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'i ExxonMobil Production Compa,oy Alaska Interest - Joint Interest U.S. ) P.O. Box 196601 Anchorage, Alaska 99519-6601 ) EJf(onMobil \ Production November 29, 2004 2004 Report Distribution List Re: Completion Report for Point Storkersen #1 Enclosed is the Completion Report for the final closure of the Point Storkersen #1 site on the North Slope. The majority of this work was completed" last winter in accordance with the Corrective Action Plan and related permits. ExxonMobil returned to the site this summer to clean up any remaining debris and revegetate the disturbed areas. After seeding was completed, an agency site visit for ADNR and ADEC was conducted. This report should satisfy all site closure and project reporting requirements pursuant to the copied agencies and their respective permits / regulations. Should you have any questions or require additional information, please contact me at 907-564-3691 or Buddy Hand at 281-654-8457. Sincerely, JV ,£ l$.~.9 Mike Barker Environmental Advisor DMB:ddm Attachment DmblPt. Stor1<ersen #1 Final Report 11-04.doc c: Distribution List (Attached) SÇ¡~NNE.L> DEe 1 6 2004 A Division of Exxon Mobil Corporation PatriCia Bettis AK Dept. of Natural Resources Div. of Mining, Land & Water 550 West ih Avenue, Suite 1 020 Anchorage, AK 99501-3562 Leon Lynch, AK Dept. of Natural Resources Division of Mining, Land, & Water 3700 Airport Way Fairbanks, AK 99709-4699 Rex Okakok, Director of Planning North Slope Borough P. O. Box 69 Barrow, AK 99723 Gary Schultz, AK Dept. of Natural Resources 3700 Airport Way Fairbanks, AK 99709 Bruce Webb, Alaska Dept.of Natural Resources Division of Oil and Gas 550 West 7th Avenue, #800 Anchorage, AK 99501-3510 ') Point Storkersen #1 Final Completion Report Distribution Terry Carpenter U.S. Army Corps of Engineers Regulatory Branch P..O. Box 6898 Anchorage, AK 99506-6898 Kathleen Sheehan-Dugan AK Dept. of Natural Resources Office ofProj. Mgmt. & Permitting 550 West iti Avenue,#1660 Anchorage, AK 99501-1000 Craig Perham US Dept. of Interior Fish and Wildlife Service 1011 East Tudor Road Anchorage, AK 99503-6199 Dick Shideler AK Department of Fish & Game 1300 College Road Fairbanks, AK 99701-1599 Judy Bittner AK Dept. of Natural Resources State Historical Preservation Office 550 West ih Avenue, Suite 1310 Anchorage, AK 99501-3565 ') Cindy Godsey U.S. Environmental Protection Agency (EPA) Region 10 Anchorage Office 222 West ih Avenue, #19 Anchorage, AK 99513-7588 Linda Nuechterlein AK Dept. of.Env..Conservation 555 Cordova Street Anchorage, AK 99501 . Jim Regg AK Oil & Gas Conservation Commission 333 West ihAve., Suite 100 Anchorage, AK 99501 Jack Winters AK Dept. of Natural Resources Office of Habitat Mgmt. & Permitting 1300 College Road Fairbanks, AK 99701-1599 Judd Peterson AK Dept. of Env. Conservation 555 Cordova Street Anchorage, AK 99501 ~CANNED ( ( Project Completion Report J fo'1~..() 33 Point Storkersen No.1 (API No. 500292001600) Prepared for EJf(onMobil Refining and Supply Company Global Remediation 601 Jefferson Street Houston, Texas 77002 November 2004 CH2N1HILL 301 West Northern Lights Boulevard, Suite 601 Anchorage, Alaska 99503-2662 (907) 278-2551 ANC/CTS1 07 .DOC/041 060009 ( Table of Contents Section Page Declaration..................................................................................................................................... ......1 Recommendation for Closure of the Flare Pit.....................................................................l Recommendation for Closure of the Reserve Pit ...............................................................2 Recommendation for Closure of the Drill Pad ...................................................................2 1 In tro d ucti on ........................................................................................................................ 1-1 1.1 Project Objectives................... ........................................................................ .............. 1-1 1.2 Scope of Work .......... ............ .................. ...................... ........... ........................ ............. 1-2 1.2.1 Cleanup Activities ............... .................................................. ...................... 1-2 1.2.2 Screening and Sampling Activities.................. .......................................... 1-3 2 Project Organization and Responsibilities ................................................................... 2-1 2.1 Specialized Contractor Services ............ ................................. ............ ........................ 2-1 2.1.1 Survey..... ......... ............. ... ...... ....... ...................... .......... ..... ........ .......... .......... 2-1 2.1.2 Well Abandonment and Well Head Removal......................................... 2-2 2.1.3 Grinding and Injection Services................... ................................ .............. 2-2 2.1.4 Laboratory Services................. ...................................................... .............. 2-2 3 Pt. Storkersen #1 Background ......................................................................................... 3-1 3.1 General Background......... ......... .... ................. .... .... ............ ............................. ..... ....... 3-1 3.1.1 Drilling Operations and Site Construction............................................... 3-1 3.2 Past Site Assessments Activities.............................................. .......................... ........ 3-2 3.3 Onsite Conditions Prior to Corrective Action.......................................................... 3-8 3.3.1 Overall Site Conditions ...............................................................................3-8 3.3.2 Soils... ......... ....................... ......... ....................... ....................................... ...... 3-8 3.4 Environmental Conditions.................... ........................................................ ............. 3-9 3.4.1 Reserve Pit ......... ........ ...................... ............................................................. 3-9 3.4.2 Inactive Flare Pit .......................................................................................... 3-9 3.4.3 Drill Pad.................. ............................ ............................................. ............. 3-9 3.5 Cleanup Criteria............ ...................................... .......................... .................. ............. 3-9 3.5.1 Extent of Contamination Based on Cleanup Criteria ........................... 3-10 4 Summary of Closeout Activities ..................................................................................... 4-1 4.1 Ice Road Construction and Use................................. ...... ......... .................................. 4-1 4.1.1 Water Usage................................................................. .............. ................... 4-2 4.2 Pad and Pit Snow Removal................... ................................... .................................. 4-3 4.3 Well Abandonment..................................................................................................... 4-3 4.4 Excavation Activities................................................................................................... 4-3 4.4.1 Exempt Restricted Gravel and Unit 1 Drilling Wastes........................... 4-3 4.5 Field Screening and Sampling ...................................................................................4-7 4.5.1 Sample Types ................................. .............................................................. 4-7 4.6 Transport and Disposal................ ............... ................................................................ 4-8 ANCfCTS1 07 .DOCf041 060009 III ) I TABLE OF CONTENTS ) 5 6 Appendix A B C Figure 1-1 3-1 3-2 3-3 4-1 5-1 5-2 5-3 5-4 IV 4.7 Backfilling and Grading.... ..... ......... .............. ........... .... .................... ..... ........... ........... 4-9 4.7.1 Drill Pad and Well Head........................................................................... 4-10 4.7.2 Reserve Pit Cap ......... ....... ............. .................. .................. ........ ......... ........ 4-10 4.7.3 Flare Pit Cap ............................................................................................... 4-11 4.8 Winter Cleanup and Site Inspection arid Polar Bear Monitoring .......................4-11 4.9 Summer Cleanup and Revegetation .......................................................................4-12 I Conditions after Closeout Aetivities.............................................................................. 5-1 5.1 Screening and Sampling Results for Excavation Areas.......................................... 5-1 5.1.1 Step 1 Area: Excavation of Overlying Gravel to Elevations Ranging from 6.5 to 5.5 ft. ................................................................. 5-1 5.1.2 Step 2 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 4.0 ft. AMSL.. ...................... ............... ........ .................... ............. ...... 5-1 5.1.3 Step 3 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 5.5 ft. AMSL.. ......................... ................ ...................... ........... .......... 5-2 5.1.4 Step 4 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 4.5 ft. AMSL ....................................... .............. ....................... .......... 5-2 5.1.5 Step 5 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 3.5 ft. AMSL............................ ...................... ................... ............... 5-13 5.2 Stockpile Sampling Results.............................................................. ......... ............... 5-13 5.2.1 Exempt, Restricted Gravel (Step 1) Stockpile ........................................ 5-13 5.2.2 Well Head Stockpile ................ ...................................... ...................... ...... 5-13 5.3 Revegetation and Planned Monitoring................................................................... 5-13 5.3.1 Revegetation Activities .............................................. ............................... 5-14 5.3.2 Performance Standards ............................................................................. 5-15 ] ~ C onel usi ons......................................................................................................................... 6-1 6.1 Substantial Effects Assessment (after Closeout)...................................................... 6-1 6.2 Conclusion.......................................................... ..... ....... .............................................. 6-2 Manifest and Progress Reports Tracking Laboratory Data Reports and Data Evaluation NPDES DMR Point Stor kersen No.1 Location............ ................. ................................ ........ .................. 1-3 Flare Pit Boring Locations.... .......... ... ....................... .......................................................... 3-3 Drill Pad Boring Locations ........................... ..................................................................... 3-5 Estimated Extent of DRO Contamination....................... ....... ..... ....... ........................... 3-13 2004 Site Remediation....... ......................... .................................................... .................... 4-5 Step 1 Evaluation................................................................................................................ 5-7 Step 2 Evaluation....................................................... ........ ................................................. 5-9 Step 3 Evaluation.................................................................................................... ............ 5-7 Step 4 Evaluation................................................................................................................ 5-9 ANC/CTS1 01.DOC/041 060009 5-5 Table 2-1 3-1 3-2 4-1 4-2 5-1 5-2 5-3 5-4 r 5-5 l 5-6 5-7 r [ [ \ [ I I ( ( TABLE OF CONTENTS Step 5 Evaluation............................................. .......... ....................................................... 5-13 Team members and Responsibilities...........:.................................................................... 2-1 Point Storkersen #1 Site Assessment Activities.............................................................. 3-7 Geotechnical Conditions (Soil Types and Properties) of the Drill Pad and Inactive Flare Pit-Point Storkersen #1................................... ..................... ........ ............. 3-9 Documented Water Usage........................................................................... ..... ......... ........ 4-2 Field Screening and Confirmation Sampling............. ................................... .......... ........ 4-8 Flare Pit Field Screening and Confirmation Results for Step 1 Area........................... 5-3 Flare Pit Field Screening and Confirmation Results for Step 2 Area........................... 5-5 Flare Pit Field Screening and Confirmation Results for Step 3 Area........................... 5-7 Flare Pit Field Screening and Confirmation Results for Step 4 Area........................... 5-9 Flare Pit Field Screening and Confirmation Results for Step 5 Area......................... 5-11 Stockpile Field Screening and Confirmation Sampling Results................................. 5-14 Revegetation Project Schedule, Performance Standards, Monitoring and Reporting Requirements............................................ ...................................... ................ 