developes under specific conditions and is associated with certain depositional settings. Each type of log curve is not absolutely unique to one environment as seen in Figure 25.

(1) The bell shaped curve is shown in Figures 24 and 25 and represents a fining upward sequence. The abrupt basal deflection is associated with an unconformity and a rapid increase toward the sand line. The curve then slowly continues to slope inward toward the shale line and indicates a con­tinuing decrease in energy conditions with a continuing decrease in grain size. This fining upward sequence is commonly associated with channel sands and transgressive sands. Bell shaped curves exist within the Sunnyside Tar Sands deposit. Near the base of the tar sands package they represent channel sands. Near the upper portion of the tar sands package and above it, the bell shaped curves represent transgressive sands.

(2) The cylinder shaped curve is shown in Figures 24 and 25 and is characterized by abrupt changes at both the top and bottom of the curve with a near-vertical smooth or serrated edge along the sand line. This type of curve represents a well sorted sand with uniform grain size. This curve is indicative of sedimentation related to both fluvial and regressive (prograding) processes and is associated with distributary channels of delta complexes (Merkel, 1979). Cylinder shaped curves are the most abundant type of GR log curves within both the Bruin Point and Dry Canyon subdeltas.

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(3) The funnel shaped curve is shown in Figures 24 and 25 and represents a coarsening upward sequence. The bottom of the curve shows a gradual slope outward from the shale line toward the sand line and indicates a continuing increase in energy conditions with a continuing increase in grain size. The top of the curve has an abrupt deflection back to the shale line. This coarsening upward sequence is commonly associated with distributary mouth bars in the delta fringe. Funnel shaped curves are not abundant in the Bruin Point or Dry Canyon subdeltas but do exist near the top of the tar sands package.

The shapes of the well log curves have been utilized to help delineate sedimentation patterns and help define environments of deposition. Bell shaped curves indicate meander belt channel sands within the fluvial systems that extend into the upper delta plain. Cylinder shaped curves indicate distributary channels within the lower delta plain. Funnel shaped curves indicate distributary mouth bar deposits in the delta fringe. The Bruin Point-Mt. Bartles area is located on the shores of ancient Lake Uinta where the upper and lower portions of the delta plain and delta fringe were confined to a relatively short horizontal distance. Distributary mouth bars form at fluvial outlets where the flow spreads laterally and the deposits are modified by waves and long shore currents (Berg, 1986). In the Sunnyside Tar Sands area the waves and shore currents were significant factors in ancient Lake Uinta, while tides and slumping were insignificant factors.

In the Sunnyside delta complex shoreline environments prevailed and the DC, DMB and B-BB deposits have been modified by lake shore processes. Weakly modified cylinder shaped curves are the most prevalent type of well log curve. Bell shaped curves exist near the base of the tar sands, cylinder shaped curves prevail near the middle portion of the tar sands and funnel shaped curves are present in the distal portions of the tar sand deposit. Beach and nearshore bar deposits tend to have a serrated cylinder shaped or a weakly defined funnel shaped curve. High gamma responses exist at the base of numbered tar zones with a ninety percent frequency of occurrence (John Rozelle, personal communication) and these high gamma responses commonly reflect limestone units. The presence of limestones beneath most bituminous sandstones indicates the proximity to an ancient shoreline.

Within the Sunnyside Tar Sands area outcrops, drill core and well logs have been used to study lithology, sedimentary structures and biota. All these factors have been used to determine the various markers and environments of deposition associated with the Sunnyside delta complex.

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SURFACE GAMMA RAY LOGS

The surface gamma ray logs that were completed along measured sections have proved to be highly valuable for determination and correlation of numbered tar zones and de­lineation of marker horizons. The gamma ray readings are obtained from a portable 3.3 pound Urtec gamma ray spectrometer. The idea to use this exploration method evolved from two factors. First, the successful use of gamma ray well logs to establish numbered tar zones and, second, a short article by Chamberlain (1984) describing the successful use of surface gamma ray logs for correlations in areas of abundant outcrops and sparse well control.

In 1986 four old measured sections were selected and reoccupied to evaluate the validity of this new surface exploration method. A methodology was developed and correla­tions of surface gamma ray logs with downhole gamma ray logs from Amoco drill holes was completed. After encouraging results the used Urtec minispec UG-135 was purchased for the project and utilized in MS 27-61.

The field method includes the following three items: (1) Select a base station at least thirty feet from the vehicle and take a reading at the beginning and end of each day. Adjustments to recorded readings should be made if significant differences exist. No adjustments have been necessary from 1986-1989 as the diurnal changes are ±10cps. (2) Readings are taken 6 inches above the ground or 6 inches away from an outcrop to maximize reliable and consistent results. Gamma ray values are read off the digital readout for the first full 10 second period and recorded in a notebook. The meter mode is set at tc(10), which is the ten second count mode. The audio switch is kept at 250cps for normal back­ground. High gamma ray values near 400-500cps cause the instru­ment to release a high pitch sound. When no noise occurs the gamma ray values are below background levels and the audio switch can be put to a lower level. Care should be taken to check for higher readings in nearby outcrops. (3) Readings are taken at consistent slope distances of 5/ 10 or 20 foot intervals along the 100 foot tape, depending on the desired reading interval, steepness of slope and differences in lithology. Any anomalously high or low readings should be recorded regardless of the footage.

The surface gamma ray values range from 180-250cps with normal values of 250-300cps. Values of 200-230cps commonly exist in the Parachute Creek Member. Values less than 200cps are associated with oil shale. Values greater than 350cps are considered anomalous and termed spikes, kicks or peaks. Gamma ray values from the minispec are

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recorded in cycles per second (cps), while gamma ray values from well logs are recorded in API units (abbrev. of American Petroleum Institute). Calibration of cps to API units can only be accomplished at the API test pit in Houston.

Later strip logs at a scale of 1"=10* are made of these recorded surface gamma ray values. The strip logs commonly show distinct patterns and at least three spikes of high gamma ray values per measured section. The gamma ray patterns, tar sand intervals, detailed lithology and environments of deposition are all utilized to correlate intervals and select numbered tar zones. The minispec is invaluable for correlation of measured sections as it establishes definite picks and removes the guess work. When the detailed surface gamma ray log on the MS-59 strip log is compared with gamma ray well logs in Figures 21A, 21B and 31C, it is clear that the gamma ray patterns of the Blue Marker are nearly identical (see 1988 Exploration Report for strip log and Figures) . The detailed surface gamma ray logs coupled with detailed measured section data are a powerful field method to establish numbered tar zones and locate marker horizons.

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GEOCHEMISTRY

The oil shales in the Sunnyside Tar Sands area repre­sent Type I kerogen as they contain megascopic and microscopic evidence of algal structures. Type I kerogen is derived from lipid material of algal origin. These oil shales formed in shallow lacustrine environments with a weakly alkaline pH and a slightly reducing Eh. The bitumen in the tar sands was derived from the Tertiary oil shales of the Green River Formation that exist in deeply buried portions of the Uinta Basin. The bitumen is biodegraded and thermally immature.

Kerogen Type

Three types of kerogen have been defined by geochemists and are dependent on the type of organic matter in the source rocks. Type I kerogen is sapropelic, derived from lipid material of algal origin that formed in lakes and is dominated by linear chemical structures with long chains. Type I kerogens have very high capacities to generate liquid hydrocarbons. Type II kerogen is sapropelic, made up of plant and animal lipids of marine origin and is dominated by polycyclic chemical structures. Type II kerogens have high capacities to generate liquid hydrocarbons. Type III kerogen is humic, made up of plant cell material of terrestrial origin and dominated by aromatic or closed chain chemical structures. Type III kerogens have low capacities to generate liquid hydrocarbons and mainly generate gases. The differences in origin, chemical characteristics and oil potential of these three types of kerogen are shown in figure 26. Lipids represent fats, waxes and fatty acids, while woody tissue consists of lignin and cellulose (a polysaccharide). Since aquatic plants are supported and protected by water, they do not need woody tissue for support or waxes on leaves to reduce desiccation by heat and evaporation. Kerogens derived from sapropelic material have a different evolution path and final hydro­carbon product than kerogens derived from humic matter. Above summaried from Durand (1980), Tissot and Welte (1978), Hunt (1979), Waples (1985) and Stack, et al (1982).

The three types of kerogen consist predominantly of C, H, and 0 and their evolution paths are commonly shown on Van Krevelen diagrams. For example, the organic composition of the Mahogany oil shale zone in the Piceance Creek basin is C=80.5, H=10.3, 0=5.8, N=2.4, X=1.0 (Smith, 1983). The Van Krevelen diagram contains plots of H/C vs 0/C atomic ratios and represents the most suitable method for processing elemental analysis (Durand, 1980). Figure 27 shows some of the basic concepts of the Van Krevelen diagram including H/C vs O/C atomic ratios,' chemical structure during kerogen evolution and directions of losses in CH4, H2O and CO2.

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The thermal decomposition of kerogen produces bitumen that in turn thermally decomposes into crude oil (Waples, 1984). Bitumen from Type I kerogen has a marked aliphatic chemical structure and linear carbon chains between C-3n-C4n as well as n-alkanes of the C30+ range (Durand, 1980). Type I kerogen should contain mostly paraffins, some naphtenes and aromatics as summarized by Stark, et al (1982) and shown in Figure 26. "The major fatty acids present in algae are all saturated or unsaturated monocarboxylic acids with straight even numbered carbon chains in Ci2~c20 r a n9 e" (Tissot and Welte, 1978, p. 47).

Project Evidence

In the Sunnyside Tar Sands area both the oil shale and coal within the Parachute Creek Member are of algal origin. This is substantiated by both megascopic and microscopic evidence. Megascopic evidence consists of algal structures (stromatolites up to 7cm high and algal laminated sediments up to 2cm thick) that are interbedded within oil shale units R-2, R-3, R-4, R-5 and R-7 (see Figures 16 and 20, and Photo 5).

Microscopic evidence of the algal origin of oil shale and coal exists within thin sections. The R-4 oil shale contains a brown mineral that is water soluble and insoluble in 100% 111-Trichlroethane. Portions of this brown mineral exist in thin section A-71-470 and contain numerous algal-like circular pods up to 0.3-0.4mm diam with a calcite core and external concentric layers less than 0.01mm thick. The brown mineral has a color between light brown (5YR 3/2) to moderate brown (5YR 3/4). The brown mineral was first noticed during the 1988 drilling program and was always spatially associated with cored intervals of oil shale. The brown mineral is suggested to be a precusor of oil shale. Organic ooze derived from blue green algae is the precusor of oil shale (Cane, 1976 and Bradley, 1970). The microscopic evidence for the algal origin of the coal within the Blue Marker is presented in the Blue Marker section of the Parachute Creek Member.

Formation of Oil Shale

The oil shale in Lake Uinta formed from blue green algae in shallow lacustrine environments under some specific Eh-pH conditions that existed during the middle Eocene. The Eh (oxidation-reduction potential) and pH limits of oil shale deposition are Eh minus 1 ± 0.5 and pH 8.75 + .025 (Smith, 1983). Some specific conditions for oil shale deposition as determined by Robinson (1976) include: (1) pH = 8.0-10.0 and Eh of minus 0.3-0.45V at pH 8 and Eh of minus 0.4-0.58V afpH 10; (2) salinity fluctuated from fresh water to sal^2,34

94

water with up to 461 ppm dissolved salts; and (3) average annual air temperature of 66-67°F. The rate of growth of blue green algae depends partly on the water composition. Uncontrolled growth of algae is called an algal bloom. Algal blooms can create local anoxic conditions and may have been an important factor in the formation of oil shale as well as creating the anoxic conditions that caused the occurrence of fish fossils associated with the dinner plate oil shale of the Blue Marker.

Biodegradation of Bitumen

The bitumen from the Sunnsyide Tar Sands is strongly biodegraded and of Tertiary origin as determined by both David Dolcater, APC, Tulsa and Don Anders, USGS, Denver. Gas chromatography and mass spectrometry identify the distribution and abundance of carbon molecules and biomarkers (i.e., biological markers). Biomarkers represent organic com­pounds formed by previously living organisms whose carbon structure is sufficiently stable to be recognized in crude oil (Hunt, 1979).

Biodegradation occurs at the oil-water interface. Bacterial activity requires both water and oxygen. The bacteria live in the aqueous phase where dissolved oxygen is available. The bacteria preferentially consume portions of the oil phase. Biodegradation is intense between 20-60°C, limited from 60-80°C and stops above 100°C. During biodegrada­tion the C15-C35 n-alkanes are preferentially removed. The depletion of Cg-Ci5 hydrocarbons is generally caused by water washing (i.e., influx of meteoric waters). During biodegradation n-alkanes are the most easily degraded and tricyclic terpanes are the most bacterially resistant. Above paragraph summarized from Connan (1984).

After the bitumen has formed, micro-bacteria in the presence of water and oxygen preferentially change the organic matter, bitumen, or crude oil in the following degradation scheme noted by Barker (1986):

n-paraffins (n-alkanes) most susceptible aliphatic side chains branched paraffins cyclic paraffins aromatics sulfur compounds least susceptible

The most noticeable feature of the Sunnyside bitumen sample analyzed by Dolcater (1988, proprietary report) was its lack of normal paraffins; in addition, branched paraffins, cyclohexanes, benzenes, naphthalenes and phenanthrenes were also lacking. 0 1 ^ ^

95

Don Anders stated that the Sunnyside bitumen is so bio-degraded that it is difficult to define the biomarkers. Within Type I kerogen C17 n-alkane is the most abundant carbon molecule before any biodegradation. There is no C^T present in the Sunnyside bitumen. However, some C20' C21 an{* C23 tricyclics and gammacerane C 3Q was recognized and their ratios correspond to signatures of a source in the upper Green River shales. The bitumen from the Sunnyside Tar Sands contains all monoaromatic steranes and no triaromatics. Above paragraph summarized from conversations with Don Anders, 1987 and 1990.

Comparison of the bitumen composition determined by Dolcater and Anders with the degradation scheme noted by Barker (1986) clearly indicates that the Sunnyside bitumen is significantly biodegraded. About a mile east of Bruin Point and at depths greater than 900 feet a one to two square mile area contains abundant CO2 gases within tar sands near the base of saturation (see Geology Map). The presence of these CO2 gases suggests that biodegradation of the bitumen in the tar sands is still an active process.

Secondary recovery of biodegraded heavy oils by steam flooding is difficult due to reduced porosity/permeability and increased anisotropy (Connon and Coustau, 1984). Steam flooding of the Sunnyside Tar Sands by Shell failed to produce much more than 1 BOPD (see Historical Perspective and Project Chronology, 1963-1966).

Thermal Maturity

The bitumen from the Sunnyside Tar Sands is thermally immature and associated coal has vitrinite reflectance values in the range of 0.26% to 0.47%. This data indicates the thermal maturity is late stage diagenesis and before the onset of oil generation.

Van Krevelen diagrams help to illustrate the evolution paths of kerogen during thermal maturity. The diagrams in Figure 28 show the general trends of kerogen evolution and their relationship to vitrinite reflectance as well as other maturation indices. Vitrinite reflectance (Ro) is a measure of thermal maturity.

Five coal samples were submitted to Core Laboratories for vitrinite reflectance to determine the thermal maturity of coal within the Sunnyside Tar Sands area. The list of samples and results are as follows:

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Sample

outcrop: MS-50, Blue Marker outcrop: Bruin Point road, Blue Marker outcrop: MS-56, Blue Marker core: A-65, -489 ft, above limestone

IFC, 12 ft above base of Zone 33 (see strip log)

core: A-72, -881 ft, above ostracodal packstone & 25 ft above top of Zone 33 (see strip log)

*Core Lab note: Outcrop samples contain poorly preserved vitrinite. True vitrinite reflectance may be slightly higher.

These values of vitrinite reflectance are all less than 0.5%; near the upper range of diagenesis and below the onset of oil generation of 0.6%-0.7% for Type I algal kerogens (see Figures 27 & 28). Coal from an outcrop of the Blackhawk Formation in Horse Canyon (some 7 miles southeast of Sunnyside) has a vitrinite reflectance of 0.58 (Nuccio and Johnson, 1988). The near surface coals in the Sunnyside and Bruin Point area have values of vitrinite reflectance that are below the onset of oil and gas generation.

Temperature data exists for only two deep wells (148°F @ depth of 9650 ft and 304°F § depth of 17,261 ft). About 8000 feet east of Mt. Bartles is Mtn. Fuels-Mt. Bartles No. 1 with a T.D. of 9650 ft and a BHT (bottom hole temperature) of 148°F. About 7.5 miles northeast of Mt. Bartles the Chevron Stone Cabin No. 1 (Sec. 29, Twp 12S, Rge 15E) was completed to a T.D. of 17,261 feet with a BHT of 304° in Mississippian limestone.

The Uinta Basin has a low temperature gradient and a high oil generation threshold of 0.7%Ro with depths of 13,000-18,000 needed to generate oil from Type I kerogens of the Green River Formation; vitrinite reflectance values are less than 0.5% at depths less than 7500 feet, between 0.6-0.8% at depths of 12,000-15,000 feet, and 0.8-1.9% at depths greater than 15,000 (Tissot, Deroo and Hood, 1978). The oil shales below the Mahogany oil shale interval have reached oil generation and are responsible for the crude oil in the Uinta Basin (Tissot and Welte, 1978). The bitumen within the Sunnyside Tar Sands is considered to be the most immature bitumen within all the tar sands of the Uinta Basin (Don Anders, personal communication, 1990).

Vitrinite Reflectance%(Rp)

0.29* 0.28* 0.26* 0.34

0.47

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Coleman, J.M. and Gagliano, S.M., 1965, Sedimentary structures: Mississippi River delta plain in Primary Sedimentary, Structures and Their Hydrodynamic Interpretation, ed., G.V. Middleton; Soc. Econ. Paleo. and Mineral. Spec. Publ. 12, p. 133-148.

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Crawford, A.L. and Pruitt, R.C., 1963, Gilsonite and other bituminous resources of central Uintah County, Utah in Oil and Gas Possibilities of Utah, re-evaluated, ed., A.L. Crawford; Utah Geological and Mineralogical Survey Bull. 54, p. 215-229.

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103 0124.3

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104 01244

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107 01247

APPENDIX

01243

Photo 1. Aerial Mosaic of Sunnyside Tar Sands Area Looking Southeast.

The mosaic presents an excellent overall view of the project area. Bruin Point and the Asphalt Mine are the center of attraction. Other noted geographic features include the town of Sunnyside (upper right), Book Cliffs (lower right), Roan Cliffs (left central) and Grassy Trail Reservoir (right central). The bituminous sandstones extend along the Roan Cliffs for about seven miles from Mt. Bartles (extreme left) to beyond the South Overlook. The tar sands are concentrated along the Roan Cliffs and have been separated into three mineable areas — North, Central and South. The Central Area encompasses Bruin Point. The South Area encompasses the South Overlook. The North Area is centered at the unlabelled red dot near the ridge top junction of Dry Canyon Ridge and the Roan Cliffs. The location for the proposed processing plant is at the mouth of B Canyon (lower right).

The Asphalt Mine exists at an elevation of 8900 feet. Bruin Point is at an elevation of 10,131 feet. Grassy Trail Reservoir is at an elevation of 7580 feet. The distance from Grassy Trail Reservoir along Whitmore Canyon to the mouth of Bear Canyon is 2% miles. The distance from the top of the Book Cliffs near Grassy Trail Reservoir to Bruin Point is 3% miles. The distance from Bruin Point to the South Overlook is 2% miles. The distance from Bruin Point to Mt. Bartles is 4% miles.

The aerial view also shows the drainage of Range Creek from its headwaters near Bruin Point to its mouth at the Green River. The vast plateau in the upper left extending from the Green River to beyond Mt. Bartles is the West Tavaputs Plateau.

AERIAL MOSAIC OF SUNNYSIDE TAR SANDS AREA LOOKING SOUTHEAST O

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Photo 2. View of South Area Along Roan Cliffs.

Highlights of photo illustrate: (1) lateral continuity of defined units; (2) relative position of Blue Marker (light blue dots) and Carbonate Interval (dark blue dots); (3) concentra­tion of tar sands (green dots) below Carbonate Interval; and (4) nonbituminous sandstones exist below bituminous sandstones. The various colored dots are aligned along the routes of three measured sections: MS-50 (left); MS-47 (center); MS-6 (right). Each dot defines a particular feature listed below.

right red dot: left red dot:

South Overlook crest of South Knoll with topographic sag at top of Bear Creek out of view to left

MS-50 (783 vertical feet)

orange: near top of traverse It blue: Blue Marker green: Tar Zone 21 dk blue: Carbonate Interval

of Zones 25 & 26 green: Tar Zone 31 green: Tar Zone 33 green: Tar Zones 35 & 36 green: Tar Zone 37 yellow: nonbit Zone 37 orange: bottom MS-50

MS-47 (672 vertical feet)

orange? near top of traverse It blue: Blue Marker green: Tar Zone 21 dk blue: Carbonate Interval

of Zones 25 & 26 green: Tar Zone 31 green: Tar Zone 33 green: Tar Zones 35 & 36 yellow: nonbit Zone 37 orange: bottom MS-47

MS-6 (200 vertical feet)

orange: top of traverse

green: Tar Zone 31 green: Tar Zone 33 green: Tar Zone 35

View encompasses about 1300 vertical feet, and the distance between MS-50 and MS-6 is about 1800 feet. All drainages are tributary to Bear Creek. View looks southeast from Hill 94 31, NW/4, Section 10, T14S, R14E. Blue Marker exists at base of top craggy cliff. (For detail of Blue Marker in MS-50, see Photo 6, 1987 Report). Note local relief of tar sands in Zones 31, 33, & 35/36. In MS-50 the lowest designated sandstone unit is Zone 37. To the left of the creek axis Zone 37 contains 4wt% bitumen. To the right of the creek axis Zone 37 is nonbituminous. Here Zone 37 contains a unique vertical oil/water contact that parallels a major joint and is exposed throughout the 20 foot high cliff. (For details of vertical oil/water contact, see Photo 9, 1987^Report). For detailed data of each measured section see strip log in yearly reports. For det'ailed thickness and bitumen data on each tar zone see Table 1 (this report) .

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Photo 3. View of Measured Section 61 On Roan Cliffs.

Highlights of photo illustrate: (1) frequency and massive concentrations of tar zones below Carbonate Interval (dark blue dot) and especially below the red dot; (2) relative position of Blue Marker (light blue dot) and Carbonate Interval with limited tar sands above dark blue dot; (3) sheet-like nature of major tar zones; and (4) at depth the bituminous sandstones change to non-bituminous sandstones. The various colored dots exist along the traverse. Each dot defines a particular feature listed below:

orange: top of MS-61 at elevation of 9990 feet It blue: Blue Marker at distinct contact between Tgp and Tgg green: Tar Zone 21 (17 ft thick and 12 gpt) dk blue: Carbonate Interval

Zone 25 (22 ft, 11 gpt) Zone 26 (24 ft, 7 gpt)'

green: Tar Zone 31 (25 ft, 14 gpt) green: Tar Zone 33 (34 ft, 11 gpt) green: Tar Zone 35 (9 ft, 14 gpt) red: transitional contact between Tgg and Tgd green: Tar Zone 36 (59 ft, 13 gpt) green: Tar Zone 37 (73 ft, 15 gpt) green: Tar Zone 38 (77 ft, 15 gpt) green: Tar Zone 41 (39 ft, 11 gpt) & base of saturation yellow: Zone 42 (15 ft, nonbit) orange: base of section

View encompasses about 1200 vertical feet and looks easterly from Hill 9431, NW/4, Section 10, T14S, R14E. Additional details of MS-61 are shown on the strip log (see Volume 3). More complete bitumen data on each tar zone is given in Table 1 (see this volume). Bitumen values from outcrop samples are commonly 20% less than values of corresponding subsurface samples.

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Photo 4. Outcrop of Wavy Bedded Tuff.

The Wavy Bedded Tuff is the uppermost marker bed within the Sunnyside Tar Sands area. Its presence is critical to the positive field identification of the Mahogany oil shale. The Wavy Bedded Tuff has some unique textural and color characteristics that make its field identification infallible. In the foreground large blocks of Wavy Bedded Tuff contain characteristic voids near' the yellow dots. These voids represent eroded ash fragments that are commonly one to two inches in size. The actual twenty to twenty-four inch thick out­crop is behind the rock hammer and partly concealed by the thick root of a ponderosa pine. The weather tuff consists of two distinct dominant colors - shades of red and orange. The specific colors are grayish orange (10YR 7/4) to grayish yellowish orange (10YR 7/6) and moderate red (5R 5/4) to pale reddish brown (10R 5/4). These shades of hematite and limonite colors are very distinctive among the normal olive gray shales of the Parachute Creek Member. Fragments and small chips of the tuff are relatively resistant to weathering and form residual debris on the slopes. These red to orange colored chips make the Wavy Bedded Tuff relatively easy to locate even when it does not outcrop as downslope movement of these tuff chips is minimal. In addition, black medium sized grains of fresh biotite exist within the tuff and can make up as much as ten to fifteen percent in the lower six inches of the tuff bed. Extensive areas of the West Tavaputs Plateau contain the Wavy Bedded Tuff (see Geology Map). The Wavy Bedded Tuff exists thirty-five feet above the top of the Mahogany or R-7 oil shale interval. The Wavy Bedded Tuff is an air fall tuff that accumulated 47±1.8 million years ago from a violent volcanic eruption some three hundred and fifty miles to the north in the Absaroka Mountains, near Yellowstone National Park, Wyoming. This photo was taken in the West Tavaputs Plateau near MS-56.

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Photo 5. Core Sample of Algal Stromatolite in R-3 Oil Shale Interval.

This unique NX core sample (2.5 inches in diameter and 11.5 inches high) contains oil shale both above and below the algal stromatolite that is vividly shown in the central portion of the core. The oil shale in this photo has a wetted color of dark yellowish brown (10YR 4/2). The unwetted color is pale yellowish brown (10YR 6/2). Based on color the oil shale has a lean to moderate kerogen content. The well shaped algal head is 4" high x 2.5" wide and encased in oil shale. This stromatolite formed from blue green algae in a shallow lacustrine shoreline environment that was subject to minor fluctuations in lake levels. Stromatolites commonly form in iiearshore intertidal zones. During the 1989 field season almost 2400 feet of core from the Parachute Creek Member was logged. This sample from drill hole RCT-13 at a depth of 607 feet represents a rare example of a stromatolite associated with oil shale and helps to establish the algal kerogen nature (Type I-kerogen) of oil shale within the Parachute Creek Member of the Green River Formation of Eocene age.

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Photo 6. Roadside Outcrop of Blue Marker Near Bruin Point.

This photo illustrates (1) the two major parts of the Blue Marker which are highlighted by blue dots, and (2) different thick­ness of layering above and below the Blue Marker.

dark blue dot: paper shales in lower part of 3.5 foot thick R-2 oil shale interval

light blue dot: location of 0.5 inch coal seam containing algal coal

above dark blue dot: laminated shales of Parachute Creek Member. Layering is usually less than lcm thick.

below light blue dot: bedded shales of Garden Gulch Member. Layering is usually greater than lcm thick.

The Blue Marker separates the overlying Parachute Creek Member from the underlying Garden Gulch Member. The white rocks below the dark blue dot are dominated by micrites that contain 2-3wt% bitumen. These thinly laminated (2mm or less) to laminated (2mm to lcm) shales of the Parachute Creek Member are commonly olive gray (5Y-7/2 to 5Y-5/2) in color but not distinguishable in this photo. Thin algal limestone beds are occasionally present but no ostracods have ever been found in the Parachute Creek Member, or lake facies. The very thin (l-5cm) to thin (5-60cm) bedded shales and limestones of the Garden Gulch Member are commonly greenish gray (5GY-6/1) in color but not distinguishable in this photo. Ostracod and algal limestone beds are commonly present in the Garden Gulch Member, or shore facies.

The Blue Marker is the most important marker in the project area. The R-2 oil shale interval weathers into thin slabs that are frequently located slightly downslope from the outcrop and are called dinner-plates. The weathered surface of these dinner-plate slabs highlights numerous small disarticulated fossil fish fragments. This is the only oil shale interval that contains fossil fish fragments. Petrographic examination of the 0.5 inch coal seam shows algal laminae 0.01-0.02mm high and algal pods commonly 0.2-0.3mm in diameter. See Blue Marker section in text for additional details. The dinner-plate oil shale (dark blue dot) and algal coal seam (light blue dot) are both part of the Blue Marker which is easily recognized in both outcrop and core as well as in surface and downhole gamma ray logs. Photo was taken about 200 feet down the road from the top of the road to Bruin Point. For additional details see MS-59 (1988 Report).

""&-» - • • • J ^ i . - X .

@* ^* %^

^ ^ « ^

^wafes^ZX?

| /fc^T

?Tr

•%^^-4

<-~5$ki2

~ # j

..--i^^S*?^^..

Photo 7. Blue Marker in Core, Drill Hole RCT-11.

Since the Blue Marker is the most distinctive, widespread and useful marker in the project area, recognition of this marker in core is highly desirable. This photo contains sixteen feet of NX core (1.875 inches in diameter) that extends from 394-410 feet. The orange, red and blue dots highlight features of the Blue Marker.

orange dot: lean oil shale red dot: moderate to rich oil shale blue dot: 0.5 inch coal seam of algal origin

The detail of the marked core is given below.

394 -396.6 laminated olive gra*$ (5Y-4/4) shale with 4 inch nonbituminous very fine grained sandstone at yellow dot. Inclined spiral-like marks are scars made by core barrels-

H_ 396.6-401 3.4 foot thick R-2 oil shale interval with lean oil shale (orange dot) ro near 397 feet and moderate to rich oil shale (red dot) between 399-05 400 feet. Algal trash and very lean oil shale exist between 397.4 and r~* 399.1 feet. The oil shale near the red dot corresponds to the dinner-plate

oil shale in outcrop. 401 beginning of 2 inch carbon-rich interval with 0.5 inch algal coal seam at

light blue dot 401 -405 light gray (N-7) shale 405 -409.3 interbedded micrites, shales and algal mat wackstones containing 0-5wt%

bitumen. A stylolite is located at 407.1 feet. 409.3-410 greenish gray (5GY-6/1 to 5G-6/1) shale of the Garden Gulch Member

Comparisons of the outcrop (Photo 6) and core (Photo 7) compliment each other and help to visualize that the Blue Marker can readily be recognized in both outcrop and core. Drill hole RCT-11 is located about 13,000 feet southeast of Bruin Point.

\

- «

,«s

PIC^ST* j

• f - y

Photo 8. Outcrop of Carbonate Interval Measured Section 15.

The Carbonate Interval is commonly 50-75 feet thick. The upper third is limestone rich and consists of Zone 25. The middle third is shale rich. The lower third is limestone rich and consists of Zone 26. This photo shows interbedded limestones and shales of Zone 25. The top of Zone 25 contains an anomalously high gamma ray value that is easily recognized in both surface and subsurface gamma ray logs.

orange dots: massive five foot thick ostracod grainstone/ coquina beds containing an estimated 5wt% bitumen that is not apparent on the weathered surface

green dots: interbedded greenish gray (5GY-6/1 to 5G-6/1) shale

The weathered limestone beds have a characteristic light brown (5YR hue-5/6 chrome) to grayish orange (10YR-7/4) color and are recognizable from a distance, especially in the West Tavaputs Plateau. Ostracod beds are abundant within the Carbonate Interval. The ostracods are commonly 0.1-1.0mm in size and form a rough sandpaper texture at the surface of the outcrop. Ostracods are microscopic benthic crustaceans that moult their bivalve shell about eight times during their lifetime. Thus there are many more shells than actual ostracods. These ostracod beds are not considered a source for the bitumen in tar sands. Within these ostracod coquina beds the bivalves have remained together (i.e., articulated) and have a normal distribu­tion of juvenile to adult sizes. This population distribution in­dicates no winnowing and suggests low energy conditions prevailed in shallow paleoshoreline environments. The Carbonate Interval is an important regional marker that exists in the lower portion of the Garden Gulch Member. Most of the tar sands rin <the' Bruin Point area exist below the Carbonate Interval and within the Douglas Creek Member. Photo was taken some 13,000 feet northeast of Bruin Point in the West Tavaputs Plateau.

012G3

VV-

*-§H

itC^lKS

^N-T-** -w *%*., - '/VV2**-^" *

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nfiw:

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i -y

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*; *l*?{

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^

31 JM'££ftH7£«rtJ ST"

G R E E N R I V E R

*0C( IMIMOS

4 I « N : 5

o Scale „

MII.CS

Figure 1. General Location Map, Sunnyside Tar Sands, Uinta Basin, Utah.

01265

mi '•A J ^ ^ ^ X N - V ^ V . >^0 • • \ ^ r ~ l ' - : y ' / ^ ? T ^ ^ - E 3 S T E » r a e 5 M E N T ^ -,''"^ Y SS3TEHH3BGMENT "

3-5« NECMPS- V - / •

f-£A&.;\\^\—" „^Vi : 1. ••= \ .• /*-^£.y AWs

• \ :

* * • •

\ ^ ^ s j y ^ y ^ s J ^Z}irT.%T3mMS*;-

^c^x / / t^ , / .«?

C ^ V v-'- - - # ^

<=s«^i \'r^i

^ ' ^ ^ > > ^ . f 3 =M

/ /

-W'

^>#*STV^

FIGURE 3

LOCATION OF MT. SARTLES-BRUIN POINT SEGMENTED FLEXURE.

1 ULE

SCALE

01267 SUNNYSIOE TAR SANDS AREA. CARBON COUNTY, UTAH

R fW M TW\ 5 mr

i i

18 U,J f£%b&Jffl i

'wqgjf

DATA: BLM, 1983, SUNNVSIDE EIS, MAP 1-4 APC, SEPT, 1987

• SUNNYSIDE TAR SAND AREA BOUNDARY OF BLM

FIGURE 4 SURFACE OWNERSHIP MAP, SUNNYSIDE TAR SANDS, CARBON COUNTY, UTAH

(V)

t o

AMOCO FEE

COCA MINES FEE

GIBBS HEIRS FEE

PRIVATE

STATE OF UTAH

BLM

DATA: BLM, 1983, SUNNYSIDE EIS, MAP 1-4 APC, SEPT 1987

SUNNYSIDE TAR SAND AREA BOUNDARY OF BLM

FIGURE 5 SURFACE OWNERSHIP MAP, SUNNYSIDE TAR SANDS, CARBON COUNTY, UTAH

ENERGY RESOURCES MAP OF l.TAll M i l l«1i

££$££**

OE01O0* OIUHPRtOHAnO HOCK

««•** . f j M M ^

«Aftti*M*mu*(

& _ _ „ ^ OIUOHflE

OIL 8HAU

I — 1 A

I J: ,

Ann * M * w W Ktttor « * #<•**>**

GENERALIZED SEDIMENT TRANSPORT DIRECTION

FACIES

PALUDAL-LACUSTRINE

Early Paleocene paleogeography, Norlh Horn Formation, northeastern Ulah.

Figure 7. Paleogeography of the Paleocene

GENERALIZED SEDIMENT TRANSPORT DIRECTION

FACIES

[";'.•• 1 ALLUVIAL FAN

(..--..-• | ALLUVIAL PLAIN

[ ) MARGINAL LACUSTRINE

H H OPEN LACUSTRINE

- 39*

Late Paleocene paleojgeography, northeastern Utah.

Bruhn, Picard and Deck (19 83)

(66-58Ma), Northeast Utah.

•GENERALIZED SEDIMENT TRANSPORT DIRECTION 32 KM

FACIES GENERALIZED SEDIMENT TRANSPORT DIRECTION 32 KM

ALLUVIAL FAN

U3 ALLUVIAL PLAIN

MARGINAL LACUSTRINE

OPEN LACUSTRINE | [ALLUVIAL PLAIN

FACIES

J OPEN LACUSTRINE MARGINAL LACUSTRINE

Middle Eocene paleogeography. Upper Parachute Creek, Green River Formation, northeastern Utah.

Late Eocene paleogeography, northeastern Utah.

Bruhn, Picard and Beck (1983)

Figure 8. Paleogeography of the Eocene (58-37Ma), Northeast Utah.

UINTA BASIN

o

s

6 M "*z - £

D O

< 1-u; e u

&

V

c.

Duchesne

Uinta Fm

These formations are so similar that they cannot be separated in well logs.

Evacuation Cr M

Parachute Cr M

Douglas Creek M

ue

Willow Creek M

Wasatch (Colton) Fm

Flagstaff Ls North Horn Fm

Mesaverde Group

Mancos Shale

i rantier-Mowrv horn 'akota-Cedar Mtp

Morrison Fm Uurtis. Pi

± da as •ntrada Ss :armel Fm

Glen Canyon Group Chinle-Garta Fms

Moenlcopi Fm

Weber-Parle City Fms

undifferentiated Miss-renns limestones

Dwvoninn undiff Cambrian undiff,

"granite"

0-3000*

0-5000±

100-600

300-600

JB 0-1000

0-l?00

0-500

0-300

m

3200-5000

m. 500-620 ZEESE 180-220 m 500-650 70-150

100-760 "5[5wT

-830 0(SW) -1500 O-I60 0-200

Ttlndus (TitanotiwTt)

tpihippul

Ityrik) Epihippui

Uinuthmum

oil thai* Mohoqony oil

•nolo bod

block iholo mbr

Phrnocoita

Hrfocatkmwn (EoMpaw)

•hint northooihwd

m^

north onto only

Nn99»t St

AH prO'Trioslic wot ofodod from •ho Uncompolyro block. Thin rV lootoic ttction found on north-ooit tido of wb-wrtoco Uncom. polMjro uplift

SALT It LAKE

CITY

PROVO»

I O M 1 N G Present erosional edge of Uinta Basin Tertiary.,

VERNAL

ISOPACH MAP of DUCHESNE RIVER

and UINTA FORMATIONS

.SALT hLAKE

CITY

PROVOn

W Y O M I N G

Present erosional edge of Uinti Basin TertUry-

ISOPACH MAP

G R E E N R I

F O R M A T T

W Y O M I N G

SALT h LAKE

CITY

PROVOa

Ptetent croiional edge , of Uinta Batin Tertian

ISOPACH M A P of

WASATCH F O R M A T I O N

(Colton- Flagstaff -North Horn Fms)

Hintze, 1972

Figure 9. Stratigraphic Section and Isopach Maps of 01273 Uinta Basin.

Chart Illustrating stratlgraphlc nomenclature and correlation of major Alblan to middle Eocene rock units from the Sanpete Valley of central Utah to the Book Cliffs of eastern Utah (modified from Fouch and others, In press). Vertical line

,— through strata indicates a change In stratlgraphlc nomenclature.

Fouch, et al, 1983

Figure 10. .Northeastern Utah Correlation Chart.

- 40°

39° 39°

en

uo° modified from VanWvst, 1972 •<>•• EXPLANATION

UINTA ft YOUNGER FORMATIONS A-A': LINE OF SECTION

GREEN RIVER FORMATION NAMED TAR SAND AREAS

108°

FIGURE 11

INDEX MAP OF THE UINTA AND PICEANCE CREEK BASINS

t

WEST NORTHWEST

A

. WESTERN UINTA BASIN -

8000 -

AREA OF SUNNYSIDE TAR SANDS PROJECTED 20 M LES DOWNDIP TO SHOW ITS RELATIVE STRATIGRAPHC POSTION

4000

HORZ.

12X VERTICAL EXAGGERATION

FIGUR

WEST UINTA

SOUTHWEST

*\3

GREEN RIVER FORMATION

LOOKING NORTHWEST

PARACHUTE CREEK

_ MEMBER l-ft-SH

NORTHEAST

Bruin Point

GARDEN GULCH

MEMBER

DOUGLAS CREEK

MEMBER

Asphalt Mine

TAR ZONE NUMBER

"I ' Base of Tar Sands Falls Downdip at Average Rate of 30 Feet Per 1000 Feet /

Beds Dip at Average Rate of 120 Feet Per 1000 Feet

IOOOO

-9700

— 9400

-9100

-8800

-8500

300

SCALE

FIGURE 13 IDEALIZED SECTION OF BRUIN POINT SUBDELTA SHOWING TAR ZONES AND DEPOSITIONAL ENVIRONMENTS

SOUTHWEST LOOKING NORTHWEST

NORTHEAST

ARCO Woter Tank

- 9 7 0 0

GREEN RIVER FORMATION

GARDEN GULCH

MEMBER

Shore or Green Shale Fades

Delta or Red Shale Facies

- 9 4 0 0

- 9 1 0 0

DOUGLAS CREEK

MEMBER

— 8 8 0 0

Base of Tar Rises to Northwest at Average Rote of 25 Vertical Feet Per 1000 Horizontal Feet

Base of Tar Falls to Southeast at Average Rate of 35 Vertical Feet Per 1000 Horizontal Feet

8 5 0 0

oo

0 300

SCALE

FIGURE '141' IDEALIZED SECTION OF DRY CANYON SUBDELTA SHOWING TAR ZONES AND DEPOSITIONAL ENVIRONMENTS

APPROXIMATE FOOTAGE

INTERVALS

T T

355

in co

I o o co w CD Z <

T 35

20

17

165

IL

90

20

BRIEF DESCRIPTION

19-23" BIOTITE-RICH TUFF WITH ERODED 1" ASH FRAGMENTS

18-27'OIL SHALE, OUTCROPS AS SEPARATE DISTINCT DOUBLETS

10-40' BROWN CLIFF, ABUNDANT MOLDS OF MUDCRACKS IN LT BROWN SILTSTONES

" r TIT II

50

i" 70

190

140

1 1 1

70

STRATIGRAPHIC MARKERS

WAVY BEDDED TUFF 47.0± 1.8 m.y.

MAHOGANY OIL SHALE

U.S.G.S. OIL SHALE ZONATION

R-7

18-22'OIL SHALE, OUTCROPS AS SEPARATE DISTINCT DOUBLETS

R-5 OIL SHALE R-5

2 -5 'O IL SHALE

1-14" BIOTITE-RICH TUFF, CORE & RARE OUTCROP

LOWER TUFF 51.5+ 2.0 m.y.

R-4

2 - 5 ' OIL SHALE R-3

2 - 7 ' OIL SHALE, OUTCROPS AS 1-2' DINNER PLATE OIL SHALE WITH 0.5" COAL SEAM 1-1.5'BELOW

BLUE MARKER BASE OF PARACHUTE R-2

SCALE: 1" = 50' DATA BASE: DRILL CORE 1988-1989

OUTCROPS 1986-1989

COMPILATION. W. CALKIN DATE: 9-8-89

FIGURE 15 STRATIGRAPHIC MARKERS IN THE PARACHUTE CREEK MEMBER, SUNNYSIDE TAR SANDS, CARBON COUNTY, UTAH

(FROM 1989 FIELD SUMMARY) 01279

2.0

DENSITY g/cc

UN AIR) j i

2.5

GAMMA RAY CORE

200 LITHOLOGY DEPTH I-

LT OLIVE GRAY SH

OIL SHALE LT OLIVE GRAY SH & VOLCANIC TUFF

OIL SHALr 1

WAVY BEDDED TUFF L-M

OIL SHALE M-R

PELLET IFC

NONBIT vfs SANDSTONE WITH MUSC. LAMINAE

OLIVE GRAY SH

MED GRAY TO

MED BLUISH GRAY SH

MED GRAY TO

OLIVE GRAY SH

VL L -M LT OLIVE GRAY SH

DK YELLOWISH GRAY SH

M-R

L

ALGAL STROMATOL1TIC LS

L-VL

RICH

LEAN

RICH it« 5 WTX BIT SS f84WT%BITSS v*s3WT%Brrss

DK YELLOWISH GRAY SH ma NONBIT SS *9 1WTXBIT StLTSTQNE

YELLOWISH GRAY TO GREENISH GRAY SH

T cc ui CD

s ui

5

i

-1

o > z < a o X < 2

<

.

UI

z iU i

X

r

m ui cc o

ui

=) X o < cc < a.

01280

FIGURE 16 WAVY BEDDED TUFF & MAHOGANY ZONE, A -71 , WELL LOG & LITHOLOGY CORRELATIONS

A MIOCO

SW 0?

INDtX MAP UNI Of StCTION

ton tm matt OF HCK H U L I m u AOJITIMM.T OEFMS »T U» 0/T I t U L I uun or us ox. Ltun. «T«H

• a u i « nuuL

*i« FEDERAL TRACT C-a •10 0UMCP CO . COLORADO

SW-NC N U r O C I A M CIOSS StCTION (AFFOOX H M M A l TO *0*ACM STINK!)

Mt t? I T « j MfuCMIZ

SW-NE oil-yield histogram cross section (in gal/ton), Federal Tract C-a.

Ziemba, 1974

01281 Figure 17. Oil Shale Zonation and Important Markers in the

Green River Formation.

THICKNESS, IN FEET

0 r-

200

400 —

600 —

800

1000

1200

MAHOGANY LEDGE

OR ZONE

'B" GROOVE

R-6 ZONE <

1-5 ZONE

R-5 ZONE <

1-4 ZONE

R-4 ZONE

L-3 ZONE

R-3 ZONE <

1400 •—

R-1 ZONE <

ORANGE ZONE (Zone of low electrical

resistivity that includes the orange

marker)

The uppermost and most widespread rich oil-shale zone in the Piceance and Uinta basins. The top of the saline aquifer is in the lower one-third of the Mahogany zone

Represents a major decrease in size of Lake Uinta just prior to the deposition of the Mahogany zone

Nahcolite and halite have been leached from this zone in most of the Piceance basin

Brecciated oil shales in this zone represent intervals where nahcolite and tori halite beds have been leached. Bedded nahcolite and halite are preserved in small areas

One of the richest oil-shale zones in the Piceance basin. Also contains the greatest resou-ce of nahcolite of any zone. The uppermost significant content of dawsonite is found in this zone

Richest oil-shale zone in the center of the Piceance basin. Contains moderate amount of nahcolite and a large amount of dawsonite

Zone containing the greatest amount of dawsonite

Contains three of the most widespread, thick, dissemin­ated nahcolite zones in the basin

Lowest zone containing significant amounts of nahcolite and dawsonite

"8lue Marker", top of the Garden Gulch Member. Base of saline deposition

Rich oil shale in dominantly clay matrix

Clay-shale zone containing no oil shale

Donnell, 19 87

Figure 18. Rich and Lean Oil Shale Zones in the Green River Formation, Piceance Creek Basin, Colorado.