5-16 ANC/CTS107.DOC/021180001 v TABLE OF CONTENTS -) } I J J . ,1 , VI ANC/CTS1 07 .DOC/041 060009 EXECUTIVE SUMMARY Declaration This project completion report provides information pursuant to the requirements of Title 18, Chapters 60 and 75, of the Alaska Administrative Code (18 AAC 60 and 18 AAC 75). On the basis of information contained in this report, the Pt. Storkersen #1 inactive flare pit, reserve pit, and drill pad should be declared closed by the Alaska Department of Environmental Conservation (ADEC) and the Alaska Department of Natural Resources (ADNR). State, federal, and local agencies involved in this project included the ADEC, ADNR, (Division of Mining, Land and Water; Division of Oil and Gas; Office of Habitat Management and Permitting; Office of History and Archaeology-State Historic Preservation Office), the Alaska Department of Fish and Game, the u.S. Fish and Wildlife Service, the u.S. Army Corps of Engineers, the U.s. Environmental Protection Agency, and the North Slope Borough (NSB). This report is intended to satisfy the reporting requirement for the above agencies and their respective permits / regulations. Recommendation for Closure of the Flare Pit The recommendation for a closure declaration for the flare pit is based on the following: . About 1,970 neat cubic yards of drilling wastes were removed from the flare pit and hauled to Drill Site 4 in the Greater Prudhoe Bay Unit for disposal by ANC\CTS1 07 .DOC/041 060009 f 'C. . grinding and injection (G&I) into Class II injection wells. About 403 neat cubic yards of restricted gravel were removed and hauled to Drill Site 4 for disposal by G&I. ExxonMobil (XOM) opted to dispose of it by G&I instead of burying and capping it with clean fill in the flare pit excavations (as approved by ADEC). . The gravel was classified as "restricted;" it contained petroleum contamination in concentrations below site cleanup levels. The restricted gravel also was RCRA-exempt because the source of the petroleum contamination was drilling wastes. About 15 cubic yards of metal debris also was uncovered and removed during excavation of the reserve pits and flare pit. The metal was transported to and disposed of in the North Slope Borough Service Area 10 Landfill. . More than 37 field screening samples and 18 confirmation samples were collected during closure to help guide removal of the wastes from the flare pit, and to confirm that remaining in- place soil (as well as cover material) did not exceed cleanup criteria. About 4,043 cubic yards of clean frozen gravel was used to backfill flare pit excavations and then cover entire footprint of the flare pit. . . Another 2,200 cubic yards of organic overburden (organics with silt) was ES.1 DECLARATION . placed over the gravel to augment site revegetation. Both backfill materials were placed and graded to allow for a final flare pit cap of 0.5- to I-foot above surrounding tundra elevation after thaw and settlement, thus creating positive drainage. Based on the above corrective actions, there is now negligible risk to the human and ecological environments from the flare pit. Recommendation for Closure of the Reserve Pit As directed by the ADEC, XOM backfilled and graded the reserve pit cap to create positive drainage. . About 1,566 cubic yards of clean frozen gravel was used to backfill several large (yet shallow) ponds and connecting polygonal channels. About 500 cubic yards of organic overburden was used to cover the gravel and augment site revegetation. . . Again, backfill was placed and graded to account for settling and to create positive drainage. Based on the above corrective actions, there is now negligible risk to the human and ecological environments from the reserve pit. Recommendation for Closure of the Drill Pad . More than 28 borings were drilled in the pad. More than 86 samples were collected for field screening, and 50 samples also were submitted for offsite analysis. ES-2 . DRO-contaminated soils were found in the pad, but none was above the ADEC approved site cleanup levels. About 315 neat cubic yards of gravel and tundra were excavated during removal of the Pt. Storkersen #1 well head and hauled to Drill Site 4 for disposal by G&I. . . About 15 cubic yards of wood and insuHoam buried in the well cellar also was removed during excavation, transported to and disposed of in the North Slope Borough Service Area 10 Landfill . About 318 cubic yards of gravel was then used to backfill this wellhead excavation . Another 200 cubic yards of overburden was then spread in a thin layer across a large portion of the drill pad where patterned ground is not found due to pad thickness. Based on the above corrective actions, there is now negligible risk to the human and ecological environments from the drill pad. ANC/CTS1 07 . DOC/041 060009 SECTION 1 Introduction This project completion report (PCR) describes a gravel pad, a capped reserve pit, and a partially capped flare pit at the Pt. Storkersen # 1 exploratory drill site on Alaska's North Slope (Figure 1-1), and the cleanup and sampling activities to support their closure. Closure of the site is being managed by ExxonMobil Refining and Supply-Global Remediation on behalf of ExxonMobil Exploration Company (XOM). Corrective action for Pt. Storkersen #1 was established within the approved corrective action plan (CAP) Pt. Storkersen No.1 (API No. 500292001600) Corrective Action Plan (CH2M HILL, 2002), and consists of the following: . First, excavating slightly-contaminated (restricted) gravel to expose underlying wellbore-related drilling wastes in a partially covered flare pit. Once exposed, excavating drilling wastes along with associated ice and soils from the entire flare pit area. Injecting the same into a Class II injection well at Drill Site 4 (DS4)in the Greater Prudhoe Bay Unit (GPBU). Backfilling and grading the entire flare pit footprint with gravel and organic overburden to create positive drainage. Backfilling and grading several large ponds and polygonal channels on the reserve pit cap with gravel and organic overburden to create positive drainage. Re-plugging and abandoning and sealing the Pt. Storkersen #1 well and removing the well marker. Revegetating the flare pit and reserve pit. Revegetating the thicker, non- polygonal portions of the pad. . . . . . . . ANC\CTS1 07 . DOC/041 060009 (' The CAP also allowed for ExxonMobil to reuse the excavated restricted gravel as backfill in the bottom of the flare pit excavations as long as it was capped with at least 1-foot of clean gravel fill. Instead, ExxonMobil opted to also haul and inject this material at DS 4, a much more conservative approach. This PCR completes the requirements of the State of Alaska Solid Waste Regulations, Title 18, Chapter 60.4400) of the Alaska Administrative Code (AAC) with respect to closure of the inactive reserve and flare pits. This PCR also documents the drill pad conditions whereby it can be closed without further segregation, removal and treatment of petroleum- contaminated pad gravel. State, federal, and local agencies involved in this project included the ADEC, ADNR, (Division of Mining, Land and Water; Division of Oil and Gas; Office of Habitat Management and Permitting; Office of History and Archaeology-State Historic Preservation Office), the Alaska Department of Fish and Game, the U.S. Fish and Wildlife Service, the U.S. Army Corps of Engineers, the U.S. Environmental Protection Agency, and the North Slope Borough (NSB). This report is intended to satisfy the reporting requirement for the above agencies and their respective permits / regulations. 1.1 Project Objectives The long-term objective at Pt. Storkersen #1 is threefold: 1.1 INTRODUCTION 1. Obtain closure of the inactive reserve and flare pits and pad, following 18 AAC 60.440 and 18 AAC 75 guidelines. 2. Remove all surface debris. 3. Revegetate the site. The overall program goal is to obtain closure of the Pt. Storkersen #1 exploration site, including the drill pad, inactive reserve pits, and flare pit, and to perform pad revegetation. The corrective actions will help ensure that drilling wastes and contaminated gravel do not come into contact with surface water and/ or erode into the sea. As the source of drilling wastes in the reserve pits and flare pits is drilling activities, closure of the same is being performed in accordance with 18 AAC 60.440. Closure of the drill pad is being performed in accordance with 18 AAC 75. The goal of this PCR is to describe corrective actions that occurred at Pt. Storkersen #1 resulting in proper closure of the site. Therefore, this report contains a summary of excavation and disposal activities of drilling wastes and drilling waste-contaminated pad gravel and results of field screening and laboratory sampling activities used to verify the completion of removal activities necessary to achieve site closure. 1.2 Scope of Work 1.2.1 Cleanup Activities Cleanup activities to permanently close out the reserve pit, flare pit, and drill pad involved the following: . Constructing an ice road to the site. 1.2 . Removing restricted gravel found covering drilling wastes in a portion of the flare pit. . Once entirely exposed, removing drilling wastes from the entire flare pit along with overlying ice and underlying contaminated native soil. . Hauling excavated exempt restricted gravel, ice, drilling wastes and contaminated underlying native soil to the Drill Site 4 (DS4) grind and inject (G&I) facility. . Backfilling the entire flare pit footprint with gravel and organic overburden, taking into account thawing and settlement of frozen backfill material, native frozen soils and ice left in place. . Excavating pad gravel around the well head, sealing the abandoned well and removing the well marker. . Backfilling the well head excavation with gravel and organic overburden while taking into account thawing and settlement of frozen backfill material, native frozen soils and ice left in place. . Backfilling several large ponds and related polygonal channels while taking into account thawing and settlement of frozen backfill material, native frozen soils and ice left in place. . Hauling exempt wood and metal debris collected during excavation activities to the North Slope Borough (NSB) Service Area 10 landfill for disposaL . Grading pits, excavations, and pads to minimize ponding water. . Revegetating the flare pit, reserve pit, and select portions of the pad that has not undergone thermokarst resulting in polygonal-patterned ground. ANC/CTS1 01.DOC/041 060009 (' INTRODUCTION 1.2.2 Screening and Sampling Activities During closure, qualitative and quantitative screening was used to guide removal of drilling wastes. Confirmation sampling in the flare pit and immediate adjacent pad gravel was then used to confirm when drilling wastes had been excavated. Qualitative screening included inspecting each excavation for massive ice, as well as for fuel staining, odor and sheen. Quantitative screening including field laboratory analysis for total petroleum hydrocarbons (TPR) as an indicator of diesel-range organic (DRO) compounds by infrared spectrophotometry (IR). Confirmation samples were collected and submitted for offsite analysis for cleanup criteria parameters that include DRO; polynuclear aromatic hydrocarbons (PARs); and benzene, toluene, ethylbenzene, and xylenes (BTEX). ANC/CTS1 07 .DOC/041 060009 1.3 INTRODUCTION 1.4 ANC/CTS1 07.DOC/041 060009 • N - ~ a, `'E,~t t Egg Island C )~_r- ! h </r n y~ / S < q ^, 'Y O S -~. - StorMrrsen • SEA ~G 4` bb • -•. 'yr . Stump Island s{c,~Stump 2 - \\ ,~ ~. - • • . x`,10 ' ~ i.. er.. -y.- \~ tE~ ~'_ pdntStWI~J~+ ~ ti ' j ~~ ice _.. ~~ '`P,/M .J.y~.- I + '~ ! ?~j!' K-`~ ,'~ ~' • /+, ; _;,t ~ `/ ~~ Point McIntyre 1 ~ ,.~ v ° I ~ ~ '1 1 • r . ~ ti ,, -~ ;: - ~~, rid^~ '~• ~ f '' ~f ~ ~1 Sa ~ - )i !~ - PGnpin~ &ation jj ;,.~•y' ~ ~ i~ .. tR~1 ,,f~ 14 ~. .-ri ~~ r // ~ ~y .fir J i~ ~~w ~~ ~~) P ~J ~3.d i ~ ~. .-~j ~~ 1~~ 0 ~ e_ t~~1 / • ~ ~~ ~w ~~~{ ~ ) ~ r~A) } O~yj,~ ~~~ _ ~s t.'~ ~ k s _ ~~~y;.. ~4.~~~11--.a ~ `:~~ Y- .f;, ° G- Ai _ ~~ ~ 11 {~ 0 .~- fie. ., 14 CI-. S 5 J ` ~ .. 4 ~.'j4~ ~ ~~~! el. ~Jd ,G' • ~~lb4li \ i r~ ~ 1~~~® ~ ~`C. )l 1 pA+~ ~J``..) np°~ ~'- _. h ~ ~ 0 l~ . S u ., . til~ V, (!:_ a t);. fl , `\i~ ~ ~- ~~~~ , IO ( `•,`S -, c.i~~e-'~~~~~.. I~.' fO l Figure 1-1 Point Storkersen No. 1 Location Vicinity Map SECTION 2 ( Project Organization and Responsibilities Fieldwork and cleanup were coordinated and conducted for XOM by Marsh Creek Inc. Alaska Interstate Construction (AIC) Inc. removed contaminated gravel, native soils, and drilling wastes. Exempt drilling wastes and contaminated soils were ground and injected at the Prudhoe Bay DS4 facility. CH2M HILL provided technical and regulatory expertise while focusing on sampling and documenting cleanup activities. Team members and responsibilities are described below in Table 2-1. TABLE 2.1 T earn Members and Responsibilities Team Member XOM Marsh Creek CH2M HILL AIC. Responsibilities XOM was responsible for implementing the project and committing the resources necessary to meet project objectives and requirements. XOM acted as the primary point of contact with regulatory agencies during this project. This involved supervising and coordinating engineers and subcontractors. XOM helped ensure that all technical, financial, and scheduling objectives of the project were achieved successfully. XOM also was the primary point of contact for construction and project-related matters and had overall responsibility for work performed by subcontractors. Marsh Creek supervised field corrective activities. This involved field supervision and coordination of engineers and subcontractors. Marsh Creek helped ensure that all technical, financiaÎ, and scheduling objectives of the project were achieved successfully. Marsh Creek also was the field point of contact for construction and project-related matters and had overall responsibility for work performed by subcontractors. CH2M HILL supervised the collection and analysis of samples outlined in the corrective action plan and provided technical and environmental expertise. CH2M HILL field team leaders helped provide direction to the construction team on whether the pad or pits required additional sampling and provided progress reports to Marsh Creek and XOM. Additionally, CH2M HILL provided a site safety officer for its team. CH2M HILL reviewed closeout data and provided guidance to XOM, Marsh Creek and AIC on the adequacy of data and cleanup efforts. CH2M HILL will submit and pursue approval of the project completion report to help achieve final closure. AIC was responsible for the removal and disposal of contaminated pad gravel, soils and drilling wastes, and related construction work. AIC helped ensure that all technical, financial, and scheduling objectives of the project were achieved successfully. AIC also was the primary point of contact for onsite construction and project-related matters and had overall responsibility for work performed by its subcontractors. AIC also provided a site safety officer. 2.1 Specialized Contractor Services Alaska, provided templates of existing grades across the reserve pit, flare pit, and exploration pad. 2.1.1 Survey Early on in the program, F. Robert Bell and Associates (Bell) of Anchorage, ANC\CTS1 07 . DOC/041 060009 2.1 PROJECT ORGANIZATION AND RESPO~ITIES Bell surveyors staking toe of flare pit. Bell then provided surveying services during corrective action that included: • Staking ice road and snow removal limits • Staking "excavate to" elevations during drilling waste removal • Surveying excavation and backfill limits, and based on the results, calculating neat line volumes of the same. • Estimating materials stockpiled • Helping CH2M HILL develop a cap design and site grading plans • Providing site as-builts after corrective activities were completed. These are incorporated into this report. 2.1.2 Well Abandonment and Well Head Removal Fairweather Exploration and Production Services, Inc. was responsible for abandoning the well per Alaska Oil and Gas Conservation Guidelines (AOGCC). This included cutting casing to remove the well head, coordinating with Halliburton Services to cement all casing annuli back to the surface and having GBR Welding Inc. seal the well by welding a plate on to the top of the conductor casing. 2.1.3 Grinding and Injection Services The G&I system and operations support for disposal of exempt drilling wastes and restricted gravel was provided by BPXA at DS4. 