0128?

Detailed measured section of the Oft-shale facias of Parachute Creek Member at Douglas Pass, Colorado.

i ESTIMATED ' OIL-SHALE

; x| GRADE

•LITHOLOGY 70M-i

6 0 -

5 0 -

4 0 -

3 0 -

2 0 -

10-

0 J

EXPLANATION

B O • X

p

1

Oil Shale

Morlstone

Tuff Plant Debris

Insect Fossils

UPPER

OIL-SHALE = R-8

ZONE

« Wavy Toff

A GROOVE

-False MAHOGANY Marker

-Mahogany LEDGE Bed

«—Curly Tuff

= R-7

B GROOVE

C o l e , 1985

Figure 19. Detail of Mahogany Oil Shale Terminology.

0128$

2.0

DENSITY

g/cc

(IN AIR)

J L 2.5

GAMMA RAY

API CORE

283 LITHOLOGY DEPTH

- 175

208

- 225

CC m ffl S S

tu z o N IU - 1 < X CO - 1

o

i o I

CC %•«•»

UJ ttl DC O

tu H

I O <

< QL

01284

FIGURE 20 R-5 OIL SHALE, A - 7 2 , WELL LOG & LITHOLOGY CORRELATIONS

2.0

DENSITY

g/cc

(IN AIR)

J L 2.5

GAMMA RAY

API CORE

200 LITHOLOGY DEPTH

GRAY SHALE

OIL SHALE

LT GRAY SH

1 WT%BITvfgSS

OLIVE GRAY SHALE

1-2 WT% BIT fg SANDSTONE

OLIVE GRAY SHALE

OIL SHALE (R-2)

• • 0 5 - 1 " COAL GRAY SHALE

MICRITE

LT GREENISH GRAY SHALE

363

* UJ UJ

oc Of f UjUJ

•-£ 3 S I l i l O S <

oc < Q.

BLUE MARKER

3 0 C O UJ _ BO

MICRITE

LT GREENISH GRAY SH

UJ O OC <

UJ

01285

FIGURE 21 BLUE MARKER, C D - 1 , WELL LOG & LITHOLOGY CORRELATIONS

—"Tsctic wiucilttgc

Cell cap (CclU'lon.-'*

Cel lulose uxsll

Thimble (Cuticulcir)

Thimble oj TdircnT Cell

Cup (Tdjty &ubs)

Cuj) o^ Parent CVll

u\ \uc r i m )

-Diagram showing the layers siimiiinding two cells from a colony.

Blackburn, 1936 (no scale given)

Temperley, 1936 (no scale given)

—Cells of jlotryorjjr-cua Jiruititii drawn diugraniatically in cros« section, longitudinal section and perspective to illustrate llie development and structure of the colonial framework, (a) Kirstcup; (b)seeon<l cup; (e) third cup;

(il) cell and (c) space between cell and eup.

01286

Figure 22. Cross Section, Longitudinal Section and Perspective of Microscopic Size Botryococcus Brauni i .

APPROXIMATE FOOTAGE MARKER

INTERVALS DESCRIPTION NAME

350

1 "

250

70

I

I 2 FT. BIOTITE TUFF WITH ASH FRAGMENTS

(20 FT. OIL SHALE, OUTCROPS AS DOUBLETS, I GAMMA RAY LOG = 3 PRONGS POSITIVE SLOPE

BROWN CLIFF WITH MUD CRACK MOLDS IN BROWNSILTSTONES

20 FT. OIL SHALE, OUTCROPS AS DOUBLETS, GAMMA RAY LOG = 3 PRONGS NEGATIVE SLOPE

ONE INCH TO 3 FT. BIOTITE TUFF

1-2 FT. DINNER PLATE OIL SHALE & 0.5 INCH COAL SEAM

WAVY BEDDED TUFF

MAHOGANY OIL SHALE

TOP HAS GAMMA RAY KICK OF 600 API UNITS MULTIPLE OSTRACOD-RICH INTERVALS {ZONE 25)

MULTIPLE OSTRACOD-RICH INTERVALS, NO SPECIFIC GAMMA RAY KICK (ZONE 26)

R-5 OIL SHALE

LOWER TUFF

BLUE MARKER

T — CARBONATE

INTERVAL

I

CO 111 CO

111

111 111 cc u 111

D I u < cc < a.

CC ill CO

111

X u _ l D o z 111

a cc <

SCALE: 1" = 100' DATE BASE: OUTCROPS &

DRILL CORE

COMPILATION: W. CALKIN DATE: 9-8-89

01287

FIGURE 23 IMPORTANT STRATIGRAPHIC MARKERS IN THE GREEN RIVER

FORMATION, SUNNYSIDE TAR SANDS, CARBON COUNTY, UTAH

(FROM FALL "89 FIELD REPORT)

GRouPS OR or PS high water level Serra and Sulpice, 1975

ter level

Barre al luvial* Channel send

sea level

Zone J>ordi*re du de l ta De/fa //-o/ir deposit

Cordon l i t t o ra l Barrier bar

••• i

sea

Sable transgressif Transgressive sand sur u n * discordance

afCTROFACJES CUSSfflCATION SK* i£ PERCENTAGE INCREASING

ABRUPT

UPPER CONTACT OF SAND

GRADUAL

CTLMDER SHAPE

SMOOTH " SERRATED

•ELI SHAPE' <••» « r a l I

SMOOTH SERRATED

I < CO Ik O

d S-z o u c ui

i

CONCAVE LMEAR CONVEX

FUNNEL SHAPE SMOOTH

1

Figure 2 4.

Classification of eleetrofacies by shapes of log responses. r\ 1 O Q Q

Serra, 1986

Well Log Shapes and Grain Size Distribution.

the depositional settings in which they can are somewhat variable. The most common idealized gamma-ray originate. Several environments are listed (SP) log curve shapes and at least some of under more than one curve, indicating they C a n t , 1984

Figureo25. Well Log Shapes and Depos i t i ona l S e t t i n g s . i — •

oo CO,

'-..•. , . Types of organic matter in oil Source rocks (after TISSOT & WEITE", 1978; HUNT, 1979; DURAND, 1980)

Type

I

II

III

Chemical characteristics

mostly paraffins, some naphtenes and aromatics. Much volatile matter and/or extractable compounds

predominantly naphtenes and aromatics, relatively high sulphur

rich in oxygenated functional and heteroatomic groups and in polycylic aromatics

Sedimentology, Parent matter

lacustrine clays: algae, zooplankton, bacteria

mostly marine marls and carbonates: plankton, bacteria, a mixture of kerogen I and III

deltaic and paralic clays: terrestrial higher plants, similar to coal parent matter

Oil yield

very high

high

low

S t a c k , e t a l , 1982

KEROGEN TYPES AND HYDROCARBON GENERATION POTENTIAL

KEROGEN TYPE

KEROGEN FORM

ORIGIN RELATIVE OIL POTENTIAL

U

< a o <

- i

< E

Vt u c E u

'

II

III

(IV)

ALG1NITE | ALGAL BODIES

-AMORPHOUS KEROGEN"

-AMORPHOUS KEROGEN-

EXINITE

VITRINITE

INERTINITE

STRUCTURELESS DEBRIS OF ALGAL ORIGIN

STRUCTURELESS PLANKTONIC MATERIAL, PRIMARILY OF

MARINE ORIGIN

SKINS OF SPORES AND POLLEN CUTICLES OF LEAVES AND

HERBACEOUS PLANTS

FIBROUS AND WOODY PLANT FRAGMENTS AND STRUCTURELESS COLLOIDAL

HUMIC MATTER

OXIDIZED. RECYCLED WOODY DEBRIS

VERY GOOD

GOOD

FAIR

POOR

01290

"Figure 26. Kerogen Types: Their Origin, Chemical Character­istics and Oil Potential.

CH4- -400

300

cr

o i— <s

<_> X

~ 0 ^ *21 0

rXP-.. 0-ZOO ^ "1 ' - 174

XXXXXX -167

o?>- " *

Graphite -

— 1.00

- - 0 5 0

- 0 0.5 10 15

— 0 / C (ATOMIC RATIO)

Durand, 1980

20

Van Krevelen diagram.

4.0 O

3.5

3.0

2.5

" 2.0

o < 1.5

1.0

0.5

METHANE

WET GASES

PARAFFIN WAXES AND NAPHTHENES

LIPIDS

PRINCIPAL PRODUCTS OF KEROGEN EVOLUTION

— WATER AND CARBON DIOXIDE

D CRUDE OIL

••• HYDROCARBON GASES

KEROGEN MATURITY

VITRINITE REFLECTANCE (MEAN R0)

LIGNITE COAL RANK

1.0

-SAPROPEL-

?\£» .^BITUMINOUS ..• m » T — : •£ .ANTHRACITE

VGRAPHITE

0.1 0.2 0.3 0.4 0.5 0.6

Dow, 1977

ATOMIC O/C Example of thermal evolution paths of three basic types of kerogen according to

atomic H/C and O/C ratios. Also shown are the composition of some biopolymers, ther­mally evolved hydrocarbons, and three kerogen types.. . * ~ •

01291 Figure 27. Highlights of Van Krevelen Diagram and Products

of Kerogen Evolution.

ISO-

100

^ , //s^?^~'^^~>^ •

\ M Principal V \ • J JOtltOl / _ \ = /loiltormiiionl ^ j l "". \ » / ^W-t-^'-^^^S-'-^;:

I L* r^^^ \ §5>$>$>~" l"lV \JS-'' ' • *

\w&^^ ifm^ i7 lff% ~ ^ 9 « tormitren

m -•

General scheme of kerogen evolution presented on van Krevelen's diagram. The successive evolution stages are indicated and the principal products generated during that time. (Modified after Ttssot. 1973)

^ Atomic O/C

Principol products of kerogen evolution

E 3 COJ.HJO

CD 0>> H I 60s

T i s s o t and W e l t e , 1978

,y yVEANEVOwWNPATHOnrPn

Differences in the kinetics of petroleum formation for types I. II and II I OM:

A. Immature zone. B. Principal zone of oil formation. B, - B, Maxi­mum of oil formation. C. Structural reorganization of the carbon skele­ton.

Durand, 1980

>i 60

IS.

til]

1 lOMCI

}

mm

« mm

5

mm

Dow, 1977

01292

Correlation of the coal rank scale with various maturation indices and the zones of petroleum generation and destruction. The relative importance of petroleum generation zone depends on the composition of the original kerogen.

Figure 28. Scheme of Kerogen Evolution and Petroleum Formation

TAR ZONE DATA

EXPLANATION FOR TABLES 1, 2 AND 3

CE TD 21T-21B GP-17 NC ND *

Thin NP NA Nonbit Bit wk mod X Bit 5. 6/13.4

5 est 114 100M

24+

TE BE NM EOD DF DB B BB OS NS Bay L DMB DC

collar elevation of drill hole total depth of drill hole designated tar zone, top and bottom top picked by geophysics no core not drilled not a designated tar zone used in mine model less than 5 feet thick not present no analyses nonbituminous bituminous weak bitumen content moderate bitumen content weighted average bitumen by analysis in wt%/gals per ton 5wt% bit visual estimate continuous tar sands 114 feet thick multiple tar sands, cumulative thickness noted 24 feet of nonbituminous sandstone drilled; drill hole stopped before full thickness of zone was penetrated top elevation of measured section bottom elevation of measured section not measured environment of deposition delta front distal bar beach beach-bar offshore nearshore interdistributary bay levee distributary mouth bar distributary channel

01293

Table 1 index of eight pages

Bruin Point Subdelta Tar Zone Data

Sunnyside Tar Sands

DRILL CORE DATA

page 1

A-l A-2 A-3 A-A A-5 A-6 A-7 A-8 A-9 A-10 A-11

page 2

A-12 A-13 A-IA A-15 A-16 A-17 A-18 A-l 9 A-20 A-21 A-22

page

A-23 A-2 A A-25 A-26 Signal Shell Shell A-27 A-28 A-2 9 A-30

3

No No. No.

i.l

2 3

page A

A-A 2 A-5 2 A-60 A-63 A-6A A-6 5 A-6 6 A-6 7 A-68 A-6 9 A-70

Page

A-71 A-7 2 Pan Am BP-1 BP-1A RC-1 RCT-1 RCT-2 RCT-3A RCT-A RCT-5

5

No.l

page 6

RCT-6 RCT-7 RCT-8 RCT-9 RCT-10 RCT-11 RCT-12 RCT-13 RCT-1A

MEASURED SECTION DATA

page 7 page 8

MS-1 MS-50 MS-2 MS-51 MS-3 MS-52 MS-A MS-53 MS-6 MS-5A. MS-10 MS-56 MS-18 MS-57 MS-A5 MS-58 MS-A7 MS-59 MS-A8 MS-61 MS-A9

01294

Table 2 index of six pages

DRY CANYON SUBDELTA TAR ZONE DATA

SUNNYSIDE TAR SANDS

Drill Core Data (Table 2, pages 1-3)

(page : A-31 A-32 A-33C A-3A A-35 A-36 A-37 A-38 A-39B Shell A-AO

I)

No. 1

(page 2) A-Al A-A3 A-AA A-A5B A-A6 A-A7 A-A8 A-A 9 A-50 A-51 A-53

(page A-5A A-55 A-56 A-57 A-58 A-59 A-61 A-62 CD-I CD-2 CD-3

Measured Section Data (Table 2, pages A-6)

(page A) MS-5 MS-7 MS-8 MS-9 MS-11 MS-12 MS-13 MS-1A MS-15

(page 5) MS-16 MS-17 MS-19 MS-20 MS-21 MS-22 MS-23 MS-2A MS-25 MS-26

(page 6) MS-27 MS-28 MS-29 MS-30 MS-31 MS-32 MS-33 MS-3A MS-36 MS-55 MS-60

01295

Table 3 index of two pages

WHITMORE CANYON SUBDELTA TAR ZONE DATA

SUNNYSIDE TAR SANDS

Drill Core Data (Table 3, page 1)

SS-NW-1 SS-NW-2 SS-NW-3 SS-NW-A SS-NW-5 SS-NW-6 SS-NW-7 WCT-3A WCT-A GN-13 GN-15

Measured Section Data (Table 3, page 2)

MS-35 MS-37 MS-38 MS-39 MS-AO MS-A1 MS-A2 MS-A3 MS-AA MS-A6

01296

Table 4. Lithology Within Western Segment of Flexure, Sunnyside Tar Sands

Lithology Area of Western Segment

%ss

36.2 43.8 35.4 33.1

%SL

10.5 10.4 12.2 8.2

%SH

44.8 38.1 44.2 48.2

%LS

6.9 5.8 6.6 8.8

%CG

1.6 1.9 1.6 1.6

%V0LC

TR — —

0.1

Total (49 holes) North Area (18 holes) Central Area (20 holes) South Area (11 holes)

BSAT

800 571 1071 680

Average

Member TD Thickness

856 631 1114 756

Cored Footage

41947 11358 22278 8311

44.6 39.7

2.0 23 9 54.1

12.9 30.7 55.2

10.0 13.0

6.7 10.9 14.3

6.0 7.3 12.9

37.5 41.6

87.5 52.7 27.6

72.7 49.2 28.0

6.1 3.9

3.4 11.3 1.7

6.8 11.2 2.0

1.8 1.8

0.4 1.2 2.3

0.8 1.6 1.9

__

__

0. — —

North Area drill holes: Central Area drill holes: South Area drill holes:

NORTH AREA (18 holes) 571 631 Parachute Creek Mbr(Lake) 0 Garden Bulch Mbr(Shore) 538 Douglas Creek Mbr(Delta) 93

CENTRAL AREA (20 holes) 1071 1114 Parachute Creek Mbr(Lake) 103 Garden Gulch Mbr(Shore) 530 Douglas Creek Mbr(Delta) 481

SOUTH AREA (11 holes) 680 756 Parachute Creek Mbr(Lake) 105 Garden Gulch Mbr(Shore) 500 Douglas Creek Mbr(Delta) 151

A-31,32.33C,34,35,36,40,43,44,46,47,48,49 50,51,54,61,62 A-l,4(only to 1200'),8-14,16,17,21,22,24,26,42,52,65,70;RCT-9 A-67,A-69;RCT-2,3A,4,5,6,7,8,10,14

11358

22278

8311

?\5 CO

Table 5. Rock Type Characteristics. Sunnyslde Tar Sands

Bitumen Content Rock Type Common Color Fossils

significant: moderate to high

fine grained to very fine grained sandstone

dark gray to black very limited: garplke fish, log fragments and thin coal seams

significant: moderate to high

fine grained to very fine grained sandstone

dark gray to black very limited: ostra-cods, algal debris

significant: moderate to high

moderate: low to moderate, streaky saturation

fine grained to dark gray to black very fine grained sandstone

slltstone tan to brown to black

limited: ostracods, biota trash, fish scales

rare

moderate: low to high

limestone white to black common: ostracods and algal stromatolites

negligible: on some shale fractures near tar zones

negligible: on some shale fractures near tar zones

negligible: on some shale fractures near tar zones

negligible: on some shale fractures CO

CO

red to maroon to grayish red

mixed colored shale: olive drab, brown, red, purple, green

greenish gray

it. olive gray

very limited: root­lets and plant debris

limited: associated algal stromatolites and ostracods

limited to common: fish scales, turtles bone fragments, associated ostracods and thick algal stromatolites

rare to limited: plant debris, small fish, associated very thin algal stromatolites, no ostracods

Distinguishing Environment Abbreviation Member Characteristics of Deposition Occurrence

channel scour, trough cross bedding, planar bedding, basal IFC's with shale and sllt­stone clasts, 1-2% muscovlte, subtle fining upward within sandstone sequence

distributary channel

DC Tgd&Tgg

trough cross bedding, planar cross bedding, current ripple lamina­tions with muscovlte laminae, basal and internal IFC's with limestone clasts, dis­torted bedding, 2-3% muscovlte, subtle fining upward within sandstone sequence

distributary mouth bar (proximal)

DMB Tgg&Tgd

trough cross bedding, beach or planar bedding beach bar

B or BB all

micro-trough cross bedding, moderate bio-turbation, 1-2% muscovlte

levee Tgg&Tgd

micrites to biomicrltes nearshore and bay

NS & ID Tgg&Tgd

red shales, limited bioturbatlon

marsh Tgd

mixed colored laminated lnterdis-shales, moderate bio- tributary turbation bay

ID Tgg

thick green shales, limited to moderate bioturbatlon, associa­ted thin limestones with fossils

nearshore NS Tgg

it. olive gray shales, laminated to thinly bedded, oil shale with paper shale texture, deformed bioturbatlon

offshore OS Tgp

Table 6. Mean Composition of Bituminous Sandstones, Sunnyside Tar Sands

Constituents

A A

1-1 o

1-1 o s CD e « u fa

s

1-1 o c

V V

Monocrystalline Quartz Polycrystalline Quartz Orthoclase Microcline Plagioclase Rock Fragments (subtotal)

Mica Accessory Minerals Allochems (ostracods, oolites and carbonate fragments) (subtotal)

A

a ' 0) *o

E e 01 «

1 V

A

1 •H

>

Calcite Dolomite

* Hematite »j Pyrite ^ Clay Matrix (subtotal)

Porosity Bitumen (subtotal)

Banks (1981) X

31.2 2.9 9.7 3.1 15.9 7.8

(70.6)

0.5 0.A

0.3 ( 1.2)

0.8 2.5 3.8

0.A 0.5

( 8.0)

4.3 15.9 (20.2)

Remy (1984) X

29.3 3.7

11.4

16.9 8.5

(69.8)

0.5 0.4

3.1 ( 4.0)

1.2 2.0 1.0 0.4 —

1.2 ( 5.8)

17.2 3.2

(20.4)

Total 100.0 100.0

data: Banks (1981) 39 surface samples, bitumen not extracted Remy(1984) 20 core samples, bitumen extracted

compilation: W. Calkin, 1988

Table 7. Drill Core . and Well Log Correlations, Sunnyside Tar Sands

Lithology

Sandstone(bit) Sandstone(nonbit) Siltstone Limestone

Oil shale Shale: Gray

Green Mixed Red

Tuff

Unconformity

Gamma (API)

100±30 80±20 130+30 65±25

(peaks to 600) 60±20

70±25

140±20 170±20 100±20 150±50

single peaks of

Typical

Density (gms/cc)

2.25±.05 2.25+.05 2.35+.05 2.45±.05

2.1 ±.10

2.45±.05

2.40±.05 2.40±.05 2.45±.05 UNK as all readings in air

Responses

Focused Electric

(ohm/meters)

1000-20,000 100-1000 100-2000 100-10,000

20-100

200±100 (expanded and serrated pattern) 90±20 60±20 50±10 UNK

Sonic (microsec/ft)

85±5 85±5 80±5 80±15

100

85±15

75±5 75±5 70±5 UNK

200-600 common

CO C5

DRILL

D r i l l Core

A - l

£ £ g; ^

se A-2

IN <T I B r~

UJ O

A-3

O J> O fN

u a u t-

A-4

S CT.

cr. " h j D U H

A-5

o o

LlJ 2 l_) ^

A-6

— a* g; ~ L±J a

A-7 CD r-J

CT- —

UJ O

A-S

o -£ -LLJ Q

u 1-

A-9

— CO

U O U t -

A-IO

£ <t CT< ^

LLJ O U H

A - l l

o < O f i

CJ Q

CORF. DMA

Zone-* D.i t a l

E l e v . i t t on Depth Th i ckness X B i t EOD

El ev.i t i o n Depth Th i ckness X B i t EOD

E l e v a t i o n Depch Th i ckness X B i t EOD

E l e v a t i o n Depth Th i ckness X B i t EOD

E l e v a t i o n Depth Th i r kness X B i t EOD

E l e v a t i o n Depth Th ickness X B i t EOD

E l e v a t i o n Depth Th ickness X B i t EOD

EJ e v a t i o n Depth Th ickness X B i t EOD

E l e v a t i o n Depth Th ickness X B i t EOD

Elev. i t inn Depth Thickness X B i t EOD

E l e v a t i o n Depth Th ickness X B i t EOD

10T 10B

Eroded

Eroded

Eroded

Eroded

Eroded

Eroded

Eroded

111 11B

Eroded

T h i n

Eroded

T h i n

Eroded

T h i n

T h i n

Th in

Th in

Eroded

Th in

2 IT 2J_B

9916-9899 69-86

17 8 . 4 / 1 9 . 9

B

9471-9454 155-172

17 6 . 1 / 1 4 . 4

BB

9966-9955 85-96

11 7 . 0 / 1 6 . 6

BB

9698-9677 276-297

21 6 . 2 / 1 4 . 8

BB

9348-9301 55-102

47 5 . 5 / 1 3 . 1

DMB

9654-9605 263-312

49 5 . B / I 3 . 6

DUB

T h i n

T h i n

9542-9527 269-284

15 7 . 4 / 1 7 . 4

nr.

94 71-94 54 88-105 Gi"-17

4 . 8 / ] 1 . 4 BB

T h i n

22T 22B

9 8 7 0 - 9 8 5 ! 115-134

19 6 . 0 / 1 4 . 1

BB

9444-9434 182-192

10 7 . 1 / 1 6 . 7

BB

9917 9907 134-144

10 8 . 8 / 2 0 . 9

BB

9618-9602 356-372

16 8 . 6 / 1 5 . 5

BB

T h i n

Combined w i t h

Zone 21

9784-9733 204-255

51 5 . 0 / 1 2 . 1

DUB

T h i n

T h i n

0187-9 !71 172-186

14 4 . 7 / 1 3 . 8

BB

9838-9802 212-248

16 1 . 6 / 1 4 . 4

DUB

231 23B

9796-9773 189-212

23 7 . 2 / 1 7 . 0

DMB

933B-9331 288-295

7 8 . 1 / 1 4 . 4

BB

9839-9830 212-221

9 4 . 2 / 9 . 8

BB

Th in

9200-9185 203-218

15 3 . 3 / 8 . 0

B

9581-9540 336-377

41 6 . 6 / 1 5 . 3

DUB

Th in

NS

Th in

NS

Th in

NS

9339-9120 220-239

19 3 . 8 / 9 . 0

BB

9760-9740 290-310

20 7 . 2 / 1 7 . 0

DUB

25T 25B

9700-9678 285-307

22 5 . 2 / 1 2 . 8

NS

9285-9264 341-362

21 4 . 3 / 1 0 . 1

NS

9744-9732 307-319

12 5 . 9 / 1 3 . 9

NS

9521-9501 453-473

20 3 . 7 / 8 . 8

NS

9169-9144 234-259

25 3 . 3 / 7 . 7

NS

9472-9459 445-458

13 4 . 3 / 1 0 . 1

NS

9599-9587 389-401

12 3 . 6 / 8 . 4

NS

9508-9496 400-412

12 3 . 5 / 8 3

NS

9370-9345 441-466

25 3 . 5 / 8 . 3

NS

9116-9304 243-255

12 1 .3 /3 .2

NS

9678-9655 372-395

23 4 . 2 / 9 . 8

NS

26T 26B

9665-9651 320-334

14 3 . 7 / 8 . 6

NS

9252-9248 374-378

4 3 . 4 / 8 . 1

NS

9721-9714 330-337

7 4 . 0 / 9 . 5

NS

9488-9472 486-502

16 1 . 7 / 4 . 0

NS

9126-9115 277-288

11 1 . 6 / 3 . 9

NS

944»-9430 469-487

18 3 . 8 / 9 . 1

NS

9566-9558 422-430

8 2 . 5 / 5 . 8

NS

14P5-9469 423-439

16 1 . 1 / 2 . 6

NS

9334-9315 477-496

19 1 . 4 / 3 . 4

NS

9292-9276 267-283

16 0 . 9 / 2 . 1

NS

9642-9627 408-423

15 1 . 8 / 4 . 4

NS

Bru i n P o i n t Tar 7.oni

Sunnys ide

31T 31B

9519-9493 466-492

26 7 . 5 / 1 7 . 6

DMB

9190-9159 436-467

31 7 . 1 / 1 6 . 7

DUB

9641-9594 410-457

47 6 . 8 / 1 6 . 0

DMB

9428-9399 546-575

29 8 . 9 / 2 1 . 0

DMB

9072-9026 331-377

46 1 . 4 / 3 . 4

L

9404-9364 513-553

40 7 . 0 / 1 6 . 3

DMB

9537-9446 451-542

7 7M 5 . 8 / 1 3 . 5

DMB

9445-9397 463 -511

48 6 . 5 / 1 5 . 4

DMB

9266-9263 545-548

3 4 . 0 / 9 . 0

NS

9249-9216 310-343

33 3 . 1 / 8 . 7

DMB

9580-9564 470-486

16 6 . 8 / 1 4 . 2

DMB

32T 3:

NP

NP

NP

NP

NP

NP

. NP

NP

NP

NP

NP

S u h d e l t n e Da t a l a r S a n d s

T a b l e 1 p a g e 1 of

2B 33T 33B 35T 35B 36T 36B 37T 37B 38T 38B 41T 41B 42T 42B 43T 43B 45T 4 5 B BSAT

9 4 5 0 - 9 4 2 5 5 3 5 - 5 6 0

25 7.2/16.9 DMB

9376-9320 609-665

56 7.8/18.4

DC

9287-9265 698-720

22 8.7/20.6

DC

9245-9182 740-803

63 7.7/18.3

DC

9163-9113 822-872

50 8.3/19.7

DC

9013-8980 971-1005

33 8.0/18.9

DC

8954-8921 1031-1064

33 7.7/18.1

DC

8855-8803 1130.1182

32 6.2/14.7

DC

8788 1197

9091-9078 9019-8991 535-548 607-635

13 28 8.5/20.8 5.9/14.0

BB DC

8954-8895 672-731

59 3.1/7.4

DC

8880-8747 746-879

133M 3 . 4 / 8 . 1

DC

8723-8697 903-929

26 2 . 8 / 6 . 7

DC

ND ND ND 8697 929

9 5 2 6 - 9 5 1 6 9 5 0 8 - 9 4 7 1 5 2 3 - 5 3 5 5 4 3 - 5 8 0

12 37 9.8/23.4 8.0/19.1

BB DMB

9440-9381 611-670

59 8.6/20.3 DMB

9443-9250 708-801

72M

7.3/17.2 BBSDC

9207-9129 844-922

38N 5.3/12.5 BSDC

9033-8966 1018-1085

67 6.9/16.4

DC

8961-8934 1090-1117

27 6.4/15.2

DC

8912-8891 1139-1160

21 4 . 1 / 9 . 8

DC

8 8 1 3 - 8 7 9 0 1 2 3 8 - 1 2 6 0

23 0 0 / 0 . 0

DC

8 8 9 1 1160

9 3 3 6 - 9 3 1 3 9 2 6 1 - 9 2 3 6 6 3 8 - 6 6 1 7 1 3 - 7 3 8

23 25 7.2/17.0 7.1/16.8

DC DC

9210-9147 764-827

63 8.1/19.2 DMB

9110-9016 864-958

94

8.7/20.5 DMB

8985-8933 989-1041

52 5.9/13.9

DC

8829-8816 1145-1158

13 6 . 9 / 1 6 . 4

DC

8 7 7 1 - 8 7 1 1 1 2 0 3 - 1 2 6 3

60 0 . 0 / 0 . 0

DC

8 6 8 5 - 8 6 3 1 1 2 8 9 - 1 3 4 3

54 0 . 0 / 0 . 0

DC

8626 -8586 1348-1388

40 0.0/0.0

DC

8780 1194

8955-8938 448-465

17 4.9/11.6

9281-9272 635-644

9 7.5/17.5

8898-8886 505-517

12 4.1/9.7

9197-9085 720-832

112 8.1/18.9

DMB

8831-8778 572-625

53 3.5/8.3

DC

9081-9060 836-857

21 6.9/16.0 DMB

87 52-8660 651-743

92 3.7/8.8

DC

9 0 5 2 - 8 9 5 5 8 6 5 - 9 6 2

97 8.3/19.4 DMB

8575-8562 828-840

12

Nonbit

DC

8898-8863 1019-1054

35 8.4/19.7

DC

ND

8798-8769 1119-1148

29 9 . 0 / 2 0 . 9

DC

ND

8 7 4 4 - 8 7 2 5 1 1 7 3 - 1 1 9 2

19 N o n b i t

DC

N? ND 8 6 6 0 743

ND 8 7 6 9 1 1 4 8

9 3 8 1 - 9 3 6 4 6 0 7 - 6 2 4

17 8

8.1/18.9 9.2/21

9324-9316 664-672

9291-9224

697-764

67 7.6/17.8

DC

9204-9101 784-881 103M

6.7/15.6 DC

9078-8952 910-1025

99M 13.0/20.8 DCSBB

8881-8799 1107-1189

82 7.1/16.5

DC

8781-8765 1207-1232

25 Nonbit

DC

8799 1189

9344-9303 9280-9263 564-605 628-645

41 17

7.5/17.7 6.9/16.3 DC BB

9197-9132 711-776

65 7.4/17.5

DC

9101-8992 807-916

109 6 . 9 / 1 6 . 2

DC

8 9 8 4 - 8 8 6 1 8 8 3 4 - 8 7 9 5 9 2 4 - 1 0 4 7 1 0 7 4 - 1 1 1 3

100M 18M 5 . 7 / 1 3 . 7 0 . 1 / 0 . 2

2DC ' s B B ' s

ND ND 8 8 0 5 1 1 0 3

9206-9201 605-610

5 5.8/13.6

9129-9118 682-693

11 8.2/19.3

9037-8929 774-822

48 8.5/20.1

DC

8941-8843 870-968

98 6.7/15.9

DC

8825-8745 986-1066

80 4.1/9.6

DC

8720-8697 1091-1114

23 2.6/6.2

DC

8619-8539 1192-1272

80 4.0/9.3 DMB

8539 1272

9149-9111 9064-9034 410-448 495-525

38 30 6.4/15.0 6.8/16.1 DMB DC

9450-9438 600-612

12 3.4/8.1

NS

9412-9395 638-655

17 8.9/21.0

8994-8952 565-607

42 7.4/17.5

DC

9365-9293 685-757

72 5.2/12.4

DC

8905-8814 654-745

91 3.9/9.2

DC

9287-9220 763-830

67 6.4/15.1

DC

8769-8755 8750-8683 790-804 809-876

14 67

4.7/11.1 3.9/9.3 DC DC

9188-9084 862-956

79H 7.0/16.6

DC

9065-9031 985-1019

34 2.4/5.6

ND

8916-8886 1134-1164

30 7 . 5 / 1 7 . 6

DC

8 8 5 0 - 8 8 2 1 1 2 0 0 - 1 2 2 9

29 6 . 7 / 1 5 . 9

DC

01301

8 7 7 0 - 8 7 5 9 8 7 5 5 1 2 8 0 - 1 2 9 1 1 2 9 5

I I 3 . 7 / 8 . 7

ULX CORE JJAJA

• 111 ij ] e

- 1 2

i so • %o

IP - 1 1

3 O

J Q

. - l ' l

3 r~ - O

5P \ - 1 5

-> O J sO

iJ Q _) t -

^ - 1 6

3 O

3 ^ ^ n A - 1 7

_i lA

r- O 3- —

SP­A - I B

•c r j r - CO

O

UJ a u t-A- 10 vr ,o CO ^ o ••

A-20 -1 o

£ ^ u; tn

ft-21 n o c o -a> —

UJ n u i -

A-22 00 c* 00 C*

» O Q

Z o n e *

Da_ta*__ _

E l e v a t I o n D e p t h T h i c k n e s s

X B i t F.OD

K l c v . i t i o n D e p t h I l i i c k n e s s

X B i t FDD

E l e v a t i o n

D e p t h T h i c k n e s s

X B i t F.OD

E l e v a t i o n

D e p t h T h i c k n e s s

X B i t F.OD

E l e v n t i n n

D e p t h T h i c k n e s s X B i t FOD

E l e v a t i o n D e p t h T h i c k n e s s X B i t FOD

E l e v a t i o n D e p t h I l i i c k n e s s X B i t F.OD

E l e v a t i o n

nop L ii T h i c k n e s s X B i t F.OD

F l c v . i L I o n

D e p t h

T h i c k n e s s X Hi t F.OD

E l e v a t i o n

Depth T h i c k n e s s

X B i t F.OI)

E l e v a t i o n

Deptli T h i c k n e s s X Bi t FOD

Bruin Point Subdelta Trr Zone Data

Sunn-'side Tar Sands Table )

pane 2 of 8

1QT 1QB 1 IT 11B 21J_ 21B _2_2_T__22B 23T 23B 25T 25B 261 261 31T 31B 32T 32B 33T 33B 35T 35B 36T 36B 99T 99B 37T 37B 38T 38B 41T 418 42T 42B 43T 43B 45T 45B BSAT

Eroded 9964-9945 9908-9848 9841-9833 138-157

19 7.1/16.9

194-204 10

5.7/13.3 5.5/12.9 BB

9181-9160 24-45

21 3.7/13.4

BB

nr

9715-9698 387-404

17 2 . 5 / 5 . 9

NS

9138-9130 67 -75

9098-107-

9637-9594 465-508

43 6 . 1 / 1 4 . 4

DMB

-9065 -140

9749-9726 353-404

23 3.2/7.7

NS

9160-9148 45-57 12 8 33

2.0/6.9 1.4/3.4 7.8/18.5 NS NS DC

9869-9858 74-85 11

8.3/19.7 DR

9935-9921 86-100

lilt

9641-9612 140-169

29 5.8/1 ).8

HNK

9940-9929 96-107

11 7.8/18.4

BB

9811-9799 83-95 12

6.9/16.2 BB

9709-9691 lli-173

18

6.4/15.0 BB

9526-9506 296-316

20 6 . R / 1 6 . I

DMH

9 6 0 4 - 9 3 7 4 8 4 - 1 1 4

30 6 . 0 / 1 4 . 1

B

9 8 2 2 - 9 8 1 2 1 2 1 - 1 3 1

10 7 . 0 / 1 6 . 6

BB

9 8 8 7 - 9 8 7 5 1 3 4 - 1 4 6

12 5.9/14.0

NS

ND

9467-9444 293-316

23 3.5/8.2

NS

9431-9414 329-346

17 1.5/3.4

NS

9376-9354 384-406

22 6.1/14.6

DC

9568-9529 9479-9473 9428-9303 534-573 623-629 674-799

39 6 125 5.7/13.5 2.8/6.6 6.0/14.1 DMB NS DMB

9002-8987 8890-8850 8890-8765 203-218 315-355 362-415

15 40 53 3.9/9.3 5.3/12.6 5.4/12.6

BB DC DC

9311-9297 9220-9170 9112-9094

449-463 540-590 648-666 14 50 18

4.8/11.3 7.1/16.8 6.0/14.1 L DMB DC

9272-9220 9113-9100 9022-8941 8922-8894 8859-8834 830-882 989-1002 1080-1161 1180-1206 1243-1268

Shallow Pilot Mine Hole

9728-9704 293-317

1(11

9696-9677 325-344

19 3.8/8.9

NS

9605-9545 416-476

60 6 . 7 / 1 5 . 7

0M11

31 & 32 a r e

c o m b i n e d

9 5 5 9 - 9 5 4 5 22-3f,

9 4 6 2 - 9 4 3 9 9 4 2 8 - 9 4 0 9 9 3 6 1 - 9 3 4 0 3 1 9 - 3 4 2

23 NA

353-372 19 NA

9 8 6 3 - 9 8 5 4 1 7 3 - 1 8 2

9 4 . 5 / 1 0 . 8

R

9771-9753 123-141

9634-9621 210-241

13 6 . 5 / 1 5 . 4

BB

RB

9 7 7 8 - 9 7 6 8 2 5 6 - 2 6 6

10 5 . 3 / 1 2 . 5

4 2 0 - 4 4 1 21

6 . 4 / 1 0 . 2 DMB

S h a l l o w P i l o t Mine H o l e

S h a l l o w P i l o t Mine H o l e

S h a l l o w P i l o t Mine H o l e

T h i n

9 3 1 4 - 9 2 9 4 1 7 4 - 1 9 4

20 4 . 1 / 1 0 . 3

DM11

NS

9 2 8 9 - 9 2 5 1 1 9 9 - 2 3 7

38 6.3/15.1

DMB

9347-9323 475-499

24 3 . 7 / 8 . 7

NS

9300-9293 522-541

19 NA NS

9249-9232 573-590

17 7 . 0 / 1 6 . 5

DMB

9200-9176 9152-9144 9105-9086 288-312 336-344 383-401

24 8 19 2.6/6.2 NA 6.8/16.1

NS NS DMR

52 8.6/20.4 DMB

13 4.6/11.0 7.8/16.6

DC

26 7.1/16.7

DC

25 0.4/1.0

DC

8740-8692 8682-8648 8610-8598 465-513 523-557 595-607

48 34 12 2.9/7.1 3.2/7.7 0.3/0.8

DC DC DC

9 0 7 2 - 8 9 7 7 6 8 8 - 7 8 3

95 7 . 6 / 1 7 . 8

DC

8 9 6 7 - 8 8 3 8 7 9 3 - 9 2 2

129 4 . 6 / 1 1 . 0

DC

8 7 3 8 - 8 7 2 7 1 0 2 2 - 1 0 3 3

11 1 . 5 / 3 . 5

BB

8 6 9 8 - 8 6 8 3 1 0 6 2 - 1 0 7 7

15 0 . 2 / 0 . 6

DC

9545-9481 476-540

60M 5 . 8 / 1 4 . 0

DMB

T h i n

JP 9 3 9 2 - 0 3 7 2 6 2 9 - 6 4 9

20 5 . 0 / 1 1 . 9

DC

9197-9176 9113-9084 584-605 668-697

21 29 6.7/15.8 8.6/20.2

DMB DMB

9336-9281 685-740

55 6.7/15.8

DMB

NP

9 2 5 5 - 9 2 0 3 7 6 6 - 8 1 8

52 8 . 0 / 1 8 . 9

DMB

9 0 7 1 - 8 9 2 6 7 1 0 - 8 5 5

145 6 . 9 / 1 6 . 3

DC

9 1 7 3 - 9 1 4 0 8 4 8 - 8 8 1

33 9 . 3 / 2 2 . 1

DC

8 9 0 7 - 8 8 2 5 8 7 4 - 9 5 6

82 4 . 1 / 9 . 7

DC

9 0 3 4 - 9 0 0 4 9 8 7 - 1 0 1 7

30 7 . 5 / 1 7 . 7

DC

ND

8994-8885 8866-8826 1027-1136 1155-1195

109 40 5.9/14 0 6.3/14.9 DMB DC

ND ND

01302

9202-9121 620-701

81 6 . 7 / 1 5 . 9

DMB NS

9 0 1 7 - 8 9 5 3 8 0 5 - 8 6 9

6 . 3 / 1 6 . 9 DMB

8977-8970 8919-8893 8853-8819 511-518 569-595 635-669

7 26 34 4.9/11.5 5.5/12.9 4.1/9.7

BB DC DMB

8 9 1 8 - 8 8 0 9 9 0 4 - 1 0 1 3

109 4 . 8 / 1 1 . 3

DC

8 7 7 2 - 8 7 2 7 7 1 6 - 7 6 1

4 5 2 . 8 / 6 . 6

DC

8 7 9 2 - 8 7 6 2 1 0 3 0 - 1 0 6 0

30 3 . 9 / 9 . 4

DC

8 7 0 4 - 8 6 6 7 7 8 4 - 8 2 1

37 3 . 4 / 8 . 0

DC

8 7 5 2 - 8 7 0 7 1 0 7 0 - 1 1 1 5

4 5 4 . 7 / 1 1 . 2

DC

8 6 3 6 - 8 5 9 4 8 5 2 - 8 9 4

42 2 . 7 / 6 . 3

DC

8639-8632 1183-1190

7 0.4/1.0

887 7 1225

8648 557

8727 1033

8821 1200

8825 956

ND 8707 1115

ND 8594 894

DRILL CORE DATA

Drill

A-2 3

o — o o

U V-

A-24

O O

A-25

*C CO

Zo nc-»-

Da ta+

Elevation Depth Thickness X Bit EOD

Elevation Depth

Thickness

X Bit

EDI)

Bruin Toint Subdelta Tar Zone Data

Sunnyside Tar Sands

Eroded

Eroded

9920-9908 114-126

12 6.1/14.4

BB

9719-9695 184-208

24 5.3/12.4

nun

ND

965J-9643

250-260

10 4 6/10.9

1111

9544-9524

369-379

20 3.1/7.2

NS

9514-9496 3B9-407

18 NA NS

9465-9462

438-461 23

5.6/13.2

DHB

9393-9388 510-515

5 6.2/14.B

B

9317-9307 5B6-596

10 3.0/7.1

BB

9268-9245 635-65B

23 4.7/11.0

DC

9220-9172 683-731

48 7.3/17.2 DHB

Computerized Model

T a b l e 1 p a g e 3 of

37T 37B 38T 38B AIT MB 42T 42B 43T 43B 45T 45B BSAT

9129-9030 8975-8920 8817-8808 774-873 928-983 1086-1095

81M 55 9 6 . 9 / 1 6 . 3 8 . 2 / 1 9 . 3 1 .0 /4 .4

DC DC BB

8808 1095

A-26 E l e v a t i o n Depth

£ 2 T h i c k n e s s S " X n i t „, o E0»

S i g n a l E l e v a t i o n No. 1 Depth o o i h l c k n e s s 2 'T X R i t 2 ~* EOD W Q O Y*

S h e l l E l e v a t i o n No. 2 Depth 'Z £ Th ickness S - x nit w Q EOD

S h e l l E l e v a t i o n No. 3 Depth i i ro T h i c k n e s s £ - X Bi t

EOD

Eroded 9363-9347 122-138

16 6 . 6 / I 5. ft

l>MR

E r o d e d NC

A-27

9606-9559 128-175

29M R i t&Nonb i t

DB

File va t ion Depth

£ ^ Thirkness S "" X II11 n o EOD

A-28 Flevat(on Depth

co <r 1 l i fckness <£ "" X n i t UJ Q EOD

A-29 E l e v a t i o n Depth

r-i t^ ') h ickness § X n i t Z Q TOD

A-10 E l e v a t i o n -< o Depth o -• Tli Lckness 2 x m i !3 H I-:OI>

DF

Th i l l

9185-9157 9139-9115 9088-9067 9035-9009 8964-B955 B935-BB86 BB37-B780 8747-8684 8675-8670

738-801 810-815 63 5

3.0/7.2 0.1/0.4 DC DC

300-328 28

3.4/7.9 NS

346-370 24

WK/NA NS

397-418 21

5.6/15.6 DHB

450-476 26

7.5/18.0 DHB

521-530 9

7.7/18.1 BB

550-599 648-705 49H 57

5.1/12.1 3.1/7.3 DMB DC

9780-9766 9718-9714 400-414 464-466

14 4 4. 1/9.9

NS 7.2/17.1

NS

9862-9849 9798-9774 9740-9709 9647-9624 9613-9595 151-164

13 5.8/13.8

BB

9248-9219 486-515

29 7.1/17.0 DHB

9822-9809 155-168

13 8.3/20.0

BB

9877-9867 I 12-122

10 9.1/21.8

BB

9961-9946 75-90 13

8.4/21.0 BB

9907-9897 9876-9864 104-114 155-147

4/20.3 7.8/18.1

215-239 24

6.9/16.4 DHB

Thin

5.7/14. DMB

366-389 23

4.8/11.3

400-418 18

1 .2/8.2 NS

NP 9630-9612 9579-9539 9501-9462 550-568 601-641 679-718

18 40 39 4.7/11.1 4.8/11.3 3.6/8.5 DMB DMB DMB

9465-9441 9378-9345 9292-92679257-9157 54B-572 635-668 721-746 756-B56

24 33 25 100 6.1/14.5 4.9/11.6 6.8/16.1 8.0/18.9 DHB DMB DMB DMB

9086-9062 9039-9029 8993-89B4 8935-B921 BB94-8B84 BB18-B792 8741-8707

NS

Shallow

648-672 24

4.0/10.3 NS

Pilot Mine Hole

690-705 15 NA

741-750 9

3.0/7. BB

799-813 14

6.9/18.3

840-850 10

4.9/12.B

916-942 26

5.7/15.B DMB

993-1027 34

3.1/7.9 DC

Slinl low Pilot Nine Hole

Sh.illow Pilot Mine Hole

Pilot Mine Hole

9443-9297 737-BB3 146M

6.0/14.3 DHB

9151-9066 862-947

85 6.3/14.8 DHB

8655-8600 1079-1134

55 0.1/0.2

DC

92B9-9238 891-942

51M 7.3/17.2

DC

9046-9037 967-976

9 6.7/16.1

B

ND

9161-9130 1019-1050

31 5.8/17.2

DC

8928-8843 1085-1170

85 4.9/11.6

DC

ND

9108-8958 1072-1241

170M 5.5/13.1

DC

9923-8775 1190-1238

4B 6.3/14.9

DC

ND

8887-BB77 1293-1303

10 2.2/5.2

B750-8726 1263-1287

24 5.5/14.4

DC

ND

B843-8730 1337-1450

113 0.0/0.0

DC

8695-8633 1318-1380

62 0.0/0.0

DC

ND

8684 801

8877 1303

8726 1287

8707 1027

01303

11,1.

i l l

1*2

1

r>2

o

3

COKE DM'A

Zone-*" H.-iLn +

E levn t i on Mop t i l Th ickness X B i t EOD

E l e v a t i o n

Th ickness

run

10T

Er od

10B

cd

1 IT l i n

9819-9810 141-150

9 6 . 9 / 1 6 . 5

DB

Bruin Point SubJeltn Tar Zone Data

Sunnys ldo Tar Sands

21B 22T 22B 23T 23B 2 5 T 2 5 B 26T 26B 31T 31D 32T 32B 33T 33B 35T 35B 36T 36B 99T 99B

9749-9733 211-227

16 7 . 3 / 1 7 . 4

BB

Tli i n

9671-9656 289-304

15 3 . 7 / 8 . 8

BB

9764-9746 86-104

18 3 . 9 / 9 . 4

1.