2.1.4 Laboratory Services The Anchorage laboratory of Analytica Alaska Inc. was used for 24-hour rapid turnaround of petroleum hydrocarbon samples. This facilitated rapid decision making in the field. 1.2 ANGCTS107.DOCI041060009 • SECTION 3 Pt. Storkersen #1 Background 3.1 General Background Map location for Pt. Storkersen #1 pad is SW/4, Section 7, Township 12 North, Range 14 East, Umiat Meridian, of the U.S. Geological Survey (USGS), Beechey Pt. (B-3) Quadrangle. Wellhead longitude and latitude coordinates are 148°41'75" west by 70°24'15" north, respectively. 3.1.1 Drilling Operations and Site Construction The Pt. Storkersen #1 drill site (Alaska Division of Lands Lease 34623) is about 1,000 feet south of the coastline of Gwydyr Bay. The site consists of a drill pad, reserve pit, and flare pit that were constructed by Hamilton Brothers Oil Co. of Denver, Colorado during the winter of 1968/1969 by placing sandy gravel fill on tundra. The Pt. Storkersen #1 wildcat well (American Petroleum Institute [API] #500292001600) was then drilled. Discharges to the two pits were different as they occurred during different phases of well operations. The reserve pit was used to contain drilling muds and cuttings discharged during drilling. Eight drillstem tests (DSTs) were performed before and after drilling was completed to test various intervals for oil content and producability. The flare, or burn pit was used to contain fluids produced during these well tests, which were then combusted. Exploration Drill Pad The drill pad was originally constructed as an irregular rectangle about 650 feet long by 350 feet wide in plan, 5 to 10 feet in thickness. Photographs taken during inspections in 1973 and 1974 show that several feet of pad gravel had been removed from most of the pad to backfill the reserve pit. Due to gravel removal that was used to cap the reserve pit and cover a portion of the flare pit, the pad now consists of three terraces, or layers. or n ~ ~w,w rwnu la ~. a.w P.0 .M SAI.bw MMM. Pnlwiwa GYUW) I~~~~~\ I 1 a.•a ~.,,~ ~ ' ~1 1 1 1 1 1~ ~ 1 1 •~~ I 1 ` '\ I 1 >3' Md.. rwr.c. 1 I 1 ~ oln P.E. ~o P.IYmN I I 1 coal • I 1 ~~~ • •" ° , ° ~~ I Flaro Pll 1 ~~, >s~ u~ : 1 ~ Capped) 11 ~•r x.• >3' I I lysnP.a; ! I I Rewrvo Pll ~ '1 ~,5„' 1 I j (CaoPOA) 1 1 I 1 1 ~ua.r__ ______ ! ! n'M° / {~ 1 ~I / ~ 1 '1'~ • w.m gym. ~ ~ or Drill Pad and Pit Configurations ANCICTS107.DOC1041060009 3.1 Pt Storkersen #1 Exploration Site (' SECTION 3 Pt. Storkersen #1 Background 3.1 General Background Map location for Pt. Storkersen #1 pad is SW /4, Section 7, Township 12 North, Range 14 East, Umiat Meridian, of the U.S. Geological Survey (USGS), Beechey Pt. (B-3) Quadrangle. Wellhead longitude and latitude coordinates are 148°41'75" west by 70°24'15" north, respectively. 3.1.1 Drilling Operations and Site Construction The Pt. Storkersen #1 drill site (Alaska Division of Lands Lease 34623) is about 1,000 feet south of the coastline of Gwydyr Bay. The site consists of a drill pad, reserve pit, and flare pit that were constructed by Hamilton Brothers Oil Co. of Denver, Colorado during the winter of 1968/1969 by placing sandy gravel fill on tundra. The Pt. Storkersen #1 wildcat well (American Petroleum Institute [API] #500292001600) was then drilled. Discharges to the two pits were different as they occurred during different phases of well operations. The reserve pit was used to contain drilling muds and ANC\CTS1 07 .DOC/041 060009 cuttings discharged during drilling. Eight drillstem tests (DSTs) were performed before and after drilling was completed to test various intervals for oil content and producability. The flare, or burn pit was used to contain fluids produced during these well tests, which were then combusted. Exploration Drill Pad The drill pad was originally constructed as an irregular rectangle about 650 feet long by 350 feet wide in plan, 5 to 10 feet in thickness. Photographs taken during inspections in 1973 and 1974 show that several feet of pad gravel had been removed from most of the pad to backfill the reserve pit. Due to gravel removal that was used to cap the reserve pit and cover a portion of the flare pit, the pad now consists of three terraces, or layers. } ~g.:OW8fT8t"'" ~ \ \ «3 ft. Glml Pad '« WiIh ThtrmolUlltI l =ç-= \~;.;----,~ L,_,..-.t: t--'" ' \ ~\ I , \ {'-...--, I , >3' '-"ddl. T...... I I , 1"/ ". (>3ft ~';¡It.mod,' : \ r- G<~~~~ , .w...... ~r I Flare Pit' ~ , ... . >5' I (Open) \ " ,.5, .: I I Capped) \ '.U_. I \ ~;>~~~ l' ~I I , '. >5". I : J> Reserve PIt ,. I I I l (Capped) : : T~o;'':'-- - -- - - - : I ,I ...-' " -¡ I >3''''' .,. , ~~~f1'I' ~ ....--' Drill Pad and Pit Configurations 3.1 PT.STORKERSEN#1BACKGROUND • • Inactive Flare Pit The flare pit was constructed along the east edge of the pad by constructing gravel berms. Fluids from DSTs flowed to the pit. Therefore, the flare pit contained residual raw crude as well as crude combustion by-products and residual drilling muds. For clarity, the flare pit is described in this report as an "open flare pit area' and a "capped flare pit area." This is due to a portion of the flare pit (containing well- bore associated fluids) appears to have been covered by a thin layer of gravel in the early 70's. Thus, the western boundary of the flare pit was hard to distinguish. Flare pit drilling wastes were found exposed (in the open flare pit area) and covered in the partially capped flare pit area. Capped Reserve Pit The capped reserve pit is described in detail in the 2002 closure plan. The ADEC directed XOM to backfill depressions and polygonal channel and then grade this cap to achieve closure. Contaminants of Concern Flare Pit. As noted, drilling activities at this site included DSTs flowed to the flare pit, plus the use of diesel-based muds. Therefore, the contaminant types suspected would be diesel, residual raw crude, and residual crude by-products. This means the potential contaminant of concern (COC) for both the gravel covering and flare pit is DRO along with commingled BTEX and PAHs. Again, these well-bore associated contaminated soils are called "drilling wastes" for clarity. Drill Pad. Surface releases related to heavy equipment operations likely occurred and some DRO contamination was found in the pad. The contamination, however, was minimal and did not constitute gross contamination after 30 years. _~ _..-. ~.. , ~' . CH2M HILL sampling flare pit in October 2001. 3.2 Past Site Assessments Activities Five site assessments were completed. Surface water sampling stations, plus pad and tundra boring locations are shown in Figures 3-1 and 3-2, and summarized in Table 3-1. 3--2 ANGCTS107.DOC1041060009 u g ~ 0 ïii ...;, õ: ~ ¡¡: I C' c: '§ CO U Z ;$i 0 g 0 ¡;: 53 ( ...~. Xs.iI' : ",/oi" \ x 5oSO ../ \ )( 5,30 /' . /./ J / ..' ~ IX~ ' ,/ ./ ...---.. ...,-; X 5.30 I i ! \ l "",/" ./ ./.. I !. ................. ,.../ , '. .", , . i ~ I \. . . ( WATER POND) \ I ", \ "', -: ". l \ ;10» \.. .: °.........../ I< 5.80 ! f \ 1 ¡ / ~ '. ~ "' \ " \,.~, .'\ . FNCE POL .- //'\ ; \ \ : ..~>...." ' '1 I !J:'" , , \ '>"..-- /: f ", . . , 'I~. / ,I " ..( ) V '<........ j è,~...,...j 7~ \ . I i'--"-'" ..\ ,-1iOE""::-:::---' "F'OE cø¡. ", .' . ',. \ I ,¡ "'.. -"""" , ' / .89 ,.\ o," ,002 \. . .~ '\. ~\. ., {~. V ) 7.60 x (\\ ,"" >. I \ 7....r. \, '. "'.., \: ' \ WATER EDGE <804 ...' I. \ "", ''":i'.., \\. \ 82 '!'.. ¡. ,,;"'\ \ '. \" . 8 7.70 x \ 84 8 .T2 ~, \ ~ '. \', .', / , '..'" >7JO I <tie ' .... ~ \." . "" / "1 4 I< 7.5Q I " '..".,. ~,,\" " .,...".."'::t!':'. / "~,... ¡ . "" ",IP' "'-"'. " i, ' ",-,", .. . .. '.'LV... ~ \. ~¡Io" CJ15. (' : \~,.."T 85 ~.,. ~,.':'I\ ,-,1 . ".",""./ .. .,.,./1) ...'.'.'. WATER POND / ,--' i:' . ¡ I ~ l~ m4 { / ib [- i ; ; I ¡ , CJ17 ': \ . I , ¡ i ... I j \. ., / '\)1 t \ /'.. .".,. (113 "', "1,,- \ . 86 '\\, ~ \"\ " \'\ \' <lOa J " \ . WATER EDGE '.! .,. 1 Þr~RE:. \ -Y"- 7 \. I (C~¡P. P'~D )..~ . (lorr"'.. <Þ10.. . .60 <: L - ~ - - ~ "./ .30 \ \ 88 ::" \ \...,... .,-), , " \ \ ~;-:.) IU ¡ ...i, ~ SHQIJLDER \ ."=;:,, 8T1 /-'-'~--._._,._.".. '-'- FNCE POL 001 )( 61'0 03(1 1<5."'0 )C 6.20 >(GAO 1<6.60 )(6.90 . FNCE POL x ..30 )(7.00 )C 5.50 x 7.00 <t06 x 5.80 FNCE POL. EW2 '¡" / )(7.00 FLARE PI T (OPEN) <112 <Þ07 x 5.60 )C B.ID X 8.70 ..."""'-) )C 7.80 1/ / ( WATER POND ..' I / , t..,.,/ 8T4 <Þ11 878 50110 I< )( 5.00 )(6.50 /-'.. í ")1<7.10 )(7.50 I< 6.90/ j ~ j \ . °\ í WATER POND '''../' x 7.50 1<7.90 )( 7.60 """--' Ir.ró )(8.30 )(7.50 )( 6.5D )(9.00 HAMILTON POINT STORKERSENNo.1 X 7.10 )(7.30 \ \ \ .\ \ \ "" ( i ." .../ WI <: " 'I.. '..... :6.80 ("- i¡3 ~ \ ... , x 7.60 . FNCE C )(7.50 7.60 x ~~ -~- I tI,ttI,. 8Ar ) I '. '7 ),' ".~ THIS SURVEY ð v" "", ... / '.f~; ';i1-.. CW'~~'~"r.:':~-,;'}ç,"'~ ~,r-' I " .. ß ,." ~ Ç:¡ -Ii. _\'.."" Òìl~,¿' ';. , i.". t2~~ \ . ,~, ' ,.. . n~- \,... i( ~;., .;>;; /~_. . . ( . '. .,-- ,I'¡:::""'~''- .,....,\,. (', t ., \...5 ('c" :y/ JR '\i' . !...II, ...;---,.,."..fl"' ~ . ¡;::,. t" J:: ~à.: . ~Þ(- ~ A:, t \,1 ... -. . ~" . " ,,":( \ ¡,;. .r"'-,."', . , ~\:: . ' " r;r',' ,N',T¡....J/" > '/¡ ." ,,'.: -, ,~:¡~,;,~J, ", ". ;!: .', VICINITY MAP N,T.S. CONTROL REM0201..., REM020147A REM0201!10A REM020160B REM020150C A.S.P. OOORDINA 16 OEODE11C POSl110N (OMS) NORMNG £ASTINC LA 111\.10£ LONGl1UPE 5999864.80 659701.02 70024'20.355" 148"41'59.368" 5998588.31 680085.80 70024'09.8698 148'41'48.77'. 5998924.4!1 880408.03 70"24'12.828- 148'4"38.119- 1511198320.18 860481.52 70'24'06.8698 148"4"37.348" 5998281.28 659789.83 70024'06.736" 148"""'58.219'" COOR'DINA1ES ARE ~ STA'Œ PLANE. ZON£4, NAD27. J..EŒN:) aT! <807 @) 0 X 2001 CH2MHtll BORING PS03-07 2003, ~2MHlLL BORING SURVEY CONTROL POINT WEU.- PIpe; MARKER TUNDRA £l£VA~ON NOTES: 1. BACKGROUND MAPPING IS FROM AEROMAP U.S. PROVIDED 1 : Sooo TOPOGRAPHIC MAPS FROM AERIAL PHOTOGRA~Y. 2. DATES OF SURVEY: APRIL. 2. 20D3. 3. REF. FIElD BOOK: REM03-D1 PG 45 0 I GRAPHIC SCALE 40 80 . 1SD I ( IN FEET ) , Inch - sa ft. Figure 3-1 Flare Pit Boring Locations Point Storkersen #1 Project Completion Report ( I ¡ I I [ I I ( I i3 "'" g 5 I ~ '¡¡j ~ !ê 0 I I 0- .E 0 CXI U Z <I: a 0 I s 0 N U'I ß I ~"\ . ;.'-"¥' \ x !.SO ,! / \x.... ~~ í \ ( ../" \ I I \ \ ~// /) I\ì ../... j~ ~ )1 \ I.: ...... /. . r-- /' "'.'1 ...-..r I~... I ~~ \ ". J"'" )(5.30 i ~ \ . " ~ . (xsa ~"FN1 POL r~ r--.- /. ~/. L .\,...(::-:*7: . x&p . \ I ) V.. \¿ .a.6'lCECOR" J - ; J )(5'''°. .~...O.O..'''' .........~Û'..~.............'~..~.-."".-'..'.V.......... ~. ... - . ... OO~(. .... .... h... / x...... .' .. '1(6,4..° J. ...ccJ\ .'1.'.. ~"'. '~. ..~. . . ."\.' . ;,... "".~... 7.60X .\.\..w A1ER EDGE 1/ x.... ,,"" .J J~r~~.. ~).. ~\ )8 "' "7M) 1,70x \ x'" \ /001 '... ...;' '" X7,5Q t....-... FNCE POLx1.30 . . . ..........., .1 . . V'" \ ~07 ~.\, . ,~~.;:- ') ) r...¥-.! '\ . \. . x ,.. 'ì I'~ ~ -.. le, 0" 0-4./ I ',.. .)(5.50 )(7.00 .....-':!~¡ I r'lf f~ ' .«I~' \. ~ï"/ : '.1E:. )(5.80. (.f. ~ '#').0. 005 .~ l~ I)H I WI<, R POND I.:.FNCEPO..L. ... '. v.. )Jj ..... .l (....... ........ .... ~....... ~~. . .. .... .'... ---;'1' .a.oOi~..'. /.r-'. f. C.~. . WATER POND )(1.00 ' , \ 'vJ "~/ 11 ~'I.. j¡/~~ _lœ ¡. J ~ 1" "-..'\.. \.' r'.'~.,. fÅ1ER;;:..... .~.~?..~.~...-..~.~.......r0. m..r....- .J.,..~...'.....' ,.. '~.J.'..(.\ \.......\. F(~~~~1T \. r \ ^ '\ (... . '^..\ h ¡\r ? /~ ~\ \ \" I \ (\j t .~¡. \~,\,. ... ~~. (I, 10013 .. \\ '\-î '-- ( 0 l'" . \~~Jr~~~l' '~. . .~Ä\ \WAlER EDGE ~ ¡-J ~ R~~ . ~t?~ \ ::~Åcm2~.. f~~~D~"~.. /-...- I.' . .... rJ'f (c ~ l. .)' \ U.. '\..l/. J~ \..'1' L¿D04 '> .~ ,~,...... ,,7'" I.. ..-.j OVERS.. URDEN . .. ~'/) J . ~.... '... \..'~. 8C041 \ j(¡I~..' '7., '\ xW I r rì FA~ ,,~ ~? \t~ \\~~ \ \ x- \,\.{. . I ..~, ~..if\. 'ì "'..~).. . .. n ;,1002{/"'.t....'. 1.1)(. '. ". *~..../ \ \~t\ '" þ:'~;J \ (,/ \l .,. }Y. ~.) \ . FNC2 ~t ) /" ~ \,---""_</-~-~ 1. \ ',.,~j~ \ c Y '\. \ ./ .. \ t",_i"-o.. ;--.I~, \"" ~~ \ ~ í Toe: ( ,<:::,,,~~#,., t " . <, ..'''''''''- . . 'Þ~.. \ i ~. ... ....- '7/ \ \ z r' J"~.) x7.S0 ~' \ \ I ... ,".,.. I.'.'. -'''. . \\... I: ( WATËR POND' l \)(7.10 X7.50 , ~",.~_. )(8. .. If"'" -""'''"'''''' )( 8.70 .? J I ,St) I( 8.&0 t.. ¡ X690/' )( .. ... . .. . )(C).OG .., I . ~. t, HAMILTON POINT STORKERSEN No.1 ~ \. Î WATER POND ' " I "'v' x 6.50 x IUD x 6.5'0 >:7.50 x 7.90 )(7,60 x7JO * 6.80 11(7£10 x 7.30 CONTROL REM020147 REM020147A REM020150A REt.t020150B REM020150C ( awmyt ...r THIS SURVEY A.S.P. COORDINATES GEODETIC POSITION {DMS} NORTHING . EAS11NG . LA TllUDE lONCliUOE 5999664.80 659701.02 70'24'20.355- 14lr4"S9.368" 5998586.3'1 660065.80 7Ö"24'OS.669- 148.41 '48.771" 5998924.47 660408.03 70"24'12.926" 1<48"41'39.119" 5998320.1B 660481.52 70'24;06.969" 148"41'37.346" 5996281.28 659769.83 70"24'06.7jS" 148.41 '58.21 9" ~A1'ES ARE ALASKA STAlE PlANE. ZONE4, NAD27. Núlt:tP 1. eACKGROUNOMAPPINGIS)'ROM AEROMAP U.s. PROVIDED': 6000 1'OPOœAPHJC. MAPS FROM. AERIAl. PHOTOGRAPHY~ 2. DA'I'£S OF' SURVEY: APRIL 10. . 2003. '3.REF.FlELPBOOK:REM03-j01 PG 46 J-EŒND "'00 . C047 @ 0 >< 0 t ,I PS03-D010 DEUNEATlON BORING PS03-C047 2003 CHARACiERIZA1'10N/OEUNEAi10N BORING (Co-LOCATEO,Wl111 CO2 SOIL G~ PROst) SURVEY CONTROL . POINT WELL - PIPE MAAKER TUNDRA ELEVATION GRAPHIC SCALE 40 80 160 1 ( IN Fm ) 1 Inch.. ao ft. Figure 3-2 Drill Pad Boring Locations Point Storkersen #1 Project Completion Report TABLE 3.1 Point Storkersen # 1 Site Assessment Activities Soil Sampling Date Suñace Water No. of No. of Field Sampling Borings Samples Other Capped Reserve Pit Oct. 4 stations None None 2001 March None None None 2003 Cap inspection Site survey Partially Capped Flare Pit Oct. None 13 2001 39 Soil field screening Dec. 2001 Geophysic al survey None None None March None 2003 Site survey 17 70 PT. STORKERSEN #1 BACKGROUND Fieldwork Description CH2M HILL conducted an initial site assessment that included inspecting the pit cap and sampling surface water at four stations around the reserve pit. CH2M HILL subcontracted F. Robert Bell and Associates of Anchorage, Alaska, to establish survey control, measure reserve pit boundaries and topography, and calculate the volume of fill required to regrade the cap to create positive drainage. CH2M HILL drilled and sampled 13 borings in the open flare pit (9 within the pit and 4 tundra borings around the pit). CH2M HILL subcontracted with NORCAL Inc. of Petaluma, California, to conduct a geophysical survey by using vertical magnetic gradient methods to identify metal objects buried in the pits. CH2M HILL returned to the inactive flare pit and drilled 17 more borings within the pit. This fieldwork further characterized pit contaminants and refined the vertical and horizontal extent of contamination. Delineation information was then used to calculate the volume of contaminated material requiring disposal by grinding and injection. F. Robert Bell established survey control, measured flare pit boundaries, and located all borings drilled to further refine excavation and backfill volumes. Exploration Drill Pad Dec. None None None Geophysic NORCAL conducted a vertical magnetic 2001 al survey gradient geophysical survey to identify metal objects buried in the pits. URS conducted a CO2 soil gas survey of the gravel pad to help delineate potential areas of hydrocarbon contamination. A total of 67 survey points were screened with pad pore CO2 soil space gas collected at a depth of 1 .5 feet on gas 50-foot or 25-foot grid spacings. URS also 67 survey focused on inspecting and cataloguing solid Aug. (probe and site waste debris, such as metal, wood, and paper 2002 None points) 67 inspection found strewn across the site. ANC/CTS1 07 .DOC/041 060009 3-1 PT. STORKERSEN #1 BACKGROUND TABLE 3.1 Point Storkersen # 1 Site Assessment Activities Surface Soil Sampling Water No. of No. of Field Date Sampling Borings Samples Other Fieldwork Description CH2M HILL drilled two pad borings. Refusal in both was at shallow depths, and the drilling program was suspended. While onsite. F. Robert Bell established survey control, reestablished select soil gas survey probe locations where characterization borings would March Site be drilled, and established/surveyed proposed 2003 None 2 6 survey delineation boring locations. CH2M HILL returned to the site and conducted a follow-on site assessment of the exploration drill pad. Fieldwork focused on characterizing and delineating contamination in the pad, and establishing the western flare pit boundary. CH2M HILL also reestablished several soil gas survey points and collected samples to help Aug. establish if there is a correlation between soil 2003 None 26 50 None gas and petroleum contamination. 