9576-9553 384-407

23 WK/NA

NS

9510-9523 420-437

17 4.0/9.5

9480-94 70

480-490 10

5.6/13.4

9667-9643 9630-9614 9577-9555 183-207 220-236 273-295

24 16 22 4 . 1 / 9 . 7 3 . 2 / 7 . 7 7 . 3 / 1 7 . 7

NS NS' DMB

9339-9331 621-629

8 6 .3 /25 .0

BB

9318-9256 642-704

62 7.4/27.7

DHB

9245-9124 715-836

121H 8 .2 /19 .7

DMB

9536-9510 9409-9372 9337-9287 314-340 441-478 513-563

21M 37 50 5 . 3 / 1 2 . 7 1 0 . 4 / 2 4 . 9 7 . 8 . 1 8 . 8

DMB DMB DMB

37T 37B

9100-9037 860-919

59 9 . 3 / 2 2 . 5

DHB

9265-9133 585-712

127M 7 . 5 / 1 7 . 8

DHB

38T 38B

9002-8944 956-1016

60 7 . 8 / 1 8 . 8

DC

9127-9037 723-813

90 8 . 2 / 1 9 . 7

DHB

41T 41B

8876-8851 1084-1109

25 8 . 2 / 1 9 . 6

DC

T h i n

Bay

42T 42B

8804-8743 1156-1217

61 9 . 3 / 2 2 . 4

r>HB

8899-8850 951-1000

49 0 . 3 / 0 . 7

DHB

43T 43B

8719 -8711 1241 1249

8 0 . 4 / 0 . 9

DC

ND

T a b l e page 4

45T 45B

ND

ND

1 o f 8

BSAT

8743 1217

8890 960

ThU-kncss X H i t Kon

l - l r v n t l o n Depth Th ickness X B i t

K l e v a t l n n Depth Th ickness X B i t Kill)

9728-9721 95-102

7 4.6/11.0

9560-9550 281-303

22 6/l4est

9357-9347 275-285

10 5.8/13.9

9294-9270 9172-9159 9127-9101 338-362 460-483 505-531

24 23 26 4.3/10.3 4.8/11.5 4.3/10.4

DMB NS NS

9474-9462 9423-9415 9357-9347 349-361 400-408 466-476

12 8 10 7.6/18.2 5 .6 /13 .5 7 .3 /17 .6

B BB BB

Th in

Rll

9217-9203 636.650

14 4 / 9 . 5

BB

NP

9249-9225 574-598

24 3 . 4 / 8 . 2

NS

9043-9018 810-835

25H 4/10est

NS

9202-9183 621-640

19 2.5/9.6

NS

8993-8968 8937-8922 860-885 916-931

25M 15 3 / 7 e s t 9 . 1 / 2 1 . 8

NS BB

9093-9077 539-555

16 8 . 3 / 1 9 . 9

B

9149-9132 674-691

17 7 . 1 / 1 7 . 0

DB

T h i n

NP

9034-9009 598-623

25H 5 . 3 / 1 2 7

DMB

Th in 741-745

4 7/17

Bay

T h i n

Bay

8984-8951 839-872

33 6 . 4 / 1 5 . 4

UDMB

8845-8815 787-817

30 0 . 5 / 1 . 1

DHB

8901-8852 922-971

49 3 . 0 / 7 . 2

DHB

8762-8732 8581-8674 1091-1121 1172-1179

30 7+ 3 .2 /7 .6 0 . 1 / 0 . 2

DMB BB

1824-8787 999-1036

37 2 .9 /7 .0

DC

8772-8754 1051-1069

18 0 .1 /0 .2

DC

8835 797

8787 1036

8732 1121

M e v n t i o n Depth Ih i ckness X H I : Kill)

F. lev. i t i , . Depth Ih lckneps X l i l t FXJO

Tlevntion Depth

8756-8748

59-67

8609-8576

206-239 33

3.5/8.5

i ;U'v; iLion Depth Thickness X H i t EOD

E l e v a t i o n Depth Thickness X n i t EOD

E l e v a t i o n Depth 1hiekncsR X B i t EOD

9.lH/i- 'U67 309-326

17 5 . 2 / 1 2 . 4

BB

Thin 9939-9919 165-185

20 8.1/11.3

Rll

Thin 8407-8389 408-426

18 7.8/18.6

B

9547-9515 9505-9483 171-203 213-235

12 22 5 . 2 / 1 2 . 4 6 . 5 / 1 5 . 6

mi n

9861-9841 243-263

20 6 .6/15 7

nn

8357-8347 458-468

10 6.3/16.0

9771-9745 333-359

26H 5/l2cst

NS

8292-8273 523-542

19 2/5est

NS

9359-9336 359-382

23 3/7est

NS

9734-9717 370-387

17M 3/7est

NS

9694-9645 410-455

45 4.2/8.4

DHB

9649-9602 455-502

5.9/14.2 DHB

9591-9558 513-546

33 6.5/15.4

BB

9522-9466 582-638

56 8.3/19.9

BB

9445-9392 659-712

53 5.3/12.5

8241-8219 8157-8125

574-596 658-690 22 32

2/5cst 3.3/7.9 NS BB

9325-9306 393-412

19 2/5est NS

8023-8012 7980-7966

792-803 835-849 11 14+

3.2/7.7 0.3/0.6

9377-9311 727-793

66 6.1/14.7

9302-9237 802-867

65 8.8/21/2

DMB

ND

9279-9238 439-480

41 9.0/21.7

DMB

9227-9202 491-516

25 9.1/21.9

DMB

9164-9148 554-570

9.7/23 3 B

9088-9072 630-646

16 3/7est

9088-9066 9011-8991 8931 8923 8825-8804 K79I-8772 8737-8714 8675-8660 8621-8616 8588-8482 8472-8457 605-627 682-702 762-770 868-889 902-921 956-979 1018-1033 1072-1077 1105-1211 1221-1236

22 20 8 21 19 23 15 5 106 15+ 4.9/11.7 6.0/14.4 3.8/8.9 3/7est 3/7est 6.4/15.4 5.0/11.9 5.5/13.1 4.5/10.8 0.1/0.3

B B B NS NS DMB B

9513-9490 9489-9469 [78-201 211-222

23 11 6.0/14.3 4.3/10.4

9500-9490 67-74

9463-9433 104-134

30 5.6/13.4

9435-9402 256-289

33 7.1/17.0

9366-9342 201-225

24 5.5/13.2

9342-9318 349-373

24 5/12cst

NS

9283-9259 284-308

24

3/7est NS

9307-9286 384-405

21

3/7est NS

9248-9230 319-337

18

2/5est NS

9275-9230 416-461

45

6.3/15.0 DMB

9210-9172 357-395

38 6.4/15.3

DMB

9197-9177 494-514

20 7.5/18.0

DMB

9143-9103 424-464

40 8.5/20.3

DMB

9142-9127 549-564

15 /16.6

9103-9069 464-498

34 7 . 4 / 1 7 . 7

DMB

9054-9049 9019-8961 637-642 672 -730

5 58 6 . 7 / 1 7 . 0 9 . 2 / 2 2 . 0

B DC

9019-8984 548-583

35 6.4/15.4

DMB

8945-8907 622-660

38 8.0/19.2

DC

Zone-34 548-583

35 6.4 /15 .4

DHB

9202-9069 9019-8960 8950-8908 8855-8832 902-1035 1085-1144 1154-1196 1249-1272

66H 59 42 23 6 . 9 / 1 6 . 6 7 . 5 / 1 7 . 9 5 . 8 / 1 3 . 9 7 . 7 / 1 8 . 5

3B'sSDC D C s DC DC

ND ND ND ND

8 7 9 9 - 9 7 7 5 1 3 0 5 - 1 3 2 9

2 4 + 0 . 1 / 0 . 3

DC

ND

8832 1272

8012 803

9036-9000 also Z-36 682-718 721-733

36 12 8.2/19.6 0.4/1.1

8961-8890 730-801

71 9.5/22.8

DC

8809-8713 758-854

95M 2.7/6.5

DC

8856-8722

837-971 78M

3.7/8.9 3DC's

8706-8637 861-930

69 3.6/8.7

DC

8673-8639 1018-1052

34 3.5/8.3

DC

8583-8559 984-1008

24 4 .3 /10 .2

8597-8569 8538-8522 1094-1123 1153-1169

29 16 3 . 7 / 8 . 8 3 . 8 / 9 . 0

DC DC

8513-8482 1054-1085

31 3.7/8.9

DC

part z-42

1085-1099

0.1/0.1 DC

ND 9000 718

ND 8482 1211

ND <8522

>1169

01304

ND 8482 1085

I l l Core Data

Ben in I ' o l u t Sub t l e l t a Tar Zone Data

Sunnyside Tar Sands Table I page 5 of 8

111 Zone * Data*

Elevation

Depth Thickness X BIL r.on

Elov.itton Depth Thickness X Bit KOI)

ii Am Elevation . 1 Depth g Thickness ~ X Bit

F.OD

IOT IUB 11T 1 IB 21T_ 21B

9262-9257 316-321

5 6.2/15.0

BH

9384-9351 107-140

26N 2 . 5 / 6 . 1

i l l l l ' s

Unk

n 8945-8933 633-645

12 8 . 0 / 1 9 . 2

II

9221-9206 9051-9042 270-285

15 NoTibit

440-449 9

4 .1 /10 .0

8919-8910 392-401

9 Nonb i t

- 1 F. levat ion

r l Depth ^ Th ickness

X B i t H h-or>

-1A E l e v a t i o n ,, Depth ^ Th ickness -1 X B i t p. rim

9809-9797 51-63

12 6 . 3 / 1 4 . 8

II

-1 D r v a t l o n

r l Depth ;* Th ickness

X B i t ^ E0I)

:i-l Elevation Jj Depth ^ Thickness p X Bit p KOI)

:i-2 Elevation T Depth

r't Thickness X Hi t

: i - IA I I. vat ion l l ep lh

g I h i c kness -X K i t

, ™ FOD

CT-4 E l e v a t i o n „ . , " '-rth

;; Thickness X Bit

£ EOD

c.l-5 E l e v a t i o n g Depth 35 Th ickness o X B i t

9J26-9293 88-121

33 6 . 0 / 1 4 . 3

Dl!

NP 9548-9539 112-321

9 6 . 6 / 1 5 . 5

B

9163-9153 9003-8989 251-261 411-425

10 14 Nonbit 4.8/11.5

I) B

22T 22B

Thin

9000-R963 491-528

37M 2.3/5.5

2B's

8899-8891 412-420

9505 9490 355-370

15

7.4/17.3 II

9400-9379 422-446

21 6 .3 /15 .0

Bll

8935-8907 479-507

28 6.2/14.7

B

23B 25T 25B 26T 26B 3IT 31B 32T 32B 33T 33B 35T 35B 36T 36B 99T 99B 37T 37B 38T 38B 41T 41B 42T

8818-8788 760-790

8882-8876 609-615

6 2/5est

8855-8841 456-470

14 Bit

8710-8687 8674-8666 8639-8593 8558-8545 8454-8442 8356-8339 868-891 904-912

23 8 3cst 3est NS NS

939-980 41

5.1/12.2 DHB

1020-1033 1124-1136 1222-1239 13

6.8/16.3 12

4.9/11.7 17

0.4/0 8

Nnnbi t B

9804-9795 9619-9590 20-29 :»n5-2'i4

9 29 7.2/17.3

BB

9531-9310 215-236

21 6.9/16.4

9641-9618 9483-943 7 48-7 1 206-252

23M 46 1.7/R.8 5.2/12.5

I'DB's DMB

8829-8803 8790-8771 8732-8705 662-688 701-720 759-785

26 19 26 2/5est ]/2est 7.5/18.0

NS NS B

17 4.0-9.7

8698-8678 8639-8621 613-633 672-690

20 18

Bit Bit NS NS

8585-8574 726-737

11 Bit

B

NT)

8585-8568 8553-8523 8523-8482 906-923 938-968 968-1009

18H 41 2.4/5.7 0.0/0.0

8418-8398 8354-8307 893-914 957-1004

21 47 Bit Nonbit

9328-9304 ND 532-556

24

3/7est NS

9216-9193 9180-9145 9116-9100

23 2/5est

35 2/5cst

NS

16 8.2/19.5

DMB

9079-9025 8974-8917 743-797 848-905

54 38H 7.5/17 8 7.0/16.7

DMB BB

8873-8819 949-1003

54 4.3/10.2

DC

E r o d e d

E r o d e d

9657-9645

23-35 12

0 0/0.0 B

9640-9609

40-71 31

0.0/0.0 DMB

9605-9526 75-154

79 Nonbit DMB

9509-9496

171-184

13 Nonbit

B

9656-9615 9575-9546 9509-9495 9442-9415 9403-9378

10-51 91-120 157-171 224-251 263-288 41 29 14 27 25

8.4/20.1 7.5/18.0 6.2/14.9 7.3/17.5 4.7/11.3 BB BB B DC DC

9442-9419 182-405

21

2/5est NS

9407-9388 4 17-4 16

19 2/5est

NS

9358-9336 388-410

9325-9306 421-440

22 19 3/7est 2/5est

NS NS

9379-9329 445-495

4 2M

8.2/19.6 2DC's

9297-9270 449-476

27 6.8/16.4

DMB

9319-9286 505-538

33

7.7/18.5 DMB

9266-9238 480-508

28 9.1/21.8

DC

NP

9158-9146 588-600

12 8"1/19.3

9154-9120 9114-9066 670-704 710-758

25M 48 6 .6 /15 .8 0 .0 /0 .1

2DC's DC

9097-9048 9038-8980 649-698 708-764

31M 56 0.2/0.5 0.1/0.1

2B's DC

NP

9310-9290 9279-9261 9234-9196

379-399 410-428 455-493 20 18 38

l/?est l/2est 7.6/18.2 NS riS DMB

NP 9118-9108 571-581

10 10.9/26.0

BB

9024-9019 665-670

5 Nonbit

B

8261-8193 1050-1118

54M Nonbit

DC

8181-8141 1130-1170

40 Nonbit

DC

Zone 24 850-868

18

6.8/16.3 B

ND

8086-8029 1225-1282

57 Nonbit

DC

43T 43B 45T 45B BSAT

ND ND 8393 1185

8523 968

8001-7973 1310-1338

28 Nonbit

Dt

8798-8738 1024-1084

60 3.4/8.2

2DC's

8684-8563 1138-1259

121 Nonbit

2DC's

8523-8501 1299-1321

22 Nonbit

DC

8485-8475 1337-1347

10 Nonbit

B

9346-9307 320-359

32M Nonbit

2B's

9047-9008 777-Blfi

39 Nonbit

DC

9273-9242 393-424

31 Nonbit

DC

8965-8930 859-894

22M Nonbit

2DC's

8998-8955 8902-8884 691-734 787-805

43 18+ Nonbit Nonbit

DC DC

7948-7917 1363-1394

31 Nonbit

DC

8372 939

7899-7822 1412-1489

77 N o n b i t

DC

ND 8731 1091

01305

Above c o l l a r

9378 2 88

9120 704

9136 610

9108 581

1. CORE DATA

1 /.one » Da cat! 1

6 Elevation Ucpth Thickness X lilt lol)

7 Elevation Depth Thickness X nit i-.nn

8 Elevation

1)0 [Ull I h l c k n e s s X H i t EOD

9 i: I ev . i t Ion Depth Thickness

x nit EOD

10 Flcv.it ion IVplh Thickness X Bit

FDD

I I K l e v . u i en D e p t h I h i c k n e s s X Hit I nil

V) K l e v . u Inn l l e p l h I h i c k n e s s .X B i t l"(ID

-1 1 E l e v a t i o n l lep t l i I h i c k n e s s X B i t KOD

B r u i n P o i n t S u b d e l t a Tar Zone Data

S u n n y s l d e T a r Snn t l s T.-ible 1 pane 6 of

.UI U» 21T 2IB 22T 22B 23T__23B 251_ 25B 26T___26B 3JX 3_1_B 32T 32B 33T 33B 35T 35B 36T 36B 99T 99B 37T 37B 38T 38B 41T 41B 42T 42B 43T 43B 45T 45B BSAT

Eroded 9592-9575 180-197

17 5.5/13.0

9349-9328 9207-9145 3 7 - 5 8 179 -241

21 62 7 . 3 / 1 7 . 5 4 . 5 / ; 0 . 6

II DUB

9 4 8 7 - 9 4 7 7 9 164-9359 6 1 - 7 1 184 189

10 5 4 . 0 / 9 . 7 5 . 1 2 e s t

DB BB

9783-9779 9635-9624 10-14 158-169

4 II 6.6/15.4 5.3/12.5

B B

9564-9542 208-230

22 4.9/11.6

9324-9298 224-250

26 4.7/11.1

BB

9592-9583 201-210

9

7 . 4 / 1 7 . 5

9 119-9285 9 2 - 1 2 6

3 ' . 5 . 6 / 1 3 . 3

BR

9 3 7 2 - 9 3 6 3 8 4 - 1 2 2

I8M 4 / Q e s t

1111

9 3 5 0 - 9 3 2 5 1 4 9 - 17',

ISM ' . . 7 / 1 1 . 2

DB

E r o d e d

NP 8 9 9 8 - 8 9 8 4 89 1 0 - 8 9 0 ) 4 1 3 - 4 2 7 ' , 8 1 - 3 0 8

14 27 4 . 9 / H 6 6 . 9 / 1 6 . 4

Thin T h i n 8 9 7 4 - 8 9 5 5 4 8 0 - 4 9 9

19 6 . 2 / 1 4 . 8

BB

9120-9105 900O-9000 8981-8949 579-594 690-699 718-750

15 9 32 3 . 4 / 1 0 . 9 6 . 6 / 1 5 . 6 6 . 3 / 1 5 . 0

B II

9 4 9 9 - 9 4 6 0 2 7 3 - 3 1 2

39 6 . 0 / 1 4 . 4

DMB

NP

9253-9248 295-300

5 l/2est

9541-9492 252-301

37M 4.6/10.9

BB

Zone 24 31-37

6 4.0/9.5

9416-9394 356-378

22 3/7est

NS

9017-8994

369-392 23

3/7est NS

9171-9149 377-399

22

l/2est NS

9435-9422 358-371

13

4/9.5est NS

9756-9734 37-59

22 3/7est

NS

8771-8746

640-665 25

3/7est NS

8822-B795 636-659

23 2/5est

NS

8778-8758 921-941

20 3/7est

NS

9384-9365 388-407

19 3/7est

NS

8982-8962 404-424

20 3/7est

NS

9137-9117 411-431

20 l/2est

NS

9412-9394

381-399 18

3/7est NS

9723-9707 70-86

16 2/5est

NS

8726-8701 685-710

25 5/I2est BSNS

8783-8762

670-691

21

2/5cst NS

8 7 4 9 - 8 7 2 4 9 5 0 - 9 7 5

25 5.4/12.8

9355-9321 417-451

34 6.5/15.5

DMB

8942-8891 444-495

51 7.5/17.9

DMB

9105-9048 433-500

46H 6.5/15.4

2DMB's

9369-9339 424-454

30 5.5/13.2

9700-9655 93-138

45 6.9/16.6

DMB

8690-8656

721-755

34 6.9/16.4

BB

8740-8706 714-748

34

6.8/16.2 DMB

8696-8667

1003-1032 29

7.2/17.2

9223-9216 549-556

8831-8824 555-562

7 3/7est

9038-9018 510-530

20 7.0/16.7

DMB

9239-9274 504-519

15 8.5/20.4

9192-9176 580-696

16 7.1/17.1

8775-8759 611-627

16 6.5/15.6

B

8959-8953 589-595

6 5.9/14.2

B

9252-9238 541-555

14 7.8/18.7

9136-9119 9092-9057 636-653 680-715

17 35 6.0/14.4 8.4/20.0

B DC

8725-8699 8698-8622 661-687 690-764

26 74 5.0/12.0 0.1/0.2

DMB DMB

8900-8876 8833-8787 648-672 710-761

24 51 7.7/18.5 3.8/9.2

DMB DMB

9168-9156 625-637

12 44 6.6/15.5 8.3/19.8

9116-9072 677-721

9597-9579 9535-9528 196-214 258-265

18 7 6.4/15.4 5.8/13.5

BB B

8706-8683 8596-8585 748-770 858-869

22 11

2.3/5.4 6.5/15.6 DUB B

8647-8622 8552-3542 1052-1077 1147-1151

25 10 4.8/11.4 6.2/14.9

DC B

9484-9463 9463-9403

309-330 330-390 21 60

2.4/5.6 3.7/8.8 DC DC

8517-8500 894-911 938-974

17 Void 3.9/9.3 Driller's

BB Note

8573-8587 8469-8466

881-917 958-988 36 30

7.1/17.0 Nonbit DMB DMB

8515-8495 ND 1184-1204

20 4.2/10.1

Hole RCT-6U: Drill cuttings to 1098, logged by HP cored 768-857 891-1003 1023-1043 ND to 753 6IM 78M 20

Bit Bit Nonbit no analyses

8603-8582 783-804

21+ Nonblt

DC

ND

9037-8998 756-795

39

7.9/18.9 DC

9384-9381 409-412

3+ 0.0/0.1

DC

ND ND

8963-8795 830-998

146H 7.0/16.8

2DC's

ND

8732-9725 1061-1068

8711-8679 1082-1114

32

0.0/0.1 DC

ND

8769

1003

8676 710

8787? 761?

8725 1068

9403 390

8500? 911?

8499 955

8495? 1204?

-14 Elevation Depth Thickness X Hit EOD

E r o d e d 9 4 2 9 - 9 3 6 6 6 3 - 1 2 6

48M 5 . 5 / 1 3 . 1

2 B ' s

Thin 9244-9232 248-260

12 7.5/17.9

9197-9157 9147-9106 295-335 345-386

40 41 4.9/11.7 7.4/17.8

DMB DMB

9064-8962 8899-8859 8827-8802

428-530 593-633 665-690 80H 40 25

6.9/16.4 4.0/9.7 Nonbit DC&BB DMB DHB/DC

8 8 5 9 6 3 3

01306

1 SECTION DATA

B r u i n P o i n t S u b d e l t a T a r Zone D a t a

S u n n y s i d e T a r S a n d s T * b l e 1 *>age 7 of 3

MS-6

o o

I I

MS-4 8

O r-i

D/uai

F . l e v a t i n n D e p t h T h i c k n e s s X B i t EOD

Election

Dor iii

Thickness

X Bit

EOD

F, leva Li on

Depth Thickness

EOD

F. Iev.it ion Depth Thickness X Bit BOD

KlL'ViiLlim

Depth Thickness X Bit EOD

Elevation Eroded

Depth Thickness

X Bit

EOD

Elevation Def-th Thickness X Bit EOD

Elevation

Depth

Thickness

X Bit

EOD

i;icv<i tion Depth Thickness X Bit EOD

Elevation Depth Thickness X Bit EOD

Elevation

DcpLli

Ihickness X Bit EOD

T 11 B__

E r o d e d

21 B 22 23 B T 25

NM

E r o d e d

E r o d e d

9947-9930 Thin 93-110

17 mod DUB

9830-9812 2i0-228

18 mod DMB

9748-9740 292-300

9762-9743 9690-9665 9557-9537 123-142 195-220 32fl-V.fl

19 23 20 mod mod mnd BB DUB BB

9899 21-

-9877 -43 22

mod

1

.0113-30

3D

-10100 -35 5

nine!

9365-9337 "242-270

28 mod DMB

Thin

NP NP 9760-9738 160-182

22 mod DUB

10015-10004 9946-9940 128-139 197-203

11 6 mod mod B NS

9254-9234 353-373

20 mod BB

8958-8925 127-160

33 2«%

9714-9695 206-225

19 mod DMB

NF.

T. A!—•-

9690-9670 350-370

20 mod DMB

9461-9428 ',17-457

40 mod DUB

9644-9639 276-281

5 mod

9391-9376 494-510

15 mod

32 B T 33

9627-9602 413-438

25 mod DMB

9357-9309 528-576

48 mod DMB

9608-9587 312-333

21 mod DUB

9760-9729 383 414

31 mod BB

T 35

9577-9455 463-585 122 mod DC

9284-9253 601-632

31 mod DC

9534-9435 386-485

99 mod DC

9721-9601 422-542 120 mod DMB

T 36 B T 37

9455-9312 585-728 143 mod DC

9245-9196 640-689

49 mod DC

9450-9432 4 70-488

18 mod

9590-9518 553-625

72 mod DMB

9264-9230 776-810

34 mod DC

9150-9083 735-802

67 mod DC

9420-9380 500-540

40 mod DUB

9518-9418 625-725 100 mod DMB

T 38

9210-9163 830-877

47 mod

9670-9648 9628-9589 9547-9532 9515-9431 9402-9374 9362-9339

9.3wt% DMB

NE 9069-9062 538-545

42-81 39

7.2wt2

123-138 15

7.7wc%

8824-8807 8788-8724 261-278 297-361

17 64 l-2ut% 3-4wtJ

NS DMB

5 3-4ut%

155-239 84

6.2wt% DMB

8966-8957 641-650

9 vk

5 2-3wt%

8924-8912 683-695

12 wk

8474-8444 611-641

30 2 4wt%

308-331 23

nonbit DC

8850-8840 757-767

10 nonbit

DC

Thin

DC

9026-8960 859-925

53H mod 2DE's

9322-9262 598-658

60 mod DC

9353-9329 790-814

24 mod BB

NM

41 B

9141-9087 899-953

54 mod DC

8912-8880 973-1005

32 mod DC

9210-9196 710-724

14 mod-wk

9301-9226 842-917

75 mod DC

42 B T 43

NM

9067-9033 973-1007

34 mod DC

8841-8758 1044-1127

69M nonbit 2DC's

9170-9087 750-833

43M nonbit 3BB's

9175-9038 968-1105

105M mod

2DC's

NM

9030-8945 1010-1095

85 mod DC

8 7 3 6 - 8 7 0 8 1 1 4 9 - 1 1 7 7

28 n o n b i t

DC

9054-9036 866-884

18 nonbi t

DC

9023 8938 1120-1205

7 2M mod BSDC

NM

8 7 1 5 - 8 7 0 4 8 9 2 - 1 0 0 3

11 n o n b i t

DC

T h i n

NM

8 1 8 6 - 8 1 6 2 8 9 9 - 9 2 3

24 n o n b i t

DC

NM

8 1 1 3 - 8 0 8 7 9 7 2 - 9 9 8

26 n o n b i t

DC

45 B

8933-8852 1107-1188

81 mod DC

8697-8561 1188-1124

136 nonbi t

DC

9 0 1 6 - 8 9 6 8 9 0 4 - 9 5 2

4 8 n o n b i t

DC

8 8 9 4 - 8 8 5 9 1 2 4 9 - 1 2 8 4

3 5 mod

nc

NM

9 8 1 6 - 9 7 9 9 100-117

17 5 . 4 / 1 2 . 9

KB

9 6 5 6 - 9 6 4 6 1 2 4 - 1 3 4

10 5 . 4 / 1 3 . 0

B

E r o d e d

NP

NP

9 5 1 7 - 9 4 71 7 3 - 1 1 9

46 3 . 9 / 9 . 4

DMB

9 6 5 1 - 9 6 2 6 2 6 5 - 2 9 0

25 2 / 5 e s t

NS

NE

9 3 8 7 - 9 3 7 1 2 0 3 - 2 1 9

16 4 . 3 / 1 0 . 3

9 6 2 6 - 9 6 0 6 2 9 0 - 3 1 0

20 l / 2 . 4 e s t

NS

NE

9 3 4 4 - 9 3 3 4 2 4 6 - 2 5 6

10 5 . 3 / 1 2 . 8

9 5 8 3 - 9 5 1 9 3 3 3 - 3 9 7

64 7 . 4 / 1 7 . 7

DMB

9 4 5 2 - 9 4 1 3 3 2 8 - 3 6 7

39 7 . 2 / 1 7 . 2

BB

9 3 0 3 - 9 2 6 8 2 8 7 - 3 2 2

35 7 . 1 / 1 7 . 0

9 4 7 9 - 9 4 6 2 4 3 7 - 4 5 4

17 6 . 4 / 1 5 . 3

8B

9 4 0 1 - 9 3 7 6 3 7 9 - 4 1 3

34 7 . 0 / 1 6 . 7

DMB

9 2 1 8 - 9 2 0 6 3 7 2 - 3 8 4

12 4 . 6 / 1 1 . 1

9 3 7 6 - 9 3 1 8 5 4 0 - 5 9 8

5 8 6 . 6 / 1 5 . 8

DMB

9 2 8 2 - 9 2 6 9 6 3 4 - 6 4 7

13 0 . 8 / 1 . 9

B

NM NM NM NM

9363-9305 9205 9173 417-475 575-607

58 32 6.4/15.3 0.1/0.2

DMB BB

9186-9115 404-475

71M 4.8/11.4

DMB

9058-8979 532-611

79 3 . 7 / 8 . 8

DMB

b e l o w c r e e k l e v e l and n o t e x p o s e d

8 9 1 6 - 8 8 7 3 8 8 0 5 - 8 7 5 3 8 7 1 0 - 8 6 9 7 8 6 5 2 - 8 6 2 9 6 7 4 - 7 1 7 7 8 5 - 8 3 7 8 8 0 - 8 9 3 9 3 8 - 9 6 1

43 34M 13 23 4 . 6 / 1 1 . 0 2 . 4 / 5 . 7 2 . 2 / 5 . 4 0 . 1 / 0 . 5

DMB 2 L ' s B B

8 8 5 2 1 1 8 8

RRRO 1005

9 1 9 6 724

8859 1284

9428 242

8 9 1 2 6 9 5

8352 733

E r o d e d 9 7 1 0 - 9 6 3 5 9 6 2 1 - 9 5 9 3 9 5 5 2 - 9 5 1 0 9 4 8 4 - 9 4 4 9 9 4 4 7 - 9 3 4 5 9 2 1 3 - 9 0 7 6 8 9 8 3 - 8 8 8 8 8 8 3 3 - 8 7 8 5 8 8 8 8 7 - 8 2 9 6 - 1 2 4 1 6 5 - 2 0 7 2 3 3 - 2 6 8 2 7 0 - 3 7 2 5 0 4 - 6 4 1 7 3 4 - 8 2 9 8 8 4 - 9 3 2 8 2 9

75 28 42M 35 102 137 95 4 8 5 . 8 / 1 3 . 9 9 . 6 / 2 2 . 9 6 . 5 / 1 5 . 5 8 . 2 / 1 9 . 6 9 . 3 / 2 2 . 2 5 . 9 / 1 4 . 1 7 . 1 / 1 7 . 1 0 . 1 / 0 . 1

DC BB 2 B B ' s DMB DMB DUB DC-DMB DC

NM 9 2 6 9 647

9305 475

NM NM 8 6 9 7 89 3

01307

MKASHRFD SECTION DATA

Bruin Point Subdelta Tn r 7-one Da tn

Sunnyslde Tar Sands

Table 1 pane 8 nf R

Measured Section

o o>

Data I

ElevaLion Depth Thickness X Bit FOD

Elevation Depth Thickness X Bit FOD

Elevation Depth Thickness X Bit EOD

.T_J1 ". 9891-9886

25-30 5

2.0/4.8

T 21 B

9741-9724 175-1>)2

17 4.3/10.3

Bit

9198-9176 9136-9080 342-364 404-460

22 56 4.8/11.6 3..7/8.8

25 26 B T 31 T 37 B T 38 B T 42 B T 43

9587-9560 9548-9526 9512-9479 329-356 368-390 404-437

27 22 l/2est <l/<2.

NS NS

E r o d e d

9420-9370 9316-9284 9284-9246 9152-9132 496-546 600-632 632-670 764-784

9012-9003 528-537

9 2/5est

8949-8904 8876-8839

591-636 664-701 45 37

l/2.4est 2.5/6est NS NS

33 4.7/11.2

BB

9741-9648 76-169 93

7.1/17.3 DC-DHB

8742-8737 798-803

5 2/5est NS

9635-9607 182-210

28 3.6/8.7 DMB

NP

37H 5 0/11.9 DMB&B

9550-9532 267-285

18 3.8/9.0

B

8702-8659 838-881

43 4.6/10.9 DUB

32 38 3.4/8.1 8.1/19.4 DMB DMB

9520-9467 297-350

53 2.0/4.7

BB

NH NH

20 4.3/10.4

BB

9431-9405 386-412

26 0.1/0.1

BB

T 45 B BSAT

9132 784

9467 350

8659 881

Elevation Depth Thickness X Bit EOD

Elovation Depth Thickness X Bit EOD

Klov.it I on Dep t h Thickness X Bit FOD

F 1 rv.i t i on

Depth Thickness X Bit EOD

Elevation Depth Thickness X Bit EOD

9182-9154

72-100 28

nonbit DB

8815-8771 439-483

44 2.9/7.0

BB

E r o d e d

8878-8840 154-192

38 1.5/3.5 2DB's

9.'(4.'.-(l/,22

254-27J

22 3.1/7.4

BB

9571-95J6 64-99

35 l/2est DB

567-571 4

4/10est

3 8636-8607 618-647

29 4.5/10.7

BB

9892-9874

28-46

8488-8467 766-787

21 3.9/9.5

9848-9845 9742-9719 72-75 178-201

1 23 4/l0est 3.8/9.1

below creek level and not exposed

9719-9692 9658-9638 201-228 262-282

27 20 2/5est 7.2/17.3

NS B

9599-9592

321-328 9498-9495 422-435

3 4/10est

9404-9372 516-548

32 4.1/10.2

8596-8586 8611-8608 421-424

3

8392-8376 640-656

5/12est 6.7/16.1

416-446

10 6.4/15.3

It

9I09-9O92 Thin '111 I n T 586-603

17 5.0/12.1

r, below level of Ranee Creek, section

8376-8354 656-678

22 3.7/8 9

NS

8342-8124 690-708

18 0.3/0.8

NS

Thin

8288-8266 744-766

22 6 0/14.4

8865-8845 830-850

20 5.2/12.5

not exposed

8735-8722 960-973

13 4.0/9.5

B

8698-8657 997-1038

41 5.1/12.2

DC

oil shale Intervals and Blue Marker

9326-9186 594-734

140 6.4/15.3

DMB

9184-9105 8992-9950 736-815 928-970

79 42 7.6/18.1 4.9/11.7

DMB DC

below level of Range Creek

8467? 787?

8950 970

8266? 766?

bel-v R646 below 1046

Flevat ion Depth Thickness X Bit EOD

10028-10017 90-101

1986 purpose: establish Blue Marker and effectiveness of surface gamma ray instrument

1988 purpose: illustrate abundance of carbonates near base of Parachute Creek Member

Elevation Depth Thickness X Bit FOD

9808-9791 Thin 1R;? -1 99

17 5.1/11.9

Thin 9677-9655 9653-9629 9593-9568 Thin 9516-9482 9948-9439 9368-9309 9268-9195 9172-9095 8995-8956 8880-8865 313-335 337-361 397-422 474-508 542-551 622-681 722-795 818-895 995-1034 1110-1125

22 24 25 34 9 59 73 77 39 15 4.6/10.7 3/7est 6.1/14.4 4.6/10.9 6.1/14.2 5.4/12.9 6.2/14.9 5.4/12.8 4.6/10.8 0.0/0.0

B NS B DUB B DMB DMB DUB DC DC

NH 8956 1034

01308

D r i l l (

D r i l l H o l e

A - 3 1

ui a

A - 3 2

CM vt

CT*

ui a (J H

A - 3 3 c

o ^ o w a (J H

A - 3 4

CM m •"- £-c^

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A - 3 5

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A - 3 6

u-l O O

SB ft-37

os •"-o

SB A - 3 8

*£> —'

CK

UJ O CJ H

A-39B

ro

S 10 "