3.3 Onsite Conditions Prior to Corrective Action 3.3.1 Overall Site Conditions 3.3.1.1 Standing Water (Ice) Aerial photographs and past site surveys suggest the site has not been flooded during spring breakup since construction. Inactive Flare Pit. Standing water up to 2 feet deep was found in the open flare pit area, and was connected to ponds surrounding the pit. This was due to thermal degradation and formation of the patterned ground. A fuel sheen occurred on pit water when underlying wastes were stirred. Drill Pad. Standing water was found east, west, and north around the site. It was not observed on the pad. From September through May, the site is generally covered 3..8 by drifting, windblown snow. During spring breakup, most snowmelt water drains directly off the pad instead of draining through the still frozen pad. Any remaining standing water left is then lost through evapotranspiration. Capped Reserve Pit. Up to 50 percent of the reserve pit cap was covered by snowmelt water in shallow polygonal channels and ponds that freeze solid from October through June. 3.3.2 Soils Flare pit. Soils in the inactive flare pit are comprised of two distinct soil profiles or units: petroleum contaminated drilling wastes (Unit 1) and underlying clean native soils (Unit 2). Drill pad. Soils in the drill pad footprint can be linked to three distinct units: restricted use pad gravel containing <2,000 mg/kg DRO found overlying drilling wastes (also called Unit 1); clean pad gravel ANC/CTS1 07 .DOC/041 060009 containing less than 230 mg/kg DRO (Unit 3) and underlying clean Unit 2 native soils. Pad gravel was used to cap the reserve pit more than 30 years ago (CH2M HILL, 2002). Although this gravel was "seasoned" after undergoing several freeze/ thaw cycles before placement, it has settled as thermokarst has occurred, resulting in patterned ground covered by vegetation. As noted, these channels fill with snowmelt during summer. Thermokarst was evident throughout the flare pit, portions of the drill pad and on top of the reserve pit cap. In September 2001, frozen soil was found at depths ranging from 2.2 to 3.5 feet below waste grade in the inactive flare pit. These depths can be considered the top of permafrost beneath the open flare pit, as maximum subgrade thaw occurs during late September in the Arctic 3.4 Environmental Conditions 3.4.1 Reserve Pit Reserve pit environmental conditions were described in detail in the closure plan (CH2M HILL, 2002). Therefore, discussion in this section focuses on the flare pit and the drill pad. 3.4.2 Inactive Flare Pit Sampling results are presented in Tables 2-4 and 2-5 of the 2003 CAP. Soil sampling focused on delineating the extent and characterizing Unit 1 drilling wastes. Therefore, more than 30 borings to depths of up to 6 feet were drilled in and around the open flare pit area during the 2001 and 2003 site assessments. ANC/CTS1 07 .DOC/041 060009 PT.STORKERSEN#1BACKGROUND A total of 64 samples were field screened by IR; 32 of these also were analyzed for DRO. Of the 32 samples that were both field screened and analyzed for DRO, about 95 percent contained less than 1,562 ppm TPH. These same samples also contained less than 2,000 mg/kg DRO. Therefore, a cutoff of 1,562 ppm TPH was used as a rough guide in delineating the extent of contamination. Elevated DRO, BTEX, barium and, in some cases, trace P AH concentrations were found commingled. Therefore, elevated DRO results were used to assess the distribution of drilling wastes in the flare pit. DRO results also were used to measure and track cleanup activities as the target compound. 3.4.3 Drill Pad Sampling results are presented in Table 2-7 of the 2003 CAP. Soil sampling focused on delineating the extent of contaminated gravel. More than 20 borings were drilled in the drill pad and during the 2003 site assessment, to depths of up to 6.5 feet. Elevated DRO concentrations, ethylbenzene, xylenes, and P AHs (albeit at very low levels) also were found commingled. Therefore, elevated DRO results were used to assess the distribution of DRO-contaminated soils in the pad, especially in the impacted areas. It is important to note, however, that while elevated DRO results were encountered, none were above the ADEC-approved cleanup level. 3.5 Cleanup Criteria Well bore-associated Unit 1 drilling wastes were excavated followed by G&I disposal. Therefore, cleanup criteria was set to help guide field efforts in determining when the 3-9 PT.STORKERSEN#1BACKGROUND inactive flare pit drilling wastes had been cleaned up. Specifically, cleanup criteria helped determine when sufficient Unit 1 drilling wastes and associated contaminated gravel had been excavated so that remaining pit and pad soils were below cleanup levels. XOM proposed, and ADEC accepted the following criteria for cleanup of the Unit 1 drilling waste: . DRO-2,000 mg/kg Massive ice-as an indicator of a clean pit bottom (below original native grade) Petroleum Hydrocarbons. Based on these ADEC-approved cleanup criteria, XOM implemented clean up and removal of contaminated Unit 1 drilling wastes that exceed the 2,000 mg/kg DRO cleanup levels. . As noted in previous sections, the extent of contamination in the open flare pit was known and was spatially relocated by survey; therefore, removal of contaminated Unit 1 drilling wastes was carried out to predetermined excavation limits. Massive Ice. Past investigations and corrective actions at other locations have encountered massive ice beneath the wastes in reserve and flare pits, fuel storage pits and pads. Experience has shown that if in situ massive ice is present, then drilling wastes and petroleum-contaminated soils are not. The most common definition of massive ice used in geotechnical engineering is material that contains greater than 50 percent ice (American Society for Testing and Materials [ASTM] D 4083-89). Massive ice at Point Storkersen # 1 will be defined as containing greater than 70 percent ice. 3..10 3.5.1 Extent of Contamination Based on Cleanup Criteria Figure 3-3 shows the extrapolated horizontal and vertical extent of DRO contamination based on the 2,000 mg/kg DRO criterion; the extent of 1,000 mg/kg DRO also is shown for comparison and information. Information shown in Figure 3-3 was based on surveying, sampling and site conditions. Therefore, Figure 3-3 was used to relocate contamination and set excavation limits. Inactive Flare Pit Unit 1 drilling wastes in both open and capped flare pit areas contained raised petroleum concentrations. With few exceptions, wherever elevated DRO was found, elevated BTEX and PAHs (albeit slight) also are found. Therefore, results above the 2,000 mg/kg DRO cleanup level were used to track overall drilling wastes. Based on fieldwork and surveying, contamination greater than 2,000 mg/kg DRO, as shown in Figure 3-3, was found in two distinct areas: a north area and a south area. The vertical and horizontal extent of these areas can be characterized as follows: Vertical Extent Depths explored and sampled extended to 5.6 feet in the flare pit area. All concentrations greater than 2,000 mg/kg of DRO were found from surface to a depth of 4.5 feet. A depth of 4.5 feet can be expressed via topographic survey as an elevation of 3.5 feet above mean sea level (AMSL). Soil in samples collected from below a depth of 4.5 feet (3.5 feet AMSL) did not contain detectable DRO. All concentrations in soil greater than 2,000 mg/kg of DRO in the north area were found as a 2-foot thick layer at survey elevations of 4 to 6 feet AMSL. All concentrations in soil greater than 2,000 ANC/CTS1 01.DOC/041 060009 ( P~STORKERSEN#1BACKGROUND [ r [ [ [ I I I mg/kg of DRO in the south area were found as a 3-foot thick layer at survey elevations of 3.5 to 6.5 feet AMSL. Horizontal Extent The greatest horizontal extent of contamination in the north area is an irregular elliptical shaped area at survey elevations of 4 to 6 feet above mean sea level (AMSL) that is 100 by 72 feet in plan, encompassing 2,356 square feet (ft2). Most of this area is within the open flare pit and the Unit 1 drilling wastes are exposed. The greatest horizontal extent of contamination in the south area is an irregular elliptical shaped area, also found at survey elevations of 4 to 6 feet above mean sea level (AMSL). This south area is larger, and is about 220 by 100 by feet in plan, encompassing 6,333 (ft2). A good portion of this area is covered with gravel and the Unit 1 drilling wastes are not exposed. I I I I I I I I Drill Pad DRO values in pad fill and native soils did not exceed the 2,000 mg/kg criterion for DRO in borings drilled in the pad to depths of up to 4.8 feet (3.5 feet AMSL). ANC/CTS1 07 .DOC/041 060009 3.11 PT. STORKERSEN #1 BACKGROUND 3..12 ANC/CTS1 07 .DOC/041 060009 Pad Gravel (Over 9 ft AMSL) .. v M sy ;.+ ~. w .per 1 M M P903 1A ~ w ~ ~ 1 ~ ~ ~ M ~...,'~ ~ Open Pj ~ F ~ ~ .. ' A~ A +i ~ Open and Partially Capped Flare Pit (6 to 4 ft AMSL) .. w Pad Gravel (9 to 7 ft AMSL} .~ .. v .w` ~ w r ~. P503D0-,APSO~3oba r N `• T 1 ~ ...y ~`-~ V r 1. rJ1~IW,nV'Vr ~ ~ ~ M -'---P303D0~12 ; ~ M pin ~1 11 M N Y 1 N T~° ~ wiq r 50 Capped ti VAS Open and Partially Capped Flare Pit (4 to 2.5 ft AMSL) f a~ ~3~o-sY"' L1-;~ .~ - T~S0306 PSi314 +'Open 3pp.~S03ll~ pS03~12 ~r ~~03 t 3 ~ +' ''~~PSO3o°e X14 ~~~ Capped PS X10 .~ am1°'" goo, ` w...... '~ ~° .~ .. ~~ ~ ~~ m Open and Partially Capped Flare Pit (7 to 6 ft AMSL) .,, .. ~ ~' t ~i ~ P6 `!+ 1U wBJ M ~ « \M ~3 M.e CBpPed r10' He~i`~ ~~ .., ~ .~~ a°P .. r°' ,~ F~ Open and Partially Capped Flare Pit (2.5 to 1 ft AMSL) .,, M •. PSD~Dt~ an ~p ~ ,m, « Pso3Db~e 50318 .. *" 53 • PS0+305 "~ P8p3D 1ff ~~ ~, ,!~ P50314~{~ Ft 'P~ ~~p313 {~ T 1 11... n ~~~ ~V ~ M A Capped P50308 n 1 ~ .w~ ~ ~ :~.... .~ .~ ~° ~ bw If zo~~o ~~~ Impacted Area 1000 uD DRO in Soil (mglkg) Figure 33 Estimated Extent of DRO Contamination Point Storkersen #1 Project Completion Report • SECTION 4 Summary of Closeout Activities • Section 4 summarizes the closeout activities performed during this past winter's corrective action at the Pt. Storkersen #1 site. 4.1 Ice Road Construction and Use 3 i aa}} ~ ~ t ~ S~ { t <,_ ., D4C Cat bulldozer and Volvo 6•axle water tanker constructing ice road A 4.6-mile ice road to Point Storkersen #1 was pioneered by AIC beginning on March 10, 2004, and completed by March 14, 2004. The ice road started at the Point McIntyre #2 drill site and traveled west on grounded sea ice, following the coast of the Beaufort Sea (Figure 4-1), until it passed BPXA's North Star Unit pipeline where it turned on to the tundra to the project site. Vehicles that maintained the ice road included: • Volvo six-axle water tankers • D4C Cat bulldozer • Cat 14G motor grader • Cat 966 front end loader Hauling gravel on ice road (looking east towards Pt. McIntyre #2) Vehicles that used the ice road during remedial activities included: • Cat 966 front end loader • Volvo R150C front-end loader • Kenworth tractors with 30-cubic yards MaxiHaul end dumps • Tractor with lowboy trailer (hauling a 320C Cat trackhoe and other equipment) • Mechanic's truck • Lube truck • Fuel truck • Various pickups ANCICTS107.DOCI041060009 4.1 ^ • • ~. . , ~ ~ ~ :; is t ,~~,- r ~ P~ Z.r: r-r r~ ~ ~~ f . ~ ~ , -~~ t .~- 3~ ~ ~, ~ • ~~ 1 ~~ 0 -N- I ~ r 1 f" f E' ` ~ },+ t. , ' I ~ ` ~ r a,' '~,~ 'y . E - ~ f: ~ Ice Road from Pt. Maclntyre 11 on West Dock to Pt. Storkersen #7. 4.1.1 Water Usage The source of the fresh water used to construct the ice road was the Kuparuk River Dead Arm Reservoir. This reservoir was permitted under ADNR Temporary Water Use Permit A2001-108#5 (Dead Arm Pit). Total volume withdrawn from the reservoir and daily water appropriations are presented in Table 4-1. Sampling results from discharge monitoring are included in Appendix B Laboratory Data Reports." XOM turned over control of the road to ConocoPhillips Alaska Inc. and the United States Navy's contractor, TetraTech Inc., after remedial activities at Pt. Storkersen #1 were completed on March 30, 2004. TABLE 41 Documented Water Usage Water Volume (gallons) 12-March-04 95,760 13-March-04 102,480 The Kuparuk River Dead Arm Reservoir is a rehabilitated mine site. It is now considered a reservoir, and not subject to the general nationwide NDPES permit. Nonetheless, XOM has opted to fill out a discharge report for consistency. This report also is included in Appendix B. ~• `_ ~-_ ~,- 14-March-04 114,240 15-March-04 57,120 16-March-04 16,800 Total water 386,400 ANCICTS101.DOCI041060009 4-2 • SUMMARY OF CLOSEOUT ACTNITIES 4.2 Pad and Pit Snow Removal _~ ~ ;~, Snow removal was an ongoing task beginning with removal to expose the gravel pad, flare pit and reserve pit on March 11, 2004. Snow from this major effort was stockpiled on the pad and screened for sheen. None was found. Drifting snow from several "blows" also was removed as needed from the site, especially in the flare pit area. Fortunately, this occurred after Unit 1 drilling wastes had been excavated; thus the snow did not come into contact with drilling wastes and did not have to be hauled offsite for disposal. This snow also was stockpiled on the pad and screened for sheen. Again none was found. 4.3 Well Abandonment On March 14, 2004, AIC used a 320 C Caterpillar trackhoe to excavate and stockpile about 315 neat cubic yards of material to expose the well head marker and conductor casing. About 15 cubic yards of wood and insulfoam also was mixed in the excavated material. The wood and insulfoam came from the well cellar. Most of the wood and insulfoam was removed by hand. Fairweather began well abandonment on March 16 and completed it on March 18, 2004. Abandonment included excavating around the well head, cementing inner and outer casing annuli, and finally sealing the well by welding a cap on to the conductor casing. XOM has separately filed a sundry notice for well abandonment with the Alaska Oil and Gas Conservation Commission (AOGCC). ,~ ... - ~,^.._ - ~.