S h e l l No . 1

CO *0

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_. a*

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: o r e D a t a

Z o n e r

D a t a 4

E l e v a t i o n D e p t h T h i c k n e s s X B I T EOD

E l e v a t i o n D e p t h T h i c k n e s s X B I T EOD

E l e v a t i o n

D e p t h T h i c k n e s s X B I T

EOD

E l e v a t i o n

D e p t h

T h i c k n e s s X B I T EOD

k i r v a t i o n D e p t h T h i c k n e s s X B I T EOD

E l e v a t i o n

D e p t h T h i c k n e s s

X BIT

EOD

E l e v a t i n n D e p t h T h t c k n e s s

X B I T

EOD

E l e v a t i o n

D e p t h T h i c k n e s s X B I T EOD

E l e v a t i o n

D e p t h T h i c k n e s s

X BIT EOD

E l e v a t i o n

D e p t h T h i c k n e s s

X B I T EOD

E l e v a t i o n DepLli T h i c k n e s s X R I T EOD

23T 23B 25T 25B

E r o d e

E r o d e d 9 7 2 5 - 9 7 0 6 0 - 1 9

19 UK NS

E r o

E r o

E r o d e d 9 3 8 6 - 9 3 8 1 1 3 - 1 8

5

NONE IT NS

E r o

THIN 9 2 8 1 - 9 2 6 0

1 1 7 - 1 3 8 21

1 . 5 / 3 . 5 NS

9 2 9 7 - 9 2 8 9 9 2 2 5 - 9 2 0 2

1 1 5 - 1 2 3 1 7 3 - 1 9 6 11 23

NA 5 . 6 / 1 3 . 3 BB NS

E r o d

26T 26B

I <l

9 6 9 S - 9 6 8 0

2 7 - 4 5 18 UK NS

d e cl

d e d

9 3 5 0 - 9 3 4 3 4 9 - 5 6

7

WK/NA NS

d e d

9 2 4 2 - 9 2 1 5

1 5 6 - 1 8 3 27

4 . 4 / 1 0 . 6

NS

9 1 8 1 - 9 1 7 1

2 1 7 - 2 2 7 20

3 . 5 / 8 . 3 NS

e d

3 1 T 31B

9 5 5 1 - 9 5 3 2 4 9 - 6 8

19 2 . 3 / 5 . 4

BB

9 6 4 5 - 9 6 2 6 8 0 - 9 9

19 4 / 9 . 6

DMB

E r o d e d

E r o d e d

9 6 3 2 - 9 6 1 1 2 0 - 4 1

21

4 . 2 / 1 0 . 2

DMB

9 3 0 3 - 9 2 9 8 9 6 - 1 0 1

5 NA

NS

THIN

NS

THIN

L

UI

S o

3 3 T 33B

9 4 7 0 - 9 4 5 2 1 3 0 - 1 4 8

18 7 . 1 / 1 7 . 1

DMB

9 4 8 5 - 9 4 4 2

2 4 0 - 2 8 3 4 3

9 . 8 / 2 3 . 4

DMB

E r o

9 5 8 2 - 9 5 5 3 7 0 - 9 9

29 5 . 0 / 1 2 . 0

DMB

THIN

BAY

9 2 0 0 - 9 1 7 0 6 4 - 9 4

30 2 . 4 / 5 . 7

DMB

9 0 8 3 - 9 0 6 0

3 1 5 - 3 3 8

23 6 . 9 / 1 6 . 6

DMB

9 0 7 7 - 9 0 4 5

3 2 1 - 3 5 3 32

7 . 8 / 1 8 . 8 DMB

9 5 9 7 - 9 5 7 7 2 0 - 4 0

2 0 5 . 3 / 1 2 . 6

DMB

T.u Z o n e I). n n ^ s l d e T a r

3 5 T 35B

9 4 0 9 - 9 3 5 9 1 9 1 - 2 3 1

4 0 7 . 2 / 1 7 . 2

DMB

9 3 8 6 - 9 3 7 3 3 3 9 - 3 5 2

13 1 0 . 4 / 2 4 . 8

BB

9 5 0 4 - 9 4 7 1 8 - 2 9

2 1

7 . 5 / 1 8 . 0 DMB

9 5 4 8 - 9 5 1 8 2 4 - 5 4

30

5 . 7 / 1 3 . 6 DMB

cl o d

9 5 0 3 - 9 4 4 8 1 4 9 - 2 0 4

55M

8 . 1 / 1 9 . 3 BB S DMB

9 2 0 3 - 9 1 7 4 1 9 6 - 2 2 5

29

5 . 2 / 1 2 . 5 DMB

THIN

NS

9 0 3 8 - 9 0 2 8

3 6 0 - 3 7 0 10

6 . 4 / 1 5 . 4

BB

9 0 2 4 - 9 0 1 6

3 7 4 - 3 8 2

a 7 . 2 / 1 7 . 3

BB

9 5 4 9 - 9 4 9 3 6 8 - 1 2 4

56

7 . 9 / 1 8 . 9 DMB

i H l l ' i L.I

n l . l

S a n d s

36T 36B

9 3 4 5 - 9 2 9 3 2 5 5 - 3 0 7

5 2 7 . 9 - 1 8 . 8

DMB

9 3 4 6 - 9 2 9 5 3 7 9 - 4 3 0

51 5 . 8 / 1 3 . 9

DMB

9 1 5 1 - 9 4 3 2 5 3 - 7 2

19

5 . 0 / 1 2 . 1 EMB

9 4 8 3 - 9 4 3 5

8 9 - 1 3 7 4 8

4 . 9 / 1 1 . 7 DMB

9 5 4 9 - 9 5 3 0 1 0 - 3 9

2 9 8 . 5 / 2 0 . 4

DMB

9 4 2 5 - 9 3 7 1 2 2 7 - 2 8 1

54 6 . 9 / 1 6 . 6

DMB

9 1 3 9 - 9 1 1 3 2 6 0 - 2 8 6

2 6

7 . 3 / 1 7 . 4 DMB

9 0 3 3 - 8 9 9 3 2 3 1 - 2 7 1

4 0 8 . 3 / 1 9 . 7

DMB

8 9 5 0 - 8 9 2 5

4 4 8 - 4 7 3 2 5

5 . 4 / 1 2 . 9 DMB

8 9 5 1 - 8 9 1 3

4 4 7 - 4 8 5 3 8

5 . 0 / 1 1 . 9 DMB

9 4 6 1 - 9 4 0 2 1 5 6 - 2 1 5

52M 6 . 0 / 1 4 . 2

DMB

9 9 T 9 9 B

9 2 6 5 - 9 2 2 5 3 3 5 - 3 7 5

2 5M 6 . 8 / 1 6 . 4

2 BBs

9 2 8 0 - 9 2 1 1 4 7 8 - 5 1 4

36 7 . 0 / 1 8 . 2

DMB

9 3 9 8 - 9 3 6 0 1 0 6 - 1 4 4

32M

6 . 1 / 1 4 . 7 BB & 1MB

9 3 9 9 - 9 3 5 9

1 7 3 - 2 1 3 4 0

6 . 7 / 1 6 . 1 DMB

9 5 1 2 - 9 4 8 4 5 7 - 8 5

2 8 5 . 7 / 1 3 . 7

L

9 3 4 0 - 9 3 1 3 3 1 2 - 3 6 6

39M

7 . 5 / 1 7 . 9 DMBSBB

9 0 5 7 - 9 0 1 3 3 4 2 - 3 8 6

4 4

6 . 7 / 1 6 . 0 DMB

THIN

NS

8 8 8 8 - 8 8 4 9 5 1 0 - 5 4 9

39 6 . 6 / 1 5 . 7

DMB

8 8 5 9 - 8 8 3 9

5 3 9 - 5 5 9 20

8 . 7 / 2 0 . 8 DMB

9 3 9 7 - 9 3 4 8 2 2 0 - 2 6 9

4 9 7 . 4 / 1 7 . 7

DMB

3 7 T 37B

9 1 9 3 - 9 1 1 9 4 0 7 - 4 8 1

74 6 . 1 / 1 4 . 7

DMB

9 1 9 5 - 9 1 1 7 5 3 0 - 6 0 8

7 8 7 . 7 / 1 8 . 5

DMB

9 3 3 9 - 9 3 1 5

1 6 5 - 1 8 9 2 4

9 . 1 / 2 1 . 7

DMB

9 3 3 3 - 9 2 5 0

2 3 9 - 3 2 2 83M

5 . 9 / 1 3 . 6 2 DMBs

9 4 ) 2 - 9 3 4 7 1 5 7 - 2 2 2

6 5 7 . 8 / 1 8 . 8

DMB

9 2 7 9 - 9 2 4 7 3 7 3 - 4 0 5

32

8 . 2 / 1 9 . 5 DMB

8 9 7 9 - 8 9 2 1 4 2 0 - 4 7 8

5 8

2 . 8 / 6 . 7 DMB

8 9 1 9 - 8 9 0 9 3 4 5 - 3 5 5

10 2 . 8 / 6 . 6

BB

8 8 1 1 - 8 7 6 1

5 8 7 - 6 3 7

50 2 . 8 / 6 . 7

DMB

8 8 0 0 - 8 7 4 9

5 9 8 - 6 4 9 51

3 . 2 / 7 . 7 DMB

9 3 1 0 - 9 2 3 4 3 0 7 - 3 8 3

76M 7 . 4 / 1 7 . 7

DMB

3 8 T 38B

9 2 0 8 - 8 9 8 9 5 4 5 - 5 5 9

14

NA/WK BB

THIN

BAY

T H I N

9 1 5 3 - 9 1 3 8 4 1 9 - 4 3 4

15 5 . 9 / 1 4 . 2

B

9 2 4 4 - 9 2 3 4 3 2 5 - 3 3 5

10 5 . 7 / 1 3 . 6

BB

9 1 6 7 - 9 1 3 7 4 8 4 - 5 1 5

3 0 2 . 7 / 6 . 6

L

8 8 4 6 - 8 8 2 5 5 5 3 - 5 7 4

2 1

0 . 1 / 0 . 2 DC

8 8 5 9 - 8 8 4 8 4 0 5 - 4 1 6

11 0 . 2 / 0 . 6

DC

8 6 5 5 - 8 6 4 5 7 4 3 - 7 5 3

10 0 . 1 / 0 . 1

DC

8 6 7 0 - 8 6 4 8

7 2 8 - 7 5 0 22

0 . 1 / 0 . 2

DC

THIN

NS

4 1 T 4 1 B

9 0 2 8 - 8 9 8 9 5 7 2 - 6 1 1

2 2M

4 . 0 / 9 . 6 2 B ' s

8 9 8 4 - 8 9 1 5

7 4 1 - 7 6 9

2 8 6 . 9 / 1 6 . 4

DC

9 1 7 0 - 9 1 1 7 3 3 4 - 3 8 7

5 3

3 . 7 / 8 . 9 DMB

9 1 1 2 - 9 0 3 4 4 6 0 - 5 3 8

68M

3 . 8 / 9 . 1 DMB

9 2 0 9 - 9 1 3 4 3 6 0 - 4 3 5

7 5 4 . 5 / 1 0 . 8

DMB

9 0 5 7 - 9 0 0 2 5 9 5 - 6 5 0

55 4 . 8 / 1 1 . 5

DC

ND

ND

ND

ND

9 0 9 2 - 9 0 3 7 5 2 5 - 5 8 0

5 5 7 . 2 / 1 7 . 1

DC

Tab l e

p a g e

42T 42B

ND

8 9 5 2 - 8 8 9 9 7 7 3 - 8 2 6

5 3

2 . 7 / 6 . 5 DC

9 0 6 2 - 9 0 3 9 4 4 2 - 4 6 5

2 3

0 . 2 / 0 . 4 DC

9 0 0 0 - 8 9 9 7 5 7 2 - 5 7 5

3 n o n b i t

DC

9 1 0 2 - 9 0 2 1 4 6 7 - 5 4 8

81M 0 . 3 / 0 . 6

2 DCs

8 9 6 9 - 8 9 5 2

6 8 3 - 7 0 0 17

0 . 1 / 0 . 2 DC

ND

ND

ND

ND

8 9 8 8 - 8 9 5 5 6 2 9 - 6 6 2

3 3 0 . 1 / 0 . 3

DC

2

1 o f 6

BSAT

8 9 8 9 6 1 1

8 8 9 9 8 2 6

9100 4 0 4

9 0 3 4

5 3 8

9 1 0 9 4 6 0

8 9 8 7 6 6 5

8 9 2 1 4 7 8

8 8 9 1 3 7 3

8 7 6 1 6 3 7

8 7 4 9 6 4 9

9 0 2 3 594

01309

D r i l l Ji«J_e_

A- 41 CO -J-O r~

° UJ Q CJ H

A - 4 3 - ^r

S T CTv

sa A- 44

n o

5 ^ ° U H

A- i5B r— M3

s s °

A - 41",

o o CO n CTv

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A - 4 7 — o o o <X) <T> CT-

U H

A- 48 r- O

r^ r t Cf

O H

A - •',<)

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M2 •£" crv

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S ° 5 ^ liJ Q

7.(111(7 •

n. i r . - i

r . U v . n t i o n

l> i - i ' Lb

T h i c k n e s s

X BIT i:on

I v l r v . i L j n n

l l c p L l i

T l i i f k i u - s : :

X H I T

KOl l

! ; ] . - v ; i t i n n

l t c p t . l t

• H i u - k n e r t s

X 111 r

Kon

lUcva t i on l l C ' I ' t l l

T h i c k n e s s

X H I T

KOI)

K ! r v ; U i n n

l k T t l .

l h i c k i K - s s

X H I T

K i l l )

K l c v c i t i o n

] ) ( j | )L ! l

Thickn. -ss X BIT roi»

l U c v n t i n , ,

l H T t l .

'Hi i c k n c s s

X HIT i;oi)

l.lcvril i o n

I H - | H l i

T i n . k n r s s

x r.n K i m

E l l ' V . l l i n n

D i - I ' t ' i

T l l i c k n o s s

X r. IT run

K k v i i L i o n

I V l ' L l i

11) L c k n c s H

X H I T

r . in i

E l e c t i o n

I H - I ' t l i

T h i c k n e s s

X B I T

Ki l l )

2 3 1 2311 2 5 T 2511

T H I N 9 1 7 9 - 9 1 6 7

1 2 9 - 1 4 1

1 2

W K / N A

N S

E r o i

e

THIN 9190-9166 14 7-171

24 4 . 1/10.2

NS

E r o d e d

E r o d e d

i ; r o d , - d

E r

l - . r o d o d 9 ] 8 S - 9 1 6 2

1 3 8 - 1 6 4

2 6

2 . 1 / 5 . 0

N S

2 6 T 2 6 H

9 1 4 3 - 9 1 1 1

1 6 5 - 1 9 7

3 2

5 . 3 / 1 2 . 5

B B & NS

d e d

r u d e d

9 1 5 3 - 9 1 2 9

1 8 4 - 2 0 8

2 ' .

3 / 7 . - S L

NS

E r <>

K r o d !• i l

[ i d <• d

9149-9130 177-196

19 WK/NA

NS

31T 31B

9017-9007 291-301

111 3 . 9 / 9 . 3

BB

9093-9074 244-263

19 6 . 0 / 1 4 . 4

1MI1

d o <l

9746-9721 55-105

50M 1 . 4 / 8 . 1 DMB (. BB

9767-9728 HI -49

39 7 . 5 / 1 8 . 0

DUB

9581.-9573 43 -58

13 7 . 8 / 1 8 . 8

1!

THIN

NS

111 • y C . - i n y i m S i i l i . l . - l t i i

T .n r Z o n e D n t n

S u n n y s i d e Tar Sands

33T 33B

8984-8948 324-360

36 5 . 8 / 1 3 . 9

DMB

92 48-9218 111-143

111 6 . 1/15.1

mm

9051 -9020 281-317

36 7 . 8 / 1 8 . 8

DUB

9652-9625 149-176

27 5 . 3 / 1 2 . 7

DUB

9767-9728 75-117

42 4 . 5 / 1 0 . 8

2 BBs

9561-9541 7 0 - 9 0

20 8 . 4 / 2 0 . 1

l l l l

9549-9525 20-44

24 6 . 8 / 1 6 . 4

DMB

THIN

NS

35T 35B

893-1-8897 37 4-411

37 6 . 8 / 1 6 . 2

DMB

9159-9137 202-224

22 7 . 9 / 1 9 . 0

DKB

9473 -9443 10-40

30 5 . 9 / 1 4 . 1

CUB

8990-8964 347-373

26 8 . 2 / 1 9 . 5

DMB

9577-9528 224-267

43 7 . 3 / 1 7 . 5

DUB

9605-9577 172-200

28 9 . 2 / 2 2 . 0

DMB

9565-9513 50-102

52 7 . 5 / 1 8 . 0

l»m

9496-9444 135-187

52 8 . 7 / 2 0 . 8

DM 11

9507-9458 62 -111

49 8 . 2 / 1 9 . 8

DUB

THIN

NS

36T 36B

8849-8812 459-495

36H 5 . 8 / 1 3 . 8 2 DHBs

9118-9055 243-306

63 3 . 1 / 7 . 5

2 DMBs

9378-9351 105-132

27 4 / 9 . 7

BB

8919-8881 418-456

38H 3 . 7 / 8 . 9 DUB & BB

9565-9516 15-64

49 3 . 5 / 8 . 3

DUB

9502-9449 299-352

53 6 . 3 / 1 5 . 0

DMB

9552-9477 225-300

75 5 . 7 / 1 3 . 7

DUB

9485-9417 130-198

68 8 . 6 / 2 0 . 6

DMD

94 32-9 364 199-267

68

5 . 0 / 1 2 . 1 DUB

9426-9369 143-200

57 7 . 2 / 1 7 . 1

DUB

8925-8873 401-453

52 7 . 8 / 1 8 . 7

DMB

99T 99B

THIN

NS

THIN

9330-9293 153-190

37 7 . 7 / 1 8 . 6

DUB

8840-8807 497-530

33 4 . 4 / 1 0 . 6

DMB

9475-944 2 105-138

33 7 . 7 / 1 8 . 4

DMB

9439-9375 362-426

64 8 . 9 / 2 1 . 3

DMB

9418-9413 359-364

5 7/17esc

B

9405-9378 210-237

27 1 0 . 0 / 2 8 . 1

BB

9354-9315 277-316

39 8 . 7 / 2 0 . 8

DMB

9358-9290 211-279

68 7 . 8 / 1 8 . 8

DMB

8826-8789 500-537

37 4 . 2 / 1 0 . 2

BB

37T 37B

8748-8736 560-572

12 0 . 4 / 0 . 9

L

TIUN

9283-9257 200-226

26 9 . 8 / 2 3 . 5

DMB

8761-8711 576-626

50 1 . 1 / 2 . 5

DUB

9410-9330 170-250

80M 6 . 4 / 1 5 . 4

DMB

9349 -9321 452 -480

28 7 . 6 / 1 8 . 3

DMB

9402-9323 375-454

79 7 . 2 / 1 7 . 3

DC

9334-9304 2 8 1 - 3 1 1

19H 8 . 5 / 2 0 . 4

2Bs

9283-9199 348 -432

84

7 . 3 / 1 7 . 8 DC

9272-9226 297-343

46 8 . 5 / 2 0 . 4

DC

8749 -8706 577 -620

43 1 . 2 / 2 . 9

DC

38T 38B

ND

8962-8927 399-434

35 0 . 1 / 0 . 2

DC

9156-9141 327-342

15 5 . 9 / 1 4 . 1

BB

ND

9234-9220 346-360

14 4 . 4 / 1 0 . 6

BB

9251-9184 550-617

20M 5 . 0 / 1 1 . 8

2B 's

9286-9266 491-511

20 2 . 8 / 6 . 8

DMB

THIN

BAY

9169-9156 462-475

13 7 . 0 / 1 6 . 7

B

9163-9084 406-485

79 7 . 1 / 1 6 . 8

DUB

ND

41T 41B

ND

ND

9108-9072 375-411

36 3 . 4 / 8 . 0

DMB

ND

9192-9139 388-441

53 6 . 0 / 1 4 . 3

DMB

9140-9013 661-788

127 6 . 7 / 1 6 . 1

DMB

9167-9133 610-644

34 7 . 2 / 1 7 . 1

DC

9115-9070 500-545

36M 7 . 1 / 1 6 . 9

DC & BB

9070-8959 561-672

I I I 8 . 2 / 1 9 . 1

DMB

9054-8989 515-580

65 6 . 4 / 1 5 . 4

DMB

ND

42T 42B

ND

ND

8999-8983 484-500

16 0 . 4 / 0 . 8

DC

ND

9083-9050 497-530

33 0 . 1 / 0 . 2

DC

8985-8954 816-847

31 2 . 8 / 6 . 8

DC

9083-9067 694-710

16 0 . 3 / 0 . 7

DC

9031-9015 584-600

16 N3NBIT

BB

8937-8920 694-711

17 5 . 6 / 1 3 . 3

BB

8956-8909 613-660

47 1 . 3 / 3 . 0

DC

ND

T a b l e 2

page 2 of 6

43T 43B

ND

ND

ND

ND

ND

8 9 2 1 - 8 9 0 1 8 8 0 - 9 0 0

20+ 0 . 1 / 0 . 2

DC

ND

ND

8903 -8881 7 2 8 - 7 5 0

22 0 . 0 / 0 . 0

DC

ND

ND

BSAT

8746 562

9055 306

907 2 411

8730 607

9139 44 1

8963 838

9133 64 4

907O 54 5

8920 711

8925 644

8721 605

01310

Dry C a n y o n Suhi l r 1 tn

D r i l I Molt-

A-54

O r-l

A - 5 5

- . O

A-56

— o

A-5 7

m o

'>:'.«.•". 1

E l c v . u i on DcpLh Th i c k n c s s X n i l COD

El i -v . i l . i on

Tli i c kness X HIT EOD

FJcvnr ion ])c-|icli Th i ckness X HIT am

ElevnL i o n l)t-|>th Th i ckncss X HIT EOD

2JT _2jill 25T 251)

K r o il i- (1

E r o d e d

E r o d e d

E r o d e d

26T 26B

I I I IN

31T 31B

THIN

NS

9760-9728 21-53

32 1 0 . 1 / 2 4 . 3

DUB

9759-9743 22-38

16 5 . 2 / 1 2 . 5

BB

9783-9776 12-19

7 5 . 7 / 1 3 . 6

B

Tar Zone Data S u n n y s i d c Tar Sands

33T 33B 35T 35B 36T 36B

9608-9584 9547-9497 9469-9406 99 -123 160-210 238-301

24 38H 63 2 . 9 / 7 . 1 7 . 0 / 1 6 . R 8 . 5 / 2 0 . 5

BR B B 1 1 DHB

SHALLOW PILOT MINE HOLE

SHALLOW PILOT MINE HOLE

SHALLOW PILOT MINE HOLE

99T 99B

9368-9355 339-352

13 7 . 9 / 1 8 . 9

B

37T 37B

9319-9234 388 -473

85 7 . 5 / 1 7 . 9

DHB

38T 38B

9198-9178 509-529

20 4 . 8 / 1 1 . 6

D i s t a l DMB

41T 41B

9106-9041 601-666

65 7 . 6 / 1 8 . 1

DMB

42T 42B

8991-8991 716-726

10+ 0 . 0 / 0 . 0

DC

T a b l e 2 page 3 of 6

43T 43B BSAT

ND 9030 677

'- Zone II • .\-r-H E t o v a ! ion '"• I" o d o d ')7<>9-<l;(-() 9718-9711 SHALLOW PILOT MINE HOLE

11, l-[ I, 311-)') niil 6 1 - 6 8 S S T h i c k n e s s 9 7

x HIT 6 . 3 / 1 5 . 2 7 . 9 / 1 9 . 0 „ a EOD i) BI) u H

<- Zone 11 -<•

A-59 E l c v i l i o n E r o d e d 9 7 6 2 - 9 7 5 8 9 7 4 0 - 9 7 3 0 SHALLOW PILOT MINE HOLE ,., 0 D e p t h 4 0 - 4 4 and 6 2 - 7 2 g 2 T h i c k n e s s 4 1 0 0 1 X HIT 4 . 4 / 1 0 . 4 6 . 1 / 1 4 . 6

S ° EOD BB B

A-61 E l e v a t i o n E r o d e d 9 4 2 9 - 9 4 0 0 9 3 3 5 - 9 2 7 6 9 2 2 7 - 9 1 8 8 9 1 4 6 - 9 1 2 6 9 0 6 4 - 9 0 1 6 8 9 4 8 - 8 9 4 0 N D N D N D 9016 „ „ D e p t h 5 5 - 8 4 1 4 9 - 2 0 8 2 5 7 - 2 9 6 3 3 8 - 3 5 8 4 2 0 - 4 6 3 5 3 6 - 5 4 4 468 3 S T h i c k n e s s 2 9 5 9 3 9 2 0 38M 8 • * x BIT 6 . 4 / 1 5 . 3 6 . 3 / 1 5 . 2 5 . 5 / 1 3 . 3 5 . 0 / 1 2 . 0 2 . 3 / 5 . 5 0 . 1 / 0 . 2 fj £ EOD BB DMB DMB BB 2 DCs DC

A-62 E l c v a ! inn E r o d e d 9 4 5 6 - 9 4 2 3 9 3 6 2 - 9 3 5 9 9 2 S 3 - 9 2 6 9 9 2 5 1 - 9 1 9 8 9 1 8 4 - 9 1 3 7 9 0 5 4 - 9 0 4 2 9 0 0 8 - 8 9 6 0 N D N D 8977 m o Dep th 2 2 - 5 5 1 1 6 - 1 2 9 1 9 5 - 2 0 9 2 2 7 - 2 8 0 2 9 4 - 3 4 1 4 2 4 - 4 3 6 4 7 0 - 5 1 8 501 5 £ T h i c k n e s s 3 3 1 3 1 4 5 3 4 7 1 2 4 8 " * x HIT 6 . 6 / 1 5 . 9 1 0 . 5 / 2 5 . 2 3 . 7 / 8 . 9 3 . 4 / 8 . 1 1 . 8 / 4 . 4 4 . 5 / 1 0 . 8 1 . 1 / 2 . 5 o 8 EOD DMIi DC B DC DMB BB DHB

D r i l l Z o n e H o l e D.it.cr 101 100 1 IT 1IB 21T 21B 22T 22B 23T 23B 25T 25B 26T 26B 31T J I B 32T 32B 33T 33B 35T 35B 36T 36B 99T 99B BSAT

CD-I E l e v a t i o n HUN THIN 8 3 0 7 - 8 3 0 0 8 2 8 4 - 8 2 6 5 ND ND ND ND ND ND ND ND ND D e p t h 4 3 0 - 4 3 7 4 5 3 - 4 7 2

>- o I h i c k n c s s " ' ° X BIT o H Kill)

CD-2 E l e v a t i o n III 1W THII-co Depth -o o , . , co o I h i ' k n c s s

X B I T EOD

7 4 . 1 / 9 . 9

n

8377-8370 481-488

7 4 . 1 / 9 . 7

19 4 .7 /11 .3

B

ND

W o

Elevation 8954-8945 8812-8795 8692-8679 8630-B608 NP 8453-8427 8411-8392 B350-8321 THIN 8228-8214 8170-8149 8102-8068

wo Depth 114-123 256-273 376-389 438-460 615-641 657-676 718-747 840-854 898-919 966-1000

"" Thickness 9 17 13 22 26 19 29 14 21 34+ X HIT 3.6/8.6 0.1/0.3 6.8/16.4 5.4/13.0 3/7ost I/2osl 2.4/5.8 1.8/4.4 2.8/6.7 4.0/9.5 EOD BB BO B B NS NS B B B

-£> O O O

01311

M e a s u r e d S e c t i o n D a t a — • • •

Measured S e c t i o n

MS-5

r~~ CO

M S - 7

CO \D

UJ UJ

HS-fl m o CO r-

U i DJ H CO

M S - 9

CO r»

Ul UJ

M S - 1 1 O i "

UJ UJ

M S - 1 2

O —"

M S - 1 1

O -1

i n o 0> 0>

M S - ! >4

oo oo

•y oo

UJ UJ

MP- I S

CO r»

00 r»

UJ UJ

.-. / .OIIC"**

D a t a ! T 10 B

E l e v a t i o n Depth Th ickness X B i t ROD

E l e v a t i o n Depth Th i ckness X B i t Eon

Elevation Depth Th i ckness X B i t E0D

F-lcv.it i on DepLh Th i ckness X B i t ton

E l e v a t i o n DrpLli Tli i ckness X BiL PAID

E l f v n t i o n Depth Th ickness X B i t E0D

F.lcvat i on Depth Th ickness X B i t Kill)

Elev.it ion Depth i h i r k n e s s X B iL Eon

F,lev,-uion 3949-89)5 Depth i 0 - 5 i Th ickness 1U X B i t l - 2w tZ EOD »B

T 1

Dry Cnnynn Subduit .n T n r Zone D a t n

Sunny s i de_ Tn r S*in<1 s

T 33 B

9 7 3 3 - 9 7 1 1 0 - 2 2

22 mod

T h i n 9 4 5 0 - 9 3 8 5 1 3 5 - 2 0 0

65 mod DMB

T h i n

T 35_. ? _

9 6 5 6 - 9 6 0 6 7 7 - 1 2 5

4 8 mod DMB

9 3 4 7 - 9 3 3 2 2 3 8 - 2 5 3

15 mod

9 5 1 3 - 9 4 6 8 3 2 2 - 3 7 7

4 5

mod

DMB

T h i n

9 1 3 0 - 9 1 2 2 1 5 0 - 1 5 8

wk BB

9 4 3 8 - 9 4 0 6 9 3 6 6 - 9 3 5 1 6 2 - 9 4 1 3 4 - 1 4 9

32 15 3«t% 5wt% DMB DC

E r o d e d 9 5 0 5 - 9 4 9 5 5 - 1 5

10 3-4wtS!

BB

9 4 6 8 - 9 4 5 8 ' i 2 - 5 2

10 3 - 4 v t %

BB

8711-8699 . 276-290

14 l -2wt%

I'.!!

8 6 3 9 - 8 6 2 7 3 5 0 - )62

12 lut '< BB

8487-8471 502-518

16 3/7est

NS

8468-8450

521-5)9

4/l0cst BSNS

9205-9178

193-220

27

7-8wtZ BB

8'i04-8389 585-600

15 2-6wt%

DMB

Thin 8991-8971

407-427

<5 20

NS BB

8301-8281 688-708

20 l-2v>t7,

8259-8201 730-788

58 nonblt

CMB

36 B T 99

9356-9333 489-512

23 mod

9653-9630 162-185

23 mod

9062-9055 218-225

7

3wt%

9606-9560 125-173

46 mod DMB

9278-9268

307-317

10

mod

9217-9165 628-680

2 5M

mod 2BB's

9609-9654 206-251

45 mod DMB

8957-8916

323-364 41

wk DMB

9327-9281

173-219 46

lwt% DC

9442-9397

68-113

45

4wtZ DMB

8953-8920 445-478

33 4-6wtZ CMC

Thin

T 37 B

9482-9426 251-305

38H mod 2BB's

9226-9183

359-402 32M

wk-mod

2BB's

9125-9064 720-781

32M mod

2BB's

9482-9420 333-395

62

mod DMB

Thin

<5

NS

9200-9116 300-384

84 nonblt

DC

9397-9352 9352-9287

113-158 158-223

45 65

8-10wtI 5-6wtI DMB DBM

8888-8841 8914-RR07 510-557 584-591

47 7 l-2wt% nonblt CMB C

9530-9502 285-313

28 mod DMB

Table 2

page 4 of 6

9337-9281 9235-9224 9162-9074 9021-9001 8942-8908 9074 396-452

56 mod DC

498-509

11 mod

9101-9094 9075-9050 484-491 510-535

7 25 wk-mod wk-mod

571-659 88

mod DC

NM

712-732 20

nonblt BB

NM

791-825 34

nonbIt DC

NM

9340-9279 9247-9165 475-536 568-650

61 82 mod mod DHB DMB

8797-8759 NM 483-521

33M nonblt 2DC's

NM NM

9260-9251 9229-9182 9113-9098 250-259 281-328 397-412

9 28M 15 5-6utZ 4-5utZ l-2utl

BB 2BB's C

NM NM NM

8 0 7 2 - 8 0 5 1 9 1 7 - 9 3 8

21 n o n b l t

BB

8 0 1 4 - 7 9 7 7 9 7 5 - 1 0 1 2

31M n o n b l t

2 B B ' s

7 9 3 4 - 7 8 8 9 1 0 5 5 - 1 1 0 0

34M n o n b l t

2 B B ' s

9050

535

T h i n

9 1 6 5 - 9 1 0 5 6 5 0 - 7 1 0

60 mod DMB

NM

8 7 7 2 - 8 7 6 0 1 0 7 3 - 1 0 8 5

12 n o n b l t

DC

9 1 0 5 - 9 0 5 0 7 1 0 - 7 6 5

5 5 mod DMB

NM

NM

9 0 5 0 - 8 9 9 0 7 6 5 - 8 2 5

6 0 mod DMB

NM

9 0 6 4 781

8977 8 3 8

8 9 1 6 364

NM 9200 300

9098

412

8281 708

01312

Measured Section

HS-16

o o o <-» oo a*

vi uj H ca

MS-17 o rj m-

oo

H CO

US-1 9 *D cO

—1 -J 0> CO

H CO

MR-20 o *0 -3 CO C CO

H co

MS-21 O c-J

m o c a-H CO

MS-22

-cr -•

CK CO

UJ uj H ca

MS-23

r> co

a* oo

H CO

HS-24

CO ~ 0* CO

UJ UJ H CO

HS-25 O -3

*o a* a* aj

UJ UJ H CO

MS-26

O -3

to a*

UJ UJ H CO

Zone-*

Data! T 11

Elevation

Depth Thickness

X Bit

E0D

Elevation

Depth

Thickness

X Bit

ROD

Elevation

Depth

Thickness

X Bit

E0D

Elevation

Depth

Thickness

X Bit

EOD

Elevntinn

Depth

Thickness

X Bit

E0D

Elevation

Depth

Thickness

X Bit

E0D

Elevation

Depth

Thickness

X Bit

E0D

B T 21 B T 23 B

Eroded 8753-8733 47-67

10 4-6wt%

BB

Eroded

Elevation Eroded Thin Thin

Depth

Thickness

X Bit

E0D

Elevat ion

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

<2 <2

NS NS

T 25 B

8588-8575

212-225

13 4/lOest

NS

NE

E r o

9080-9056

246-270

24 nonhit

NS

T 26 B

8505-8553

235-247

12 4/10est

NS

Eroded

NE

d e d

9034-9024

292-302

10 nonhit

NS

Dry

Suri

T 31 B

Thin

<5 NS

Eroded

Thin

Eroded

9665-9620

180-225 40M

5-6wt%

B&BB

Thin

9016-8959

310-367

57 2-5wt%

BB

' Canyon Subdelta

Tar Zone Data

in^side Tar

T 33 B

Thin

<5 NS

Thin

<5

NS

9274-9265

166-175

9 4-5wt%

B

9510-9472

0-38 38

4-5wt% BB

9577-9520 268-325

57 6wt% BB

9530-9426 105-209 104

6wt% DUB

Thin

<2

NS

Eroded

Sands

T 35 B

8289-8275 511-525

14 2wt% BB

Eroded

Thin

<5

NS

9227-9201 213-239

26 6-7wt%

BB

94 36-9374 74-136

62 5-6wt% DMB

9505-9481 340-364

24 7wt% BB

9354-9312 281-323

42 3wt% DC

Thin

9564-9487 46-123

77 3-8wt% DMB

Eroded

T 36 B

8205-8193 595-607

12 lwt% BB

9215-9182 45-78 33

4-6wa CUB

8838-8781 268-325

57 3-4wt% DMB

9166-9134 274-306

32 7-8wt%

BB

9360-9337 150-173

23 4wt% DMB

9471-9339 374-506

132 6wt% DMB

9289-9227 346-408

62 l-2wt%

DC

8825-8775 501-551

45M 3-4ut% BSBB

9469-9430 141-180

39 2-5wt%

BB

9566-9528 24-52 38

2-8wt% BB

T 99 B

NP

9156-9126 104-134

30 4-5wt% CMB

Thin

<5

NS

9102-9087 338-353

15 4utZ

B

9322-9290 188-220

32 3-4wt% DMB

9330-9290 515-555

40 4-5wt%

BB

9190-9180 445-455

10 l-2wt%

B

8686-8674 640-652

12 3wt%

B

9411-9368 199-242

43 4-5wt%

BB

9515-9460 65-120 55

4-8wt% DMB

T 37 B

8129-8111 671-689

18 nonbit

C

Thin

8754-8741 352-365

13 4wt%

BB

9065-9051. 375-386

11 6wt%

B

9271-9247 239-263

24 3wt% BB

9210-9152 635-693

58 4-5wt%

BB

9150-9137 485-498.

13 2-3wt%

B

8656-8594 670-732

33M 4wt%

B&DMB

9274-9208 336-402

66 2-5wt% DMB

9450-9355 130-225

86M 4-8wt% DMB

T 38 B

8036-8021 764-779

15 nonbit

C

Thin

8364-8598 472-508

17M 2vt% 2BB's

Thin

9178-9170 332-340

8 3«t%

B

9110-9095 735-750

15 4-5wt%

B

9118-9081 517-554

37 2wtX DC

8540-8530 786-796

10 2wt%

B

9156-9136 454-474

20 2«t%

B

9247-9187 33?'393

60 3-8wt%

DC

T 41 B

7979-7955 821-845

24 nonbit -

B

Thin

8503-8489 603-617

14 nonbit

DC

Thin

9i45-9077 365-433

68 !-2wt% DMB

9055-9019 790-826

28M 4-5wt%

BB

9033-8950 602-685

83 l-2wt%

DC

8484-8386 84 2-940

98 2-5wt%

DC

9063-8975 547-635

88+ nonbit

DC

9142-9082 438-498

60 2-3wt%

DC

T 42 B

NM

NM

NM

NM

9037-9025 473-485

12 nonbit

DC

9001-8855 844-990

146 2-5wt%

DC

8915-8850 710-785

13 lwt% DC

8386-8316 940-1030

90 2-4wt%

DC

NM

Thin

nonbit

T 43 B

NM

NM

NM

NM

NM

NM

NM

8183-8160 1143-1166

23 nonbit

DC

NM

NM

Table page

T 45 B

NM

NM

NM

NM

NM

NM

NM

NM

NM

NM

• 2 5 of 6

BSAT

8193 607

9005 255

8581 525

90 'i 386

9077 433

8855 990

8902 733

8296 1030

9136 474

9082 498

01313

Measured

Section

co —'

Data T 10 B 11 B

Elevation 8725-8721 8577-8572 8478-8475

Depth 0-4 148-153 247-250

Thickness 4 5 3

X Bit 3.7/8.8 nonbit S.4/8. I

F.OD 1)11 l)H I'll

Elevation 8480-8473 8262-8254 8214-8202

Depth 0-7 218-226 266-278

Thickness 7 8 12

X Bit 3.2/7.6 4.8/11.6 9.4/22.5

EOD nn DB B

Dry c . i i i yc t i XIIIHICI [ a

Tar Zone Data

Sunnyside Tar Sands

23 11 25 B T 26 11 31

8306-8299 8245-8232 8220-8204 8150-8143

419-426 480-493 505-5?1 575-582

7 13 16 7

3.2/7.6 2.9/6.9 2wt% lwt%

11 NS NS 11

NC 7967-7942 7930-7917

513-538 550-563

25 13

IwtZ 3.0/7.3

NS NS

NM

T 35

8092-8080

633-64 5

12

nonbit

B

8013-7980

712-745

33

nonbit

DMB

7888-7861

837-864

27

nonbit

DMB

T 36 B T 99 B

'W>U 2

page 6 of 6

T 37 B_

7822-7789

903-936

33

nonbit

DC

NM

8142

583

HS-29

CM In

CO r~

ua u

HS-30

in in

oo r-

UJ ua

HS-31

r- oo

OO r-

ua ua

MS-3 2

CO y£)

<j\ oo

MS-33

c-l CD

CT> OO

ua ua

MS-3 4

O m

CT> ON CO r—

ua ua

MS-36

o o O r-

m r—

ua ua

Elevation

DepLh

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

8304-8286

16-34

18

1.2/2.9

DB

NM

8146-8135

24-35

11

2.3/5.5

DR

Eroded

NM

8920-8916

0-4

4

5.7/13.7

DB

Thin

8145-8129

175-191

16

3.1/7.3

DB •

8175-8156

175-194

19

0.5/1.2

DB

7974-7957

196-213

17

2.4/5.8

DB

9442-9415

38-65

27

4.9/11.7

DB

NM

Thin

8131-8117

169-183

14

2.2/5.4

DR

NP

NP

7810-7792

360-378

18

5.1/12.1

BB

9169-9142

311-338

27

2.9/6.9

DB

NP

8629-8623

291-297

6

5.0/12. 1

B

8025-8023

275-277

2

3-4wt%

R

7970-7960

350-360

10

1.8/4.2

R

NP

NP

Thin

8928-8918

102-112

10

4.5/10.8

DB

Thin

7962-7948

330-352

14

3.5/8.3

DB

7823-7805

497-515

18

nonbit

NS

7832-7817

518-533

15

lwt%

NS

7676-7649

494-521

27

nonbit

NS

NE

8813-8796

217-234

17

lwt%

NS

8387-°.371

533-549

16

3-4ut%

NS

7836-7800

464-500

36

trace

NS

7780-7752

540-568

28

ntnbi t

NS

7790-7762

560-588

28

1«%

NS

7624-7603

546-567

21

nonbit

NS

NE

8772-8743

258-287

29

lwt%

NS

8364-8356

556-564

8

3-4wt%

NS

7777-7770

523-530

7

trace

NS

7682-7654

638-666

28

2.0/4.9

BR

7734-7723

616-627

1 1

2.2/5.4

B

7582-7570

588-600 12

3.2/2.8

B

8954-8920

526-560

34

6.8/16.3

BB

8701-8644

329-386

57

4.0/9.6

BB

8281-8261

639-659

20

1«%

BR

NM

7624-7590

696-730

34

2.0/4.7

BB

7697-7656

653-694

41

1.6/3.7

BB

7530-7521

640-649

9

1.9/4.7

B

8886-8857

594-623

29

4.4/10.6

BB

NP

NP

NM

NM

NM

7451-7437

719-733

14

2.7/6.6

BB

8818-8804

662-676

14

5.6/13.4

BB

8608-8584

422-446

24

4.8/11.5

BB

8182-8178

738-742

4

l-2wt%

NS

NM

NM

NM

7404-7380

766-790

24

0.8/1.8

BB

8759-8730

731-750

29

7.9/19.0

BB

8489-8431

541-599

58

8.3/19.8

BB

8112-8066

808-854

46

2.0/4.8

BB

NM

8677-8648

803-832

29

6.0/14.5

BB

NM

917-953

36

0.1/0.6

NM 7590

730

NM 7656

694

NM 7380

790

8576-8563

904-917

13

1.8/4.3

B

NM

NM

NM

8563

917

8529

501

8066

854

7777

523

MS-

OO

60 a\

•.o t*~

no tar zone data; measured Tor oil shale inLervais and Blue Marker

T 22 B__ T 24 B

Elevation 8757-8714 8603-8596 8356-8346 8235-8216 8216-8191 8177-8158 8104-8082

Depth 63-106 217-224 464-474 585-604 604-629 643-662 716-738

Thickness 43 7 10 19 25 19 22

X Bit nonbit nonbit 3.3/7.7 1.5/3.5 4/9est 3/7est l/3est

EOD BB B B B NS NS NS

7941-7898 7832-7807

879-922 988-1013

43 25

0.6/1.5 nonbit

7747-7713

1073-1107

34

0 . 0 / 0 . 0

NM 7927 893

01314

U r i l 1 C c

D r i l l

M o l e

S S - N W - l

o —• r-i o

Ul Q U r-

S S - N W - 2

r-l O

(J 1-

S S - N U - 1

- f o

UJ a U f-

S S - N W - 4

\0 CM

U t -

S S - N W - 5

a^

[J D (J i -

S S - N W - 6

n o

o->

S P - M W - 7

o O

w o

U H

WCT-3A

O -J tN o

UJ O

WCT-4

cN-n

U Q

f!N- 1 5 O n

U O (J H

>re I ) ; l l : l

' / .one-*-

))..U.+

E l e v . i t i o n

D e p t h

T h i c k n e s s

X B i t

KIM)

I ' . l o v . H i « n

D e p t h

' t h i c k n e s s

X I t i l

i-;ni)

F.l c v . i t i n n

D e p t h

T h i c k n e s s

x m i F.OD

E l e v n t i o n

D e p t h

Tti i c k n e s s

x u u r.an

E l e v . i t i o n

D f p t - l i

T h i c k n e s s

X H i t

EOD

E l G v . i t i o n

D e p t h

T h i c k n e s s

X H i t

EOD

E l c v . i t i o n

D e p t h

T l i i r k n c s s

X H i t

EOD

E l r v . i t i o n

D e p t h

T h i c k n e s s

X B i t

r e m

E l e v . u i o n

D e p t h

D i i e k n o s s

X K i t

EOD

K l e v . i t i o n

D e p t h

T h i c k n e s s

X B i t

EOD

E l c v n t i o n

I K - p l h

T h i c k n e s s

X H I t

EH[j

9899-9847 9798-9781 27-79 128-145 52 17

3.1/7.4 4.5/10.7 Ml B

9673-9647 9610-9600 71-97 134-144 26 10 -2/5 -4/9

Eroded 9709-9679 71-101 30

8.4/20.0 BB

Eroded 9682-9648 38-72 34

8.8/20.9

9593-9572 127-148

21 9 . 4 / 2 2 . 4

B

Whltmore C.inyon Subdelt.-i T.ir 7.one D.nta

_ Sunnyside Tar Sands

T 35 B

Eroded 45-71 26 0.0 DC

9764-9755 9740-9722 9652-9580 162-173 186-204 274-346 11 18 72

2.6/6.2 4.4/10.4 7.0/16.7 B B DNB

76-113 37 0.0

161-175 14 0 B

9546-9521 380-405 25

0.3/0.7

9566-9541 178-203 25 -6/14

9515-9478 229-266 37

-5/12

9464-9444 9419-9408 280-300 325-336 20 1 1

-6.5/15.5 "3.5/8.4

9713-9705 9679-9630 9573-9495 33-41 67-116 173-251 8 49 78M

1.5/3.5 1.6/3.9 4.1/9.9 1) DC 2DC's

Eroded 9590-9552 9509-9409 21-59 102-202

9625-9619 9573-9521 155-161 207-259

6 52 4.5/10.8 6.3/15.1

9514-9460 206-260 54

8.0/19.1

9380-9352 0-28 28

3.2/7.5 BB

9702-9651 18-69 51

5.6/13.4 DMB

9389-9384 11-16 5

4.7/11.1

9506-9476 274-304 30

12.4/29.7

9393-9341 327-379 52

8.1/19.3 DC

38 4.3/10.3 BB

9340-9257 40-123 83

2.8/6.8 DMB

9641-9592 79-128 49

7.8/18.7 DC

9340-9315 60-85 25

2.9/6.9 DC

9459-9418 321-362 41

6.9/16.4 DC

100 3.6/8.6 DC

9229-9171 151-209 58

3.8/9.1 DC

9552-9458 168-262 73H

2.8/6.8 DC

9283-9268 117-132 15

3.0/7.0 DC

9362-9254 418-526 108 nonblt DC

260-284 24

0.3/0.7

9575-9549 9544-9507 9459-9445 9360-9336

9359-9344 387-402 15

0.1/0.2

9284-9246 59-97 38

0.1/0.2

Tabic 3 page 1 of 2

T 42 B B5AT

ND +9620

9337-9319 9285-9236 9185-9151 383-401 435-484 535-569 18 49 34

9.3/22.1 2.6/6.1 nonbit DC DC DC

9148-9105 ND 632-675 43

nonbit DC

9117-9078 9048-8961 603-642 672-759 39 87

nonbit nonbit DC DC

9543 383

9408 336?

9374 372

9409 202

91717 209?

9342-9297 378-423

45 0 .1 /0 .2

DMB

ND

ND

ND

9442 278

9255 145?

9408 372

9236 484 01315

Whitmore Canyon Sulxlel t.i

Measured

Measured

Section

HS-35

co o

— CO

co CO

[O UJ

MS-3 7

rJ O

UJ UI H 01

MS-38

UJ UJ

MS-39

O <n in co co --

UJ UJ H 03

MS-40 O O -< CO CO <*t

UJ UJ H B3

MS-41

^ m in iO

UJ UJ H to

MS-42

i£> (-1

UJ UJ

MS-4 3

CO <n .£> —

Ul UJ

HS'44 in O ill CO cr —<

U) UJ

Section Dat

Zone-*

Data*

El eva t ion

Depth

Thickness

X Bit

EOD

Elevat ion Depth Thickness X Bit KOI)

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X Bit

EOD

E]evat ion

Depth

Thickness

X Bit

EOD

Elevation

Depth

Thickness

X B U

EOD

Elevation

Depth

Thickness

X Bit

EOD

Elevation

Depth

Th ickness

X Bit

EOD

E] eva tion

Depth

Thickness

X Bit

EOD

a

T 10 B

8408-8402

10-16

6

3.3/7.9

DB

Thin

T U B

9234-8197 184-221

37 1.7/4.0

Dts

Thin

T 21 B

Below cree

Thin

Eroded

T 22 B

:k level and

8742-8725 471-490

17 1.6/3.8

111!

Eroded

Eroded

9959-9955

6-10

4

2-3wt%

NS

S

T 23 B

not expose

8668-8654

547-561

14

0.9/2.2

111)

9918-9897

47-68

21

l-2wtZ

8B

Tar Zone Data

unnyside Tar Sands

T 25 B

d

8580-8568

6J5-647 12

IwtZ NS

9565-9556

0-9

9

nonbit

NS

Thin

9853-9828

112-137

25

0-lwtZ

NS

T 26 B

8557-8530

658-685 27

IwtZ NS

Eroded

Eroded

Eroded

Eroded

9545-9519

20-46

26

l/2est

NS

Thin

9800-9768

165-197

32

0.3/0.7

NS

T 31 B

8496-8486

719-729

10

1.0/2.5

B

9700-9668

20-52

32

6.6/15.7

BB

9850-9754

0-86

86

8.3/19.8

BB

9786-9778

24-32

8

3.2/7.6

B

9932-9910

22-44

22

5.2/12.4

BB

9513-9496

52-69

17

0.5/1.2

B

9593-9558

92-127

35

9.5/22.8

BB

9755-9713

210-252

42

2.4/5.8

BB

T 32 B

8401-8394 814-821

7 1.5/3.7

B

9631-9614

89-106

17

8.4/20.0

B

9703-9693

147-157

10

7.3/17.4

B

9734-9694

76-116

25M"

5.1/12.1

B&B

9843-9817

111-137

26

6.0/14.5

BB

NP

9525-9498

160-187

27

8.3/19.9

BB

NP

T 33 B

9312-8310

903-905 2

trace

NS

9576-9572

144-148

4

2-3wt%

NS

9655-9644

195-206

11

6.2/14.9

B

9655-9628

155-182

27

10.3/24.7

BB

9774-9754

180-200

20

4.5/10.8

BB

9398-9363

167-202

35

2.3/5.6

DMB

9475-9426 210-259

49 1.9/4.5

BB

9643-9625

322-340

18

0.7/1.7

B

T 35 B

8264-8255

951-960 9

IwtZ

B

9527-9480

193-240

47

5.1/12.2

BB

9570-9527

280-323

43

5.9/14.3

BB

9540-9532

270-278

8

4.6/11.1

B

9717-9652

237-302

51M

2.5/5.9

BBiDHB

9304-9302

261-263

2

lwt%

NS

9360-9329 325-356

31

0.8/1.9 BB

NP

T 36 B

8185-8175

1029-1040

11

2.0/4.8

B

9420-9410

300-310

10

1.5/3.5

B

9497-9434

353-416

63

4.3/10.4

DMB

9485-9461

325-349

24

7.7/18.4

B

9591-9524

363-430

5 OH

3.8/9-0

BSBB's

9228-9205

337-360

23

9.0/21.6

S

9271-9253 414-432

15H 3.1/7.5 BIBB

9490-9465

475-500

25

9.9/22.3

BB

T 99 B

8159-8146

1056-1069

13 trace

B

9383-9360

337-360

23

3.5/8.4

BB

9400-9390

450-460

10

3.9/9.4

distalDMB

9409-9391

401-419

18

1.0/2.4

B

NP

NP

NP

9430-9406

535-559

24

1.8/4.4

BB

T 37 B

8112-8101

1103-1114

11

trace

DMB

9323-9206

397-514

117

5.0/12.0

DMB

9355-9321

495-529

34

5.8/13.8

BB

9313-9304

497-506

9

2.7/6.4

B

9498-9471

456-483

27

5.8/13.8

BB

9157-9134

408-431

23

1.2/2.9

B

9212-9179 473-506

33

1.3/3.1

BB

9350-9333

615-632

17

2.4/5.7

BB

Table

page

T 38 B

NM

9163-9125

557-595

38

nonbit

DC

9210-9183

640-667

27

nonbit

BB

NM

9372-9363

582-591

9

9.7/23.4

BB

NM

NM

9190-9180

775-785

10

2.6/6.1

B

! 3

2 of 2

BSAT

8195?

222?

8101

1114

9205

514

9325

529

9304

506

9363

591

9134

431

9179 506

9180

785

no tar zone d.i ta; measured for o i l sluile i n te rva l s and il lue Marker

01316

L

)£&%2ti W

J?~~

V

WILLIAM S. CALWNfD.Sc. ^ x

CONSULTING: GEOLOGIST •---"""'

25200 VILLAGE CIRCLE • GOLDEN, COLbRADO 80401-9642 • PHONE (303) 526-0711

\

July 30, 1990

Mr. Robert E. Lumpkin Director, Solid Resources Amoco Corporation Suite 600 305 East Shuman Boulevard Naperville, Illinois 60563-8408

Dear Mr. Lumpkin:

This three volume report represents a summary of the geology of the Sunnyside Tar Sands project. The results of the 1989 exploration program are included and integrated into the geological framework that has developed since 1980. The 1989 field work was completed with the helpful assistance of Bill Babcock.

The summary and conclusions, as well as recommendations, occur at the beginning of the written report in Volume I. All photographs, figures and tables are in numerical order in the Appendix at the end of Volume I. The five maps and five cross sections are in Volume II. The five maps include Regional, Geology, Tar Sand Isopach, Base of Saturation and Structure Contour of Blue Marker. Twenty-six strip logs of drill holes and measured sections are in Volume III.

The support and cooperation of Amoco during both the field and research phases of this project is gratefully acknowledged. The excellent drafting was completed by Shari Foos and the high quality air brushing on the maps was completed by Mike Ambrosio, both of Amoco Production in Denver.

Ten copies of this report have been made. Eight copies will be sent to your office for distribution. Two copies have been retained here in Denver... one copy for John Rozelle and one copy for myself.

If there are any questions regarding the geological aspects of the Sunnyside Tar Sands project that need clarification, please contact me.

Sincerely,

Wm. S. Calkin 01130