~,, ~~ a ~ .,, r T;i S _ 4.4 Excavation Activities Plan and profiles of the site after excavation and then again after backfilling and grading are presented in Figure 4-1. Excavation volumes are presented as "neat" volumes when describing excavation activities. Neat line volumes are based on surveyed in-place materials and do not take account into "fluff" that occurs when the material is excavated and handled. 4.4.1 Exempt Restricted Gravel and Unit 1 Drilling Wastes Excavation of Unit 1 exempt restricted gravel and drilling wastes began on March 16, 2004 and was completed by end of nightshift on March 21, 2004. Equipment used to accomplish this task included a trimmer mounted on a 966 Caterpillar front-end loader, and a Volvo R150C front-end loader. The trimmer removed about 6 inches of frozen material during each pass. The loader then removed and loaded the cuttings on to Maxi-Hauls. ANCICTS107.DOCI041060009 43 Pt. Storkersen #1 prior to cutting, cementing and cap welding SUMMARY OF CLOSEOUT ACTIVITIES • About 15 cubic yards of metal debris also was removed during excavation of drilling wastes by a 320C trackhoe. Based on the presence of drilling wastes beneath clean pad gravel in the partially capped flare pit, excavation of drilling wastes was completed in 5 steps. Each step targeted a specific area with contamination found to predetermined elevations. Step 1 focused on clean pad gravel overlying drilling wastes in the eastern, covered portion of the flare pit (Plate 3-1). Steps 2 through 5 focused (Plate 3-1) on excavating drilling wastes exposed in the partially covered flare pit during Step 1, and in the open flare pit area. Step 1 (Restricted) Pad Gravel Removal About 403 cubic yards of pad gravel covering the flare pit was removed to elevations ranging from 5.5 to 6.5 above mean sea level and temporarily stockpiled within the pit (Plate 3-1). This gravel was considered "restricted;' it contained petroleum hydrocarbon contamination, but at concentrations less than the ADEC- approved cleanup level of 2,000 mg/kg DRO. It is exempt because the source of its contamination was the Unit 1 drilling wastes it was used to cover. Removing this exempt restricted gravel then exposed underlying Unit 1 drilling wastes, thus allowing for their excavation (Steps 2 through 5). After removal, the Step 1 excavation area was screened for drilling wastes, and confirmation samples were collected. Steps 2 through 5: Excavation of Unit 1a Drilling Wastes in Flare Pit During excavation of drilling wastes, a total neat line volume of 1,370 cubic yards of drilling wastes and 600 cubic yards of ice were removed once the entire flare pit was exposed. This also was temporarily stockpiled within the flare pit. Excavation of ice and underlying Unit 1 drilling wastes was accomplished in four concurrent steps (Plate 3-2). Step 2 Area. After pad gravel was removed, Unit 1 drilling wastes in the Step 2 area were removed to a predetermined elevation of 4.0 feet AMSL by trimmer and loader. Step 3 Area. Excavation of Unit 1 drilling wastes by trimmer continued in the Step 3 area to an elevation of 5.5 feet AMSL south of the Step 2 area. Step 4 Area. The Step 4 area was within the Step 3 area. Unit 1 drilling wastes were removed until clean native soils were encountered at a lower, final elevation of 4.5 feet AMSL. Step 5 Area. The Step 5 area also was within the Step 3 area; Unit 1 drilling wastes were removed to a final elevation of 3 .5 feet AMSL until clean native soils were found. After completion, each excavation area also was field screened and confirmation samples were collected. 4-•4 ANCICTS107.DOC1041060009 Trimmer excavating Step 3 excavation area. Step 2 excavation area in foreground. ~ r ~ OVERALL SITE MAP NOTE: ELEVATIONS SHOWN IN THIS VIEW ARE ORIGINAL GROUND. ~j~-~ ~ AP+~ SCALE~~.~, f O ~o ~ Sao ,~ ~ . _- -; 1 , In~ ~. I ~~ _~ - s t , ,. ~ - " t ~ F I ~ r r 1 ~ ~ ~; - (, ~+, ~` V ~~ F'I - ,~~ ~ ~~ PIT • I - • ~ • ~~' •, ~ ~ I ~- ~ l ~ ~ ~ .~ C ~,I ~ ~ ~~ WELL PAQ ~ ~ ~ ~~ ' ~ ~~• r i ~~ ~ ~~ ~ ~ 11 ~ ~13 F I I' ~ Iv I 1WZ 1 - ' ~' ~ \ ~ ~ , ~~ - / ~:~ .mil ~ ~ ! ;itT, !f r' '} S .. ~~ -- ~ ~ ~ ' ~~i \~ . t R .~ . cRAFI uc scA~E FLARE PIT SITE DETAIL 0 50 100 15D NOTE: ELEVATIONS SHOWN IN THIS VIEW ARE FINAL GRADE. ~ 4~ ( IN FEET) -R E ~D ' 1 inch = 50 ft. GRID ~ D ~/_- F ~_~` o~ 3+00 ~ c 2+~ ~ ~ ~ ~ a ~ ~ ~#0 ~ --- - -= ~ -- --as a5. `' + ~ i. -- w ~~' ~ ". 9,0 ~ ~ ~ ~ m __ N~ ' ~ ° m 3+ 0 ,~B~" ~o U. 2 IA 1+00 ~ ~ _ _ B 0+ ~ } ~-_ 0 A >9 ~~ ~ a~ :, o I-9.0 °+~ 9.0 ~ Q oF__-: / of oD -~ ' NOTES CONTROL A.S.P. COORDINATES GEODETIC POSITION DMS NORTHING FASTING LATITUDE LONGITUDE REM02D147 5999664.80 659701.02 7D'24'20.355" 148'41'59.368" REM020147A 5998586.31 660085.80 7D'24'09.669" 148'41'48.771" REMD2D150A 5998924.47 660408.03 7D'24'12.926" 148'41'39.119" REMD2D150B 5998320.18 660481.52 7D'24'06.969" 148'41'37.346" REMD2D150C 5998281.28 fi59769.83 70'24'06.736" 148'41'58.219" 1. BACKGROUND MAPPING IS FROM AEROMAP U. S. PRONDED 1:6000 TOPOGRAPHIC MAPS FROM AERIAL PHOTOGRAPHY. 2 DATES OF SURVEY: 20D2 THROUGH 2004 3. REF. FIELD BOOKS: REM 02-01, REM 03-01, AND REM 04-01, REM 04-02. __ 4. TOP OF WELL CASING CUT OFF ELEVATION IS 2.4' (MSL). COORDINATES ARE ALASKA SLATE PLANE, ZONE4, NAD27. FINAL CAPPED GRADE HORIZSCALE.1'=60' VERTSCAIE:1°=6 A DATUM ELEV z. 0 B DATUM ELEV z. o 4 ~ STUMP ISLAND 1 GWYDYR BAY PORASTOflI~RSEN , SURVEYAREA ,D 8 d ~~~ 6 a 4 0+50 1+00 1+50 2+00 2+50 3+00 3+50 4+00 9J)~ f 8 6 4 0+50 1+00 1+50 2+00 2+50 3+00 3+50 VICINI ~~Y MAP N.T.S. 8 6 C q DATUM ELEV z.0 0+50 1+00 1+50 2+00 2+50 3+00 3+50 FNLLL cAPPEDraADf ORM,INAL GROUND e ___ e SUMMARY 0~ AREA VOLUMES _ ~ EXCAVATION VOLUMES IN CUBIC YARDS D 8 _ FXCAVAIEDAREA B q 4 DATUM ELEV z. D 0+50 1+00 1+50 2+00 FMALCAPPFO gi40E -ORIGINAL GAO CORRECTIVE ACTION PLAN ESTIMATE NEAT VOLUME ESTIMATE (SURVEYED AFTER WORK WAS COMPLETED) LOOSE VOLUME ESTIMATE (BASED ON LOAD COUNTS) FLARE PIT AREA 2,193 2,373 4,170 RESERVE PIT AREA NONE NONE NONE WELL CELLAR NONE 315 540 TOTAL z,1ss z,eea 4,no 9 9 BACKFILL VOLUMES IN CUBIC YARDS E 6 6 q IXCAVAIEDAREA q DATUM ELEV - - - 2.0 0+50 1+00 1+50 2+00 FixucAPPfscRaof CORRECTIVE ACTION PLAN ESTIMATE NEAT VOLUME ESTIMATE (SURVEYED AFTER WORK WAS COMPLETED) LOOSE VOLUME ESTIMATE (BASED ON LOAD COUNTS) FLARE PIT AREA 4,051 4,043 NOT MEASURED BY AREA RESERVE PIT AREA 400 1,566 NOT MEASURED BY AREA WELL CELLAR NONE 378 NOT MEASURED BY AREA OVERDURDENI 4,42D 2,900 NOT MEASURED BY AREA TOTAL 7,871 8,827 10,548 - B _ RIGINALGROUND b IAN OVERBURDEN CAP c)F APPROXIMATELY 6" WAS PLACED OVER SITE TO F - I ALLOW FOR SETTLEMENT OF MATERIAL AND TO RETAIN POSITIVE DRAINAGE S IXCAVAIEDAREA 6 FLOW. 4 4 DATUM ELEV 2THE VOLUMES COMPUTED ARE BASED ON SURVEYS PERFORMED BY F.R. BELL & ASSOCIATES BETWEEN 2002 & 2004. z.0 0+50 1+00 1+50 F. Robert DRAWN' 3;.. CHECKED: TH ~~~~~~~~ LO'H 0 O DATE: 4/29/04 • DRAw1NC: ~~ FR804 PTS 02-00 sREEr: ~LJ~~~~o aoeNO: 20P01NTTSTORKERISENON BxaxBBBS wo two suevBVOxs SCAtE ~ OF SOS 04 ISSUE FOR INFORMATION TH LON mi MESr tiR<nBBO unB E CiU RE 4-~ DATE RENSION av cHe wcxwecB. aesKe B950] AS SHOWN I ~ • ~ SUMMARY OF CLOSEOUT ACTIVITIES 4.5 Field Screening and Sampling After the excavation limits in each step area was reached, field screening and confirmation laboratory sampling were conducted following the ADEC-approved CAP guideline. 4.5.1 Sample Types Sample type, location, and rationale for both field screening and confirmation sampling are described below and summarized in Table 4-1. Field screening incorporated both qualitative and quantitative screening procedures. Qualitative Screening Qualitative screening focused on inspecting the entire bottom and sidewall of each excavation for massive ice, petroleum stains and odors. Sheen tests also were conducted on thawed material. A pre-requisite of 18 AAC 75 is that soil hydraulically connected to surrounding surface waters must meet ambient water quality standards, including no petroleum hydrocarbon sheen on water. Therefore, an important, yet qualitative, screening parameter was inspecting for the presence of hydrocarbon sheen. -r . ~' ANCICTS 107. DOCI041060009 Quantitative Screening ~,. Quantitative field screening for TPH by IR focused on sampling subareas within each excavation that were originally covered by Unit 1 restricted gravel. The IR results provided a quick, rough field estimate of DRO that were used to guide the field effort. Based on TPH screening results, confirmation field samples were collected from each subarea, and submitted for offsite analysis of diesel range organics (DRO). Several samples with the greatest TPH concentrations also were submitted for analysis of BTEX and PAHs. 4.7 Screening for TPH in the field lab by IR Screening and confirmation sampling in the Step 2 subarea (originally covered by exempt restricted gravel) SUMMARY OF CLOSEOUT ACTIVITIES TABLE 4-2 Field Screening and Confirmation Sampling-Number of Samples Field Screening Odor/Stain/Sheen/ Massive Ice TPH by IR (for DRO) 'DRO (AK 102) BTEX (EPA 8021) PAHs (EPA 8270) Confirmation Sampling Step 1 Area: Remove exempt, restricted gravel overlying Unit 1 drilling wastes to elevations from 5.5 to 6.5 ft. AMSL 15 8 3 Strategy: Conduct qualitative screening (odorlstain/sheen/massive ice) during and after removing up to 3 feet of exempt restricted gravel to known "excavate to" elevations of 5.5 and 6.5 feet AMSL. Conduct TPH field screening (quantitative) after excavation grade elevation of 5.5 to 6.5 feet AMSL is reached. Rationale: Screening will help guide removal effort by providing information on what should be expected in the next 1-foot lift. Confirmation sampling prior to reuse will characterize and determine if exempt, restricted gravel stockpile can be reused as clean fill. 10 9 Step 2 Excavation Area Remove now exposed Unit 1 drilling wastes to an elevation of 4.0 ft. AMSL I 3 10 9 Step 3 Excavation Area (South of Step 2): Remove Unit 1 drilling wastes to an elevation of 5.5 ft. AMSL I 3 12 8 Step 4 Excavation Area (within Step 3 excavation): Remove Unit 1 drilling wastes to an elevation of 4.5 ft. AMSL I 2 10 9 Step 5 Excavation Area (within Step 3 excavation): Remove Unit 1 drilling wastes to an elevation of 3.5 ft. AMSL I 3 Strategy: Begin qualitative and quantitative screening after excavation to known "excavate to" elevations. Rationale: Screening will help guide removal effort by evaluating if excavation bottom grade and sidewalls are below site cleanup levels. Confirmation sampling will confirm screening results and verify excavation grades and sidewalls are below site cleanup levels. 4.6 Transport and Disposal Volumes presented in this section and on Figure 4-1 are described in terms of "neat" and "loose" volumes. Loose volumes take into account fluff created during trimming and stockpiling and are based on truck counts. A comparison of neat line to loose suggests an increase of 15 to 25 percent in overall volume after handling. Neat volumes were based on surveys after excavating was completed and then again after backfilling was completed. Material removed, handled, manifested and hauled include the following: 4.8 . About 15 cubic yards of metal debris hauled to the Service Area 10 landfill. Metal debris included drill bits, drill pipe, and drill cable, pipe protectors, and crushed RCRA-empty drums. About 10 cubic yards of wood and 5 cubic yards of insulioam removed from the well head excavation stockpile. . . About 600 neat cubic yards of ice overlying Unit 1 drilling wastes in the open flare pit area A neat volume of about 1,370 cubic yards of Unit 1 drilling wastes from the flare pit. These were composed of the . ANC\CTS1 07 .DOC/041 060009 • trace crude oil in organic- and ice-rich silts sands, gravel. • Another 315 neat cubic yards of similar material excavated from around the well head during abandonment. About 403 neat cubic yards of exempt, restricted gravel. XOM opted to haul and G&I the exempt restricted gravel that had been excavated during Step 1. Disposal by G&I is much more conservative then what was approved. Hauling of stockpiled Unit 1 drilling wastes and associated ice started on March 18, and was completed during nightshift on March 27, 2004. Unit 1 drilling wastes and restricted gravel were hauled in 30- cubic yard Maxi-Haul end dumps to the G&I facility for disposal. Each Maxi-Haul was loaded with 27 to 28 cubic yards of material to avoid material loss from rough roads and high winds. Each load also was accompanied by a North Slope Manifest for disposal at the Drill Site 4 G&I facility. Loading Unit 1 drilling wastes for hauling to Drill Site 4 G&I facility, Loads hauled to Drill Site 4 are summarized by North Slope Manifest number, driver, volume, tower and date in Appendix A. AIC estimates the hauled ANCICTS 107.DOC1041060009 • SUMMARY OF CLOSEOUT ACTNITIES volume to Drill Site 4 to be 4,7101oose cubic yards. ^ Unit 1 drilling wastes stockpiled prior to hauling On March 28, 2004, 30-cubic yards of wood, insulfoam and metal debris removed from the flare pit and wellhead excavations were hauled in a single Maxi- Haul load to Service Area 101andfi1l. This load was tracked by dump ticket (Appendix A). Metal debris 4.7 Backfilling and Grading After excavating and hauling, gravel backfill was placed as cap material over the entire footprint of the reserve pit and flare pit, and well head excavation. The gravel was then covered with a thin (0.3- 4.9 SUMMARY OF CLOSEOUT ACTNITIES• foot) lift of organic overburden. Most of the middle and upper drill pad terraces also were covered with about 0.3 feet of organic overburden. Backfill was placed to final design grade in the excavation areas, flare pit and reserve pit after F. Robert Bell and Associates and CH2M HILL developed a site grading plan. This was done by surveying existing ponds, polygonal channel and final excavation limits, and then placing sufficient fill to account for a thaw settlement factor of 25 percent for frozen soils. The majority of backfill was gravel (5,927 neat cubic yards). Gravel was used to backfill excavations and cap ice left in place to achieve positive drainage to the surrounding tundra. Gravel was hauled to the site by MaxiHaul end dumps for placement and blading in 1-foot lifts by a D4C Caterpillar bulldozer. The source of the clean, frozen gravel was the Put 23 mine site. The organic overburden (about 2,900 neat cubic yards) was placed as cover over the gravel to augment revegetation. Organic overburden was placed over gravel backfill covering the footprint of the reserve pit and flare pit ,and also placed over most of the drill pad in a 0.3-foot lift. The source of the organic-rich silt and peat (overburden) was a pile at the old ARCO Alaska airstrip south of Prudhoe Bay Operations Center. 4.7.1 Drill Pad and Well Head On March 23, 2004 ,the well head excavation was backfilled with about 318 cubic yards of neat, clean gravel from the Put 23 mine site. On March 28, 2004, gravel and organic overburden were mounded up to 2 feet over the excavation to account for backfill • that will be impacted by thawing and settling. Finally, on March 29, 2004, 200 cubic yards of organic overburden was placed on the remaining middle and upper terraces of the drill pad, covering it with a 0.3-foot lift to help augment revegetation. It is important to note that this overburden cover was limited to the existing pad, and did not include any material discharged on to the surrounding tundra. 4.7.2 Reserve Pit Cap Final plan and profile as-builts for the reserve pit are presented in Plate 3-2, along with an estimated final grade after thawing and settlement. The expected end result will be a cap with very limited small ponds and positive drainage. The ADEC directed XOM to regrade the reserve pit cap to achieve closure, especially focusing on backfilling depressions and connecting polygonal channels. On March 18, 2004, about 1,566 cubic yards of clean frozen gravel was used to backfill topographical low spots that had formed on top of the cap. Based on the grading plan, fill over these polygonal channels and depressive 4--10 ANCICTS107.DOC1041060009 Placing 0.3-foot lift of organic overburden on drill pad. • was mounded to account for ice and soil thawing and settling. • On March 28, 2004, another 380 cubic yards of organic overburden fill was placed in a 0.3-foot lift cover over the gravel. Finally, on March 29, 2004, a 0.3-foot lift (1201oose cubic yards) was placed over the remainder of the reserve pit cap. It is important to note that this cap was limited to the footprint, and did not include any material discharged on to the surrounding tundra. 4.7.3 Flare Pit Cap Bell and CH2M HILL developed a site grading plan for the flare pit that accounted for several deep excavations, native tundra, and ice ranging up to 2.5 feet with respect to thawing and settling. • By March 28, 2004, about 4,043 cubic yards of frozen gravel was used to backfill the entire flare pit footprint, taking into account tundra and ice left in place as well as several excavations. • On March 28, 2004, about 2,200 cubic yards of organic overburden was placed over the entire flare foot print. A final as-built for the flare pit is presented in Figure 4-1, along with an estimated final grade after thawing and settlement. Final grade in the middle flare pit crown will be about 0.5- to-1.1 feet above surrounding tundra after settlement to provide positive drainage. SUMMARY OF CLOSEOUT ACTNITIES ~; , . + _ 4. w. t. Initial lift of clean frozen backfill being placed in flare pit As shown in Figure 4-1, about 1.1 acre of the flare pit area was capped and covered, with material placed within the original, fenced flare pit area. 4.8 Winter Cleanup and Site Inspection and Polar Bear Monitoring After blading the organic overburden lift flat across the drill pad on March 29, 2004, AIC completed a winter cleanup of the site. This included: Locating and removing trace gravel spilled on the ice road, and placing it on the pad. • Removing survey stakes and exposed surface debris. On March 30, 2004, CH2M HILL inspected the surface of the ice road and staging pad for drips and tundra damage. No drips were found and no incidents of damage to the tundra or existing vegetation cover were found. Throughout all site activities, Marsh Creek also provided a bear guard from Kaktovik. No polar bears were sighted by any project personnel. ANCICTS107.DOCI041060009 4.~ ~ SUMMARY OF CLOSEOUT ACTIVITIES 4.9 Summer Cleanup and Revegetation During summer 2004, an AIC crew returned to the site for a summer II stick pick" and completed the revegetation program. 4..12 ANC/CTS1 01.DOC/041 060009 SECTION 5 Conditions after Closeout Activities Section 5 will discuss the conditions of the ~~ ~' ' ~ ~~'' ~ ~ ~ ~~~~'~~~"~~ ~ ~~ ~4,.. ~ ~ ~ Pt. Storkersen #1 project site at the ~ ~~ f~. ~,F:=~>, . °• ~;:,r completion of closeout activities, including screening and sampling results and physical conditions. 5.1 Screening and Sampling Results for Excavation Areas The results of laboratory samples submitted for analysis during this project have been reviewed for quality assurance and quality control criteria. The data have been deemed acceptable for the purposes of this report. A memorandum summarizing this data validation is provided in Appendix C. 5.1.1 Step 1 Area: Excavation of Overlying Gravel to Elevations Ranging from 6.5 to 5.5 ft. Qualitative results for the Step 1 excavation area are presented in Figure 5-1. No petroleum stains or sheen were found; there was a slight petroleum odor noted in the exempt restricted gravel stockpile. Massive ice was found in several locations. Quantitative screening results and confirmation sampling results from the Step 1 subarea are summarized in Table 5-1 as shown on Figure 5-1. In most portions of the Step 1 subarea, where excavating was completed at an elevation of 5.5 AMSL, all samples had TPH and DRO concentrations well below the established site closeout levels. ANCICTS107. DOCI041060009 Step 1 excavation underway on March 17~h. In the only portion of the subarea where exempt restricted gravel was removed to an elevation of 6.5 AMSL (to expose underlying drilling wastes ), remaining soil was above the site cleanup level, as expected. This material was subsequently removed during Step 3 and is described as such. 5.1.2 Step 2 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 4.0 ft. AMSL Qualitative results for the Step 2 excavation area are presented in Figure 5-2. Quantitative field screening results and confirmation sampling results from the Step 2 subarea area are summarized in Table 5-2 as shown on Figure 5-2. No stains or sheen were found in the Step 2 excavation area; no petroleum odors were noted. Massive ice was found in the southeast excavation area. 5.1 CONDITIONS AFTER CLOSEOUT ACT After excavating, field screening results for TPH in the Step 2 subarea (Figure 5-2), were less than 718 mg/kg, and laboratory results for DRO were 74 mg/kg or less. Trace TEX compounds were found, but PAHs were not detected (ND) above their respective method detection levels. Thus, remaining native tundra soils are well below established site cleanup criteria. 5.1.3 Step 3 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 5.5 ft. AMSL Qualitative results for the Step 3 excavation area are presented in Figure 5-3. Quantitative field screening results and confirmation sampling results from the subarea within Step 3 are summarized in Table 5-3 as shown on Figure 5-3. The Step 3 area was by far the largest area excavated. No stains or sheen were found and no petroleum odors were noted. After excavating, field screening results for TPH in the Step 3 subarea (Figure 5-3), were less than 536 mg/kg, and laboratory results for DRO were 130 mg/kg or less. Trace TEX were found as well as PAHs as represented by naphthalene. i•' ',a c' i"' • Thus, remaining native tundra soils are well below established site cleanup criteria. 5.1.4 Step 4 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 4.5 ft. AMSL Qualitative results for the Step 4 excavation area are presented in Figure 5-4. Quantitative field screening results and confirmation sampling results from the subarea within Step 4 are summarized in Table 5-4 as shown on Figure 5-4. _:~,. r' _` ,~• _ , . t,' - ,;. . ~ • :~ Y . , #~ t y ~~' ~ __ Massive ice in Step 4 excavation bottom No stains or sheen were found and no petroleum odors were noted in the Step 4 area. Massive ice was found throughout the excavation bottom. Also after excavating, field screening results for TPH in the Step 4 subarea (Figure 5-4), were less than 536 mg/ kg, and laboratory results for DRO were 130 mg/kg or less. Trace TEX were found as well as PAHs as represented by naphthalene. Thus, remaining native tundra soils are well below established site cleanup criteria. 5.2 ANCICTS107.DOC1041060009 Screening and sampling in Step 3 excavation subarea. • Table 5.1 Flare Pit Fieltl Screening and Confirmation Sampling Results for Step 1 Area: Excavation of Clean Pad Gravel to Elevations Ranging from 6.5 to 5.5 ff. AMSL i2~ ~ -- I- ~ i I T I I I I I ~ I I I I I I I I I I 5996610.000 I I I I I I ~ I I I ~ I I I I I R:I;iFPt, I ~ ----- I I----- -----I I I ini aV,'p, i, ; "~. ~ I i I ~ I I i I 5998600.000 I I - _ _ _ r - --,-----,-~ -- $T~P 1 ------ (Excajrate to '. F ~. s996s9o.oao t 5.S fC AMSL) BPS-GP-06 I I I ~ s99esbo.ooo _ _.___i _____I______-- I I I I I I I I I I 5996570.000 ---L-----'-------- I I I ._ -.__ _.. T I I I ~ I ~ I 5998560.000 1 I I I I I `I I ~ PS-GP-03 " I ~ I 5998550.000 ~ - -I-------- --- E 5998540.000 ` I ----- -------- I ~ ` i I 5998530.000 I 5998520 000 I ~ S-GP-04 ~ i ~ . 9 _ --- ~ PS-GP-OS 5998510.000 ~ S-GP-05 `~--- i ; - Vii" . , 5998500.000 °o, °o ° ° °o °o 0 0, o d d d d m r 0 0 ~ 0 0 o a' o ~ ~ ~ d ~ ~ 0 B Sampling Location N O Photo Location and Direction a 00 z a °o a 0 1s 0 30 GRAPHIC SCALE 1"=60' O.s' CONTOUR IM ERVAL Detected Confirmation Sampling Results: (mglkg) Volatile Organic Coumpounds Field Screening Results m location Stainl ~ d North East Elevation Soil Shoanl TPH o ~ = 3 d = Sample (ASPC) (ASPC) AMSL Type Pet.Odor (ppm) o m w ~ x a PSGP03 5998521 660254 6.5 (during excavation, GP No,'NolSlight 1,215 3,800" NA NA NA NA NA more material removed during Step 5 Excavation to 3.5 ft AMSL PSGP04 5998551 660231 5.5 (after excavation) GP & ML NolNolSlight 2,648 NA NA NA NA NA NA PSGP05 5998509 660281 6.3 (during excavation) GP NolNolSlight 247 NA NA NA NA NA NA PSGP06 5998584 660248 6.5 (after excavation) GP No1NolSlight 1,989 2,200 NA NA NA NA NA PSGP08 5998520 660230 5.5 (afterezcavation) GP NoiNolSlight 690 NA NA NA NA NA NA ASPC =Alaska State Plane Coordinates and AMSL =Above Mean Sea Level ICE =Massive ice with>70% ice OL and ICE =Organic-rich silt andlor peat with ice lenses throughout GP =Sands and gravel (pad gravel) ML =Silts and fine sands * =Elevated moisture (>30°h) NA =Not analyzed ND =Not detected above Method Detection Limit (in parenthesis) ~~. r~'~ _ ~s-.fc3rw::.,p-, .y .` . lw+-~ w ~I•".w . 1 ,x v" ~ ...,-W k r'..~ - ..e fY ,TF: U... •. f ^n~- _~ Step 1 Excavation (of lower terrace pad gravel) looking southeast, with material stockpiled. :Y~, ~ ~'.r e Figure 5-1 Step 1 Evaluation Point Storkersen #1 Project Completion Report 1~ u i~ i~ i~ i~ i~ i~ i~ • . • Table 5.2 Flare Pit Field Screening and Confirmation Sampling Results for Step 2 Area: Excavation of Unit 1a Drilling Wastes to an Elevation of 4.0 ft. AMSL r'.(Iv. i ~.i. rN q'~ d.. . __-~ ( ~ ' STEP 2 ' STEP 2 i O (Excavate to - I 4.0 ft AMSL) ~ i SFP-5 ~ ~ ~ I 5998770.000 ~ SFP-6 '1- ---- - 5998760 000 SFP-4 ~' . 9 ~----- ~ SFP-7 OPEN 5998750.000 9 _ _ SFP-3 5998740.000 ~ _ _ ~ ~ _ _-- CAPPED SFP-2 5998730.000 ~ _ 5998720 000 `9 SFP-8 i i i . SFP-1 9 STEP ~ 5996710.000 _ D -. , . ~ FP-9 ~ 5998700.000 _ _ - - - 3 ~ _ ~ °o o° o o ~ °o °o. o o ~ ga ~... 0 0 0 ~ ~ ~ 0 0 0 ~ ~ d m n 0 1 9 Sampling Location O y Photo Location and Direction 15 0 30 GRAPHIC SCALE 1"=60' 0.5'CONTOUR INTERVAL Field Screening Resulls Location Stainl North East Elevation Soil Sheenl TPH Sample (ASPC) (ASPC) AMSL Type Pet,Odor (ppm) SFP-1 5998715 660259 4,1 OUML NolNo!No 372 SFP-2 5998731 660255 4.2 MLandICE NolNoMo 620 SFP-3 5998748 660258 4.0 ML and ICE NolNoMo 587 SFP-4 5998760 660253 4,0 ML and ICE NoINoINo 464 SFP-5 5998772 660251 4.3 MLandICE No1NolNo 359 SFP-6 5998770. 66D244 5.6 (north sidewall) ML and ICE No!NolNo 716 SFP-7 5996754 660233. 5.0 (west sidewall) ML and ICE NolNolNo 561 SFP-8 5998723 660236 5.4 (south sidewall) ML and ICE NoMolNo 421 SFP-9 5998703 660257 4.8 (west sidewall) ML and ICE NoINoMo 692 ASPC =Alaska State Plane Coordinates and AMSL =Above Mean Sea Level ICE =Massive ice with>70% ice OL and ICE =Organic-rich silt andlor peat with ice lenses throughout GP =Sands and gravel (pad gravel) ML =Silts and fine sands `=Elevated moisture (>30%) NA =Not analyzed ND =Not detected above Method Detection Limi1(in parenthesis) J =Detected above Method Detection Limit, but below Practical Quanitafion Limit ~4or=~ __ ~: - y ,~-~ _ _ _ _ . Figure 5-2 Step 2 Evaluation Point Storkersen #1 Project Completion Report Detected Confirmation Sampling Results; (mglkg) Volatile Organic Coumpounds v c N O ~ L ~ d x" O m w F X a NA NA NA NA NA NA 20 NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA 74 NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA NA 65 0.031 0.74 0.08 6.1 022J r~~ ..•y,p, _ rL~. _ ~ ~ %~:r Step 2 Excavation, looking south-southwest. ~: 3 1 g 1 ~J • • • r,u+t,y~ ,a ;c,;~ rr;n1 ~µ,`j ~'I~ OPEN ~II~ ~I STEP 3 APPED ~ OPEN STEP i 1i. . ;; 6 1 ~ Sampling Location O Photo Location and Direction 15 0 30 GRAPHIC SCALE i°=60' 0.5'CONTOUR INTERVAL Table 5.3 Flare Pit Field Screening and Confirmation Sampling Results for Step 3 Area: Excavation of Unii 1 a Drilling Wastes to an Elevation of 5.5 ft. AMSL (South of Step 2) Detected Confirmation Sampling Results: (mglkg) Volatile Organic Coumpounds m Field Screening Results Location Stainl e d c d s99a69o.o0o Norlh Easl Elevation Soil Sheenl TPH o ~ i~ ~ d x" ~ ~ i i ~ ~ i ~ Sample (ASPC) (ASPC) AMSL Type Pet,Odor (ppm) o m w ~ x a I I I I I I I I I s99s6so.ooo__,____~____i____~____i____~ __1____~ ___i____~____i___ _ SFP-10 5998554 660265 5.5 MLandICE NolNolNone 333 51 NA NA NA NA NA '. I I I I I I I I I I I I I I I I I SFP-11 5998606 660244 5.3 MLandICE NoMolNone 253 NA NA NA NA NA NA I I I I i I I I I s9986~0.000 __~____~____' ____;____~____;_ _~____;____~____~___ SFP-12 5998586 660246 5.3 OL NolNolNone 165 NA NA NA NA NA NA I i i i i i i i SFP-13 5998575 660251 5.3 OL NolNolNone 369 71 NA NA NA NA NA s99s66o.o0o i i II ~ II I i ~ ~ ~ SFP-14 5998563 660255 5.3 OL and ICE NolNolNone 179 NA NA NA NA NA NA __~____t_ __r____I____~___ Y____r __.__,_ __.__.T___., I I ' I ' I SFP-15 5996574 660237 5.3 OL and ICE NolNolNone 281 NA NA NA NA NA NA I I I I I I I I I I I I I STEP 3 SFP-16 5996552 660232 5.3 OL NolNolNone 536 130 ND (0.003) 0.067 0.0062 4.3 3.6 5998650.000 -__I_-- ~___-i---_I__-- __--i I I I I I I--- I I I I I I (Excavate to SFP-17 5998590 660227 6.4 OL NoMolNone 112 NA NA NA NA NA NA 5.5 ft AMSL) s99e6ao,ooo __~__ _1____~____ ___~____,____~ _____ __1_ SFP-18 5998570 660228 6.3 OLandICE NolNolNone 115 NA NA NA NA NA NA I I I I I I I ' I I I i I ASPC =Alaska State Plane Coordinates and AMSL =Above Mean Sea Level s99a63o.o00 _~____'____F ___i-----i----+----~----~----~----+--- ICE=Massive ice with>70%ice I ~ ~ ~ ~ II ~ ~ OL and ICE =Organic-rich silt andlor peat with ice lenses throughout I I I I I I I I I I GP =Sands and gravel (pad gravel) s99sbzo.ooo I I I I I I I I I I ML =Silts and fine sands -~----T --~----, ---~----T----~----,----~----T--- ~ I I I I I I I I *=Elevated moisture (>30°h) I ,'' ' i i ~ ~ i i ; NA=Not analyzed s99a6to.ooo _ _ ____I____~____1____L____I____J____1__ _ ND=Not detected above Method DetectionLimO(inparenthesis) ~ ~-t t ~ II ~ i ~ ; ; J =Detected above Method Detection Limit, but below Practical Quanitation Limit I I I I I I I 5998600.000 I I I I I I I ---I----'~----~----~----I------- ~----~ I I I I I I I I I I I I I I I I I I I I I I 5998590.000 SFP-17 ~ I I I I I I I ~ SFP-12 r----I----7----t----r-- r---y--- +----r I I I I I I I 0 I I I I I I I I I I I I I I I I _ I I I I ~----T SFP-15 SFP-13 - - -~----I--------- ----r I I I I I I I I I I I I I I I I I 5998510.000 ~ 9 9 SFP-14 ---~ ---1----~ ----~--- ~--- ~ L a SFP-18 ~ I I I - I - ---, I~ ~ ~~ 5998560.000 -: ~;,/l ~ _ .w.: ~'~A~~ ~ ~,y i•~ -~ SFP-10 -- ..~. - - --.....,, y-- . ~.. C ~ ` SFP-16 ~ _ _ y ,y„ ~ ~ ,,,; r 1998550.000 ~ ` ~ r ,~ a..,~m. •~" '"C~?a ,_ ... _ w ,~ p{€ ~~.. - ~` ~ h+ " ~ `~w I 'ter ~.~ i*~w ~ ~~~ ~~ 4 - SST 0 0 0 0 0 0 0 0 0 o -t. ` - ... g g o o d d o d d-. a ~- ~..- ~1 n n n n n raJi n m° m m m m ~ ~ ~ ~ _ - ~ ~ y ~~ "~ - ~ r 3 ~ •tr k 0 Figure 5-3 Step 3 Evaluation Point Storkersen #1 Project Completion Report Step 3 Excavation, looking north • • • Table 5~4 Flare Pit Field Screening and Confirmation Sampling Results for Step 4 Area: Excavation of Unit 1a Drilling Wastes io an Elevation of 4.5 ft. AMSL (Within Step 3 Area) 0 ~i41d I~~, i I I I I I I I I I I I I I `1d ~?I~;~~r `i. 1"..P `, I I I I I i i I I I ' 5999540.000 I ; ; , STEP 4 I STEP:< '-----~----- (Excavate to •~° SFP-019 ' ~ p i 4.5 ft AMSL) F - I 5998.530.000 I 7---- ~', CAPPED ---I I I I SFP-022 ~ 5998520.000 9 ~ -- 5FP-020 ~----- 9 SFP-026 ~ i p -" s99aslo.ooo __' 5FP-023 ~ r---~ ----- ` ~ 9 i I+ ~ i SFP-025 5FP-021 ~ 5998500.000 -_I__- B __i____- I 4 ~ ~ I SFP-024 t- OPEN E _ __-~ __~ ~ --- 1 ,, s998490.00o I --,------T- ) /1 ~ I _ ----- ~ l I I I i i i i I I I I I I I ~ ~ TE s99saeo.ooo ~------+-----~---- +-----~ I I P ~ - --- - ------~-----+------I- -- ~'~~ I I I I i I I I I i I I - ---- ~ 5998470.000 '• ~ .--- - \ ' 8 0 8 8 8 8p' S o. D ~ `, _. ~ O ~ N M V N STEP 1 rv m m m m m m m b ~ ~ vi $ ~ ~ m STEP 4 - ,;.,:,; ;:, ~;-,: , 0 9 Sampling Location O Photo Location and Direction 15 0 30 GAAPHICSCALE 1"=60' 0.5'CDNTOUR INTERVAL Sample SFP-19 SFP-20 SFP-21 SFP-22 SFP-23 SFP•24 SFP-25 SFP-26 Detected Confirmation Sampling ResuRs: (mglkg) Volatile Organic Coumpounds Field Screening Results d N Location Stainl L d m w North East Elevation Soil Sheenl TPH o ~ r ~ v x" (ASPC) (ASPC) AMSL Type Pet.Odor (ppm) o m" w ~ x a 5998535 6602895.8 (west sidewall)OL and ICE NoMolNone 170 67 NA NA NA NA NA 5998517 6602955,9 (west sidewa ll)OL and ICE NoINolNone 211 81 NA NA NA NA NA 5998501 6603025.8 (west sidewall)OL and ICE NolNolNone 195 62 NA NA NA NA ND(<12) 5998521 660310 5.5 OL and ICE NoMolNone 141 NA NA NA NA NA NA 5998507 660317 5,5 OL NoINolNone 113 NA NA NA NA NA NA 5998494 660321 5.5 ICE NolNolNone Massive Ice NA NA NA NA NA NA 5998508 660329 5,5 OLand ICE NoINolNone 394' NA NA NA NA NA NA 5998514 660341 5.5 OL and ICE No.MolNone 105 NA NA NA NA NA NA ASPC =Alaska State Plane Coordinates and AMSL =Above Mean Sea Level ICE =Massive ice with>70% ice OL and ICE =Organic-rich silt andlor peat with ice lenses throughout GP =Sands and gravel (pad gravel) ML =Silts and fine sands ' =Elevated moisture (>30%) NA =Not analyzed ND =Not detected above Method Detection Limit (in parenthesis) J =Detected above Method Detection Limit, but below Practical Quanitation Limit Figure 5-4 Step 4 Evaluation Point Storkersen #1 Project Completion Report Step 4 Excavation looking south • • Table 5.5 Flare Pit Field Screening and Confirmation Sampling Results for Step 5 Area: Excavation of Unit 1a Drilling Wastes to an Elevation of 3.5 ft. AMSL (Within Step 3 Area) li.~l~'r'r' 1Ai,i4~.!1Ui! 1!tl~-" Si c F` ~ .7iCr p 0 1 9 Sampling Locatbn O Photo Location and Direction 15 0 30 GRAPHIC SCALE t"=6D' 0.6'C0NT0UR INTERVAL -- I . II ° ~ C Detected Confirmation Sampling Results: (mglkg) Volatile Organic Coumpounds Field Screening Results v to N s99s69o.o00 _ _ _ ' Location Stainl c d 'I ~ STEP 5 i i North East Elevation Soil Sheenl TPH Sample (ASPC) (ASPC) AMSL Type PeLOdor (ppm) o o ~ m" r w ; ~ m x = a s99a6eo.ooo I, _ _ _ _ _ F _ _ _ _ _ (Excavate to _ _' _ _ _ _ i- - -- SFP-21 5998620 660252 3.4 OL and ICE NolNolNone 127 ND(2.7) NA NA NA NA NA ~ 3.5 h AMSL) ~ I I I I SFP-28 5998604 660247 3.2 OL and ICE NolNolNone 394 NA NA NA NA NA NA 5998670.000 I I I ' ' I I i SFP-29 5998589 660264 2.9 OL NolNolNone 94 NA NA NA NA NA NA r---- I I I I I I I --r-----i - I I I I -- I SFP-30 5998609 660256 32 OL and ICE NDINoINone 140 ND(4.5) NA NA NA NA ND(<1.7) I I I I ~ I I I I I I I I i SFP-31 5998634 660299 3 OL No(No/None 158 28 NA NA NA NA NA 5998660.000 ~ _ _ _ _ _ L _ _ _ _ _I _ _ _ _ _ 1 _ _ _ _ i _ _ _ I I I I _ _ L _ _ _ _ _I_ _ _ I I _ , I SFP-32 5998583 6602533.6 (west sidewall) ICE NolNolNone Massive Ice NA NA NA NA NA NA I i I I I I i i I I II SFP-33 5998563 6602583.7 (west sidewalQ ICE NoMolNone Massive Ice NA NA NA NA NA NA s99s6so.ooD ; ~ ~ ~ + ~ ~ J SFP-34 5998574 660270 32 ICE NoMolNoneMassivelce NA NA NA NA NA NA _____ ____ ___ _ _____ _____ _____ ___ _ I I I ~ I I I I I I I SFP-35 5998553 660259 3.6 ICE NoMolNoneMassivelce NA NA NA NA NA NA I i SFP-36 5998566. 6602723.7 (west sidewall) ICE NolNolNone Massive Ice NA NA NA NA NA NA s998640.000 I I "- --- r - -' SFP-37 5998616 6602503.8 (north sidewall) ICE NolNolNone Massive Ice NA NA NA NA NA NA SFP-031 ~ ASPC =Alaska State Plane Coordinates and AMSL =Above Mean Sea Level 5998630.000 ICE = Masaive ICe Wlth>7l)% ICe OL and ICE =Organic-rich silt andlor peat with ice lenses throughout GP =Sands and gravel (pad gravel) O 5FP-027 OPEN ML=Silts and fine sands 5998620.000 p ' =Elevated moisture (>30%) ~ NA=Not analyzed SFP-037 ND =Not detected above Method Detection Limit (in parenthesis) J =Detected above Method Detection Limit, but below Practical Quanitation Limit s99a610.000 eSFP-030 9 $FP-028 s998600.000 -------- CAPPED ~ ~ I_- 5998590.000 e$FP-029 I I ~$FP-031 / I i I I s99asao.ooo Q$FP-034 I _L_____I___ I __~________ _ ~r I" I I I I I I ~ I i ,, { T ~~ ~~ ~~~~ `' ~ .~~,, SFP-033~ I I I ~ ,~ 1 `~ H Y~~f I~ s998670.000 I I I -+-----F----I-- $FP-036 I I I I -.~___------- I dux! ~ --' '' - ~ wir` ~"a ~ ~. - --- - 998660.000 I SFP-032 I I I I _ _ _ _ I I I I I I I I I I I I I -^. rc'y . . .~.=~.....r~.-_^,y~-' '~"4'~-- _:''-a._.._ ,r."'' ,.~~ ~'~.~ ~~ ~ ~ ~ ;-~~~.- - . ~ ~..:_..._ .~",_,,, i'-r T..... . i. .Ii... ' '° rM1 SFP-035 ~ ,.. „ ~ ~ ; 6998s60D.000 - - - _ ~w.a.. ~. = O o 0 0 0 o O o d ~ d ro ~ a d d vi vi ~ ~ ~ vi ~ vi Siep 5 Excavation looking west Figure 5-5 Step 5 Evaluation Point Storkersen #1 Project Completion Report --- . '~. . __ li ~~ I i~ i~ i~ u n • CONDITIONS AFTER CLOSEOUT ACTNITIES 5.1.5 Step 5 Area: Excavation of Unit 1 Drilling Wastes to an Elevation of 3.5 ft. AMSL ~' ~. -~.-4 '~~ Step 5 excavation, looking east Qualitative results for the Step 5 excavation area are presented in Figure 5-5. Quantitative field screening results and confirmation sampling results from the subarea within Step 5 are summarized in Table 5-5 as shown on Figure 5-5. .'~ -,~, f ~: Sampling Step 5 excavation subarea No stains or sheen were found and no petroleum odors were noted in the Step 5 area. Massive ice was found throughout the excavation bottom. Also after excavating, field screening results for TPH in the Step 5 subarea (Figure 5-5), were less than 394 mg/kg, and laboratory results for DRO were 28 mg/kg or less. BTEX and PAHs were not detected. Thus, remaining native tundra soils are well below established site cleanup criteria. 5.2 Stockpile Sampling Results 5.2.1 Exempt, Restricted Gravel (Step 1) Stockpile The results of the field screening confirmation samples collected from the stockpiles of exempt, restricted gravel removed during Step 1 to expose underlying drilling wastes are presented in Table 5-6. Field screening results were less than 1,905 ppm TPH with confirmation sampling results indicate DRO concentrations were below the site cleanup criteria of 2,000 mg/kg. It is important to note that XOM opted to dispose of the stockpile by G&I at Drill Site 4. 5.2.2 Well Head Stockpile Sample results from the wellhead stockpile also are presented in Table 5-6. Field screening results were 1,216 ppm TPH with confirmation sampling results of 1,500 mg/kg DRO. XOM also disposed of the stockpile by G&I at Drill Site 4. 5.3 Revegetation and Planned Monitoring Revegetation and follow-up monitoring activities began in late July 2005 and will end in August 2014. 5.73 ANCICTS107.DOC1041060009 CONDITIONS AFTER CLOSEOUT ACTIVITIES TABLE 5.6 Stockpile Field Screening and Confirmation Sampling Results Field Screening Results Detected Confirmation Sampling Results: (mg!kg) Stain! Volatile Organic Compounds Soil Sheen! Pet. TPH Sample Type Odor (ppm) DRO Benzene Ethylbenzene Toluene Xylenes PAHs Exempt, Restricted Stockpiled Gravel (from Step 1 excavation of pad gravel to expose Unit 1 drilling wastes) PSGP01 GP No! 291 NA NA NA NA NA NA No! No PSGP02 GP No! 1 ,432 20 NA NA NA NA NA No! Slight PSGP07 GP No! 1,905 1900 ND 0.053 0.024 0.59 ND No! (0.00088) «0.063) Slight Well Head Excavation Stockpile (also exempt, restricted gravel) PSWELL01 GP No! 619 NA NA NA NA NA NA No! Slight PSWELL02 GP No! 1,216 NA NA NA NA NA NA No! Slight PSWELL03 OL No! 835 1,500 NA NA NA NA NA No! Slight ASPC = Alaska State Plane Coordinates and AMSL = Above Mean Sea Level ICE = Massive ice with>70% ice OL and ICE = Organic-rich silt and!or peat with ice lenses throughout GP = Sands and gravel (pad gravel) ML = Silts and fine sands NA = Not analyzed ND = Not detected above Method Detection Limit (in parenthesis) NOTE: BOTH STOCKPILES EVENTUALLY HAULED TO AND DISPOSED OF BY G&I AT DRILL SITE 4 5.3.1 Revegetation Activities Revegetation was completed in late July 2005. The following steps toward improving soil conditions and revegetation of the site were carried out. 1. Improve soil conditions on the gravel pad and soiVgravel pit caps by adding overburden soil and applying fertilizer. Approximately 1-4 inches of overburden soil was applied in March 2004 (see Section 4.7) to improve ANC\CTS1 07 .DOC\041 060009 moisture and nutrient holding capacity . Fertilizer was spread in late July 2004 in uhall-amounts," with one hall being applied by harrowing into the upper overburden soil in a north-south direction, and the second hall applied by harrow east-west. Spreading in half amounts resulted in an even application and avoiding streaks that can appear when application is in only one direction. 5-14 • The fertilizer used for this project was "0-45-0, treble super phosphate;' at an application of 200 pounds/ 1 acre, for an effective application of 90 pounds/ 1 acre of PZOs fertilizer. 2. Seed site with indigenous plant species. The grass species seeded was Alyeska polargrass (Arctagrostis latifolia), with 8 pure live seed per square foot (pls/ft2) broadcast by cyclone spreader using the same half amount approach. Other seeded species included Artemesia borealis (4pls/ft2), Descicrainia sophoides (lpls/ft2), and Puccinellia angastata (8 pls/ft2). These species were chosen, because of seed availability and adaptation to the habitat. 3. Cover the seed bed. A cover was applied over the seed by dragging soil by harrow. Steps 1 through 3 of the revegetation effort should provide cover to the pad. It is expected other pioneer native species in the area also will begin to occupy the site. 5.3.2 Performance Standards To determine if the revegetation goal of establishing an indigenous plant cover has been met, performance standards for comparison have been established. Overall, the performance standard for the project is > 10 percent live vascular cover of the site (including seeded grasses) by Year 10 (2014), with at least 5 indigenous species. • CONDITIONS AFTER CLOSEOUT ACTNITIES ~~~. . +G Vy,.. .~,A~~_. ~.p - ~~~ _ r, . ~p ~ ;. - ~~~ - ti a y, i D ~~ ~..; !S;, Reserve pit after seeding and tilling (looking east) in July 2004 Revegetation Monitoring Plan Revegetation monitoring is basic and includes the following: • A 10-year revegetation monitoring program. • Monitor and document revegetation progress by comparing it to interim checkpoints and to end performance standards. • Report monitoring results. This monitoring plan will be accomplished by completing the following tasks: 1. Monitoring revegetation efforts. Initial monitoring will involve observing and documenting revegetation activities in late July 2004 2. Monitoring revegetation for comparison to checkpoint throughout the 10-year program, and to performance standards at the end of the program. A visual inspection and photographic inventory of the pad in 2005 and 2006 will be scheduled following the July 2004 site work. The 2005 fall monitoring will be the first of 4 monitoring efforts for the revegetation program over the course of 10 years. The third monitoring effort ANCICTS107.DOC1041060009 5.15 CONDRIONS AFTER CLOSEOUT ACTNI~ will be in Year 6 (2010) and the fourth in Year 10 (2014). 3. Preparing and submitting reports of findings that presents results of the revegetation monitoring. TABLE 5-7 Revegetation Project Schedule, Performance Standards, Monitoring and Reporting Requirements Year Treatment Goal Checkpoints/ Monitoring Reporting Performance Methods Requirements Standards Several interim checkpoints also have been established for monitoring (Table 5-~. These are not as rigorous as the final performance standards to be met at the end of the 10-year program, but they will help gauge if revegetation is underway. • Year 1 Apply fertilizer Establish Baseline after (June (optional) and healthy plant revegetation 2004) seed (required) community with sufficient cover to stabilize cap Years 2 None and 3 (August 2005 and 2006) Year 6 None (August 2010) Year 10 (August 2014) None Confirm establishment healthy plant community Confirm healthy plant community, that includes indigenous species Confirm healthy plant community, that includes indigenous species Checkpoint: >5% live vascular cover (including seeded grasses) Checkpoint: >5% live vascular cover (including seeded grasses) and 2 indigenous species Performance Standards: >10% live vascular cover (including seeded grasses) and at least 5 indigenous species Plant canopy cover, density and species identification/ composition measurements by 10 photoplots. Plant canopy cover, density and species composition measurements by 10 photoplots and walking point. Plant canopy cover, density and species composition measurements by 10 photoplots and walking point. Plant canopy cover, density and species composition measurements by 10 photoplots and walking point. Monitoring letter report with initial site data Monitoring letter report with Years 2 and 3 site data Monitoring letter report with Year 6 site data summarized. Comparison to prior Year3 checkpoints Monitoring report with Years 10 site data summarized. Comparison to prior Year 6 checkpoint with conclusion on whether performance standard has been met 5•t6 ANCICTS107.DOC1041060009 Flare pit after seeding and tilling (looking south) in Ju1y2004. SECTION 6 Conclusions 6.1 Substantial Effects Assessment (after Closeout) As noted in Section 4, after excavating and hauling away drilling waste, gravel backfill was placed as a cap over the entire footprint of the reserve pit, flare pit, and well head excavation. ..e.:as-~.. Panoramic landscape of flare pit after excavating and during backfilling to south). ~. 1~ Panoramic landscape of flare pit and drill pad after placing cap (looking west, sweeping north to south). Sufficient fill was placed to account for a thaw settlement factor of 25 percent for frozen soils in several excavations and depressions, all while maintaining positive drainage. Therefore, as shown on Figure 4-1, caps vary in elevation with respect to surrounding tundra from 1.3 feet at the crown to 0 feet where they daylight into surrounding tundra. The • The gravel was then covered with a thin (0.3-foot) lift of organic overburden. Most of the middle and upper drill pad terraces also were covered with about 0.3 feet of organic overburden. 1.. end result is that the caps should be about 0.5 to 1 feet above surrounding tundra elevation after settlement. These corrective actions have resulted in the following: • The Unit 1 drilling wastes in the Pt. Storkersen #1 flare pit have been successfully removed. east, sweeping north ANCICTS107.DDC1041060009 s.~ CONCLUSIONS • • The Pt. Storkersen #1 reserve pit cap has been successfully backfilled and graded to provide positive drainage. • The remaining petroleum contamination identified within the drill pad is found in concentrations below the ADEC-approved cleanup level. Therefore, there are no known areas of contamination remaining that could have substantial future effects on surface water, groundwater, soil, or sediments at the Pt. Storkersen #1 site. • 6.2 Conclusion The drilling wastes, associated gravel, and underlying contaminated native material were successfully identified and removed from the Pt. Storkersen #1 site. The remaining gravel pad and reserve and flare pits require no further corrective actions. Therefore, this site is suitable for final closure as identified in 18 AAC 60.440 (j)(3) and 18 AAC 75. r~ Panoramic landscape of reserve pit and drill pad after placing cap (looking north, sweeping west to east). ~ .T G ~ ~ ~ ~~, ~~ ~~ i 4 ,1 3 ~..., _ _. `_ ~.~ `~~•' ` ~ 4 ~~ _ ,~ -•~ ~~ w ..:. ~, .~... MP 4 -,. ..~-w ~~~- - ~~ ..: •4~ ~ r '.. +° t "? _ aY~~ M.a. ~ ~ ,~ .~.. ~, .-. -, ~,.., r~a' .. '. '~ ~.'`w~a~~1r.-~ ilk. ~ ~ _ ~ F. ,... Oblique view of Pt. Storkersen 1 exploration site (looking east) after seeding and tilling in July 2004. 6.2 ANCICTS707.DOC1041060009 ' ANC\CTS1 01.DOC\041 060009 (" ( Appendix A Manifest and Progress Reports Tracking ( Pt. Storkersen #1 Manifests ExxonMobil March 2004 Manifest No. Driver Truck No. Trailer No. Loads Volume (cy) Loads Faxed In? Manifest Returned? Date Shift Note: Drilling Wastes Hauled and Disposed at DS 4 G&I 238 901 Morton Wubold 12-173 15-143 2 54 called in Yes 03/20/04 Day Signed original at DS#4 G&I 238 902 Anthony Hughes 12-174 15-152 2 54 called in Yes 03/20/04 Day Signed original at DS#4 G&I 238 903 Darrell Roetman 12-297 1 5-120 2 54 called in Yes 03/20/04 Day Signed original at DS#4 G&I 238 904 Gary Penker 12-167 15-113 2 54 called in Yes 03/20/04 Day Signed original at DS#4 G&I 238 905 Morton Wubold 12-173 15-143 4 108 called in Yes 03/21104 Day Signed original at DS#4 G&I 238 906 Gary Penker 12-167 15-11 3 4 108 called in Yes 03/21/04 Day Signed original at DS#4 G&I 238 907 Stan Grove 12-176 1 5-151 3 81 called in Yes 03/21/04 Day Signed original at DS#4 G&I 238 .908 Anthony Hughes 12-174 15-152 4 108 called in Yes 03/21/04 Day Signed original at DS#4 G&I 238 909 Joe Schmitt 12-166 15-11 9 3 81 called in Yes 03/21/04 Day Signed original at DS#4 G&I 238 910 James Mrosla 12-178 1 5-149 3 81 called in Yes 03/21/04 Day Signed original at DS#4 G&I 238 911 Darrell Roetman 12-176 15-120 3 81 called. in Yes 03/21/04 Day Signed original at DS#4 G&I 238 912 Darrell Wingrove 12-167 15-11 3 5 135 called in Yes 03/21/04 Night Signed original at DS#4 G&I 238 913 Bruce Pullar 12-174 15-152 5 135 called in Yes 03/21/04 Night Signed original at DS#4 G&I 238 914 Larry Pyatt 12-176 15-120 5 135 called in Yes 03/21/04 Night Signed original at DS#4 G&I 238 915 Anthony Hughes 12-174 15-152 5 135 called in Yes 03/22/04 Day Signed original at DS#4 G&I 238 951 Wayne "Butch" Kern 12-167 15-113 4 108 called in Yes 03/1 8/04 Day Signed original at DS#4 G&I 238 952 Jeremy MacPhee 12-178 15-149 3 81 called in Yes 03/18/04 Night Signed original at DS#4 G&I 238 953 Don Dillon 12-170 15-151 3 81 called in Yes 03/18/04 Night Signed original at DS#4 G&I 238 954 James G Catlin 12-166 15-119 3 81 called in Yes 03/18/04 Night Signed original at DS#4 G&I 238 955 Darrell Wingrove 12-167 15-11 3 3 81 called in Yes 03/19/04 Night Signed original at DS#4 G&I 238 958 Larry Pyatt 12-176 15-120 3 81 called in Yes 03/19/04 Night Signed original at DS#4 G&I 238 959 Bruce Pullar 12-174 15-122 3 81 called in Yes 03/19/04 Night Signed original at DS#4 G&I 238 960 Gary Penker 12-167 1 5-113 4 108 called in Yes 03/22/04 Day Signed original at DS#4 G&I 238 961 Darrell Roetman 12-177 15-145 4 108 called in Yes 03/22/04 Day Signed original at DS#4 G&I 238 962 Morton Wubold 12-173 15-143 3 81 called in Yes 03/22/04 Day Signed original at DS#4 G&I 238 963 Wayne "Butch" Kern 12-166 15-119 3 81 called in Yes 03/22/04 Day Signed original at DS#4 G&I 238 964 Larry Pyatt 12-176 15-120 4 108 called in Yes 03/22/04 Night Signed original at DS#4 G&I 238 965 Darrell Wingrove 12-167 15-113 4 108 called in Yes 03/22/04 Night Signed original at DS#4 G&I 238 966 Bruce Pullar 12-174 15-152 4 108 called in Yes 03/22/04 Night Signed original at DS#4 G&I 238 967 Gary Penker 12-167 1 5-113 5 135 called in Yes 03/23/04 Day Signed original at DS#4 G&I 238 968 Anthony Hughes 12-174 15-152 5 135 called in Yes 03/23/04 Day Signed original at DS#4 G&I 238 969 Morton Wubold 12-176 15-120 5 135 called in Yes 03/23/04 Day Signed original at DS#4 G&I 238 970 Darrell Roetman 12-177 1 5-142 5 135 called in Yes 03/23/04 Day Signed original at DS#4 G&I 238 971 Joe Schmitt 12-174 1 5-1 51 1 27 called in Yes 03/26/04 Day Signed original at DS#4 G&I 238 972 James Mrosla 12-178 15-149 1 27 called in Yes 03/26/04 Day Signed original at DS#4 G&I 238 973 Darrell Roetman 12-177 15-142 5 135 called in Yes 03/26/04 Day Signed original at DS#4 G&I 238 974 Stan Grove 12-170 15-151 1 27 called in Yes 03/26/04 Day Signed original at DS#4 G&I 238 975 James MacMillian 12-193 1 5-11 3 4 108 called in Yes 03/26/04 Day Signed original at DS#4 G&I 238 976 Larry Pyatt 12-177 15-142 2 54 called in Yes 03/26/04 Night Signed original at DS#4 G&I 238 977 Travis Kent 12-166 15-11 6 5 135 called in Yes 03/27/04 Day Signed original at DS#4 G&I 238 978 Darrell Roetman 12-177 15-142 5 135 called in Yes 03/27/04 Day Signed original at DS#4 G&I 238 979 Larry Pyatt 12-167 1 5-11 3 5 135 called in Yes 03/27/04 Day Signed original at DS#4 G&I 238 980 James MacMillian 12-169 15-111 2 54 called in Yes 03/27/04 Day Signed original at DS#4 G&I 238 981 Anthony Hughes 12-174 15-151 2 54 called in Yes 03/28/04 Day Signed original at DS#4 G&I 238 983 Larry Pyatt 12-167 15-113 2 54 called in Yes 03/28/04 Day Signed original at DS#4 G&I 238 984 Travis Kent 12~ 166 1 5-11 9 2 54 called in Yes 03/28/04 Day Signed original at DS#4 G&I 238 985 Morton Wubold 12-176 15-120 2 54 called in Yes 03/28/04 Day Signed original at DS#4 G&I 238 986 Darrell Roetman 12-177 15-142 2 54 called in Yes 03/28/04. Day Signed original at DS#4 G&I Service Area 10 Landfill Trip Tkt. 8002 Craig 12-177 15-142 30 Wood and metal debris Yes 03/28/04 Day Signed ticket at Service Area 1 ( Pad 3 Class I Injection Well 238 956 Chuck Ross 12-209 15-146 1 84 bbls Cement rinsate Yes 03/19/04 Day pH 11, Class I, Non-hazardous. 238 957 Chuck Ross 12-209 15-146 0 85 bbls Fresh flush water Yes 03/19/04 Day Class I, Non-hazardous. Signed 600090~ to\:>OO'lO ~Sl:>\:>NV uo!tenIeAa etea pue stJodêr~I etea ÂJoteJoqel 9 x!puaddv --] OJ '] I ~I c] J ) ) I ] ] .1 J I I AN¡\LYTICA Environmental Laboratories I~' I 3/24/2004 CH2M Hill of Alaska 301 W. Northern Lights Suite 601 Anchorage, AK. 99503 Attn: Rob Crotty Lab Sample Number A0403205-0 1 A0403205-03 A0403205-05 A0403205-07 ( Analytica International, Inc. 5761 Silverado Way, Unit N Anchorage, AI< 99518 Phone: 907-258-2155 Fax: 907-258-6634 Work Order #: A0403205 Date: 3/24/2004 Work ID: Pt. Storkersen #1 Date Received: 3/23/2004 Sample Identification Client Description SFP-019 SFP-021 PS-Well-03D. SFP-27 . Lab Sample Number . A0403205-02 A0403205-04 A0403205-06 A0403205-08 Client Description SFP-020 PS- W ell-03 SFP-30 SFP-31 Enclosed are the analytical results for the submitted sample(s). Please review the CASE NARRATIVE for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided.at the end of the report. Sincerely, Jason Gray Project Manager "The Science of Analysis, The Art of Service" Case Narrative Analytiea Alaska Inc. Work Order: A0403205 Samples were prepared and analyzed by methods in the following references: ADEC Method AKI02 For the Determination of Diesel Range Organics. SAMPLE RECEIPT: Samples for Pt.Storkensen project were received at Analytica-Anchorage (ADEC Laboratory Approval Number: UST-014}on 3/23/2004 at a temperature of 4.0°C. Samples were received in good condition and in order per chain of custody. As per client request, EPA method Method 3630C silica gel clean-up of the DRO sample extracts was performed on the sample extracts in order to minimize the influence of potential background biogenic hydrocarbon from the sample matrix. Please note that silica gel clean-up is not currently approved as a part of the standard AKI02 methodology. DRO samples reported on Rush 24-hr basis, remainder of results from this delivery to be reported'later on standard turn around time. REVIEW FOR COMPLIANCE WITH ANALYTICA QA PLAN A summary of our review is shown below, organized by test: Test Method: ADEC AKI02 - . (DRO w/ Silica Gel Cleanup) HOLDING TIMES: Holding times were met for this test. INSTRUMENT CALIBRATIONS: Initial calibration and CCV samples met method criteria. SURROGATE RECOVERIES: There were no surrogate recovery outliers. METHOD BLANK OUTLIERS: There were no MB outliers. LCS/LCSD OUTLIERS: There are no LCS/LCSD outliers. ( Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: ClientSal!lple Name: None Client Sample Report ISFP-019 Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sampie Number: A0403205-01A Prep Date: 3/23/2004 Analytical Method ill: ADEC AKI02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt.lvol: 10.17 g Analvte CASNo Result FIaes Units Diesel Range Organics n/a 67 mglKg Surroeate CASNo Result Flaes !l1!m. o-Terphenyl 84-15-1 9.3 mglKg ;, The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-01A Prep Date: 3/23/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ill: D2216 Prep Batch Number: A040324001 Report Basis: As Received Sample prep wt.lvol: 10.86 g Analvte Moisture CASNo na Result 56 Page 3 of 18 FIaes Units % Analytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 23 3.5 POL 1.1 MDL Snike 0.21 11 0/0 Recov 82.7 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL M!& 0.024 0.0049 3/21/2004 11 :OO:OOAM 3/23/2004 5:08:00PM Woof W4032358.D 1 57 GD 1.00 rol Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 JS 5.28 rol Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report ISFP-020 Client Sample Name: Matrix: Soil I The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-02A Prep Date: 3/23/2004 Analytical Method ID: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt.lvol: 11.11 g Analvte CASNo Result Flaes Units Diesel Range Organics n/a 81 mglKg Surroeate CASNo Result Flaes !l!Ÿ!! o-Terphenyl 84-15-1 8.3 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-02A Prep Date: 3/23/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040324001 Report Basis: As Received Sample prep wt.lvol: 10.02 g Analvte Moisture ~ 60 Flaes Units % ~ na Page 4 of 18 Analytica Alaska Inc. ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 23 3.5 POL 1.1 MDL SDike 0.21 11 0/0 Recov 73.0 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.023 0.0046 3/21/2004 11:10:00AM 3/23/2004 5:37:00PM Woof W4032359.D 1 60 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 JS 4.57 ml Rerun #: 1 ( Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report ISFP-021 Client Sample Name: Matrix: Soil The folloWiIig test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-03A Prep Date: 3/23/2004 Analytical Method ill: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt./vol: 11.02 g Analvte ~ ~ Fla2S .!!!!i!! Diesel Range Organics nJa 62 mglKg ~ Surro2ate CASNo ~ Fla2s Units 0- Terphenyl 84-15-1 8.2 mglKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-03A Prep Date: 3/23/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Pr~p Batch Number: A040324001 Report Basis: As Received Sample prep wt./vol: 10.09 g Analvte Moisture CASNo na ~ 58 Fla2s Units % '"' Page 5 of 18 Analytica Alaska Inc. ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 22 3.4 POL 1.0 MJ21 SDike 0.20 11 % Recov 75.2 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MJ21 0.024 0.0047 3/21/2004 11 :20:00AM 3/23/2004 6:06:00PM Woof W4032360.D 1 58 GD 1.00 ml Rerun #: 1 !£1 VCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE . 1 JS 4.78 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report Ips- W ell-03 Client Sample Name: Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-04A Prep Date: 3/23/2004 Analytical Method ID: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323 004 Report Basis: Dry Weight Basis Sample prep wt.lvol: 27.82 g Analvte CASNo Result Fla!:s Units Diesel Range Organics nla 950 mg/Kg Surro!:ate CASNo Result Fla!:s Units 0- Terphenyl 84-15-1 1.5 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-04A Prep Date: 3/23/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040324001 Report Basis: As Received Sample prepwt.lvol: 11.89 g Analvte Moisture CASNo na ~ 18 Page 6 of 18 Fla!:s Units % Analytica Alaska Inc. ~ Collection Date: ' Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 4.4 0.68 POL MDL Spike 0.21 0.041 2.2 % Recov 66.9 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.042 0.0083 3/21/2004 6:00:00PM 3/23/2004 6:34:00PM Woof W4032361.D 1 18 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 JS 9.89 mt Rerun #: I ( Detailed Analytical Report W orkorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Bill of Alaska Client Project Number: Report Section: None Client Sample Report Ips- W ell-03D Client Sample Name: Matrix: Soil I The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-05A Prep Date: 3/23/2004 Analytical Method ID: ADEC AKI02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt.!vol: '25.93 g Analvte CASNo Result Flal!s Units Diesel Range Organics nla 1,500 mglKg Surroeate CASNo Result Flal!s Units 0- Terphenyl 84-15-1 2.4 mglKg [ The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-05A . Prep Date: 3/23/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A04032400 1 Report Basis: As Received Sample prep wt.!vol: 11.50 g Analvte Moisture B!!Y!! 14 Flal!s Units % ~ na Page 7 of 18 Analytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 22 3.5 POL 1.0 MDL SDike 0.21 2.2 % Reeov 109 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: . Prep Extract Vol: POL M!!L 0.044 0.0088 3/21/2004 6:05:00PM 3/23/2004 7:03:00PM Woof W4032362.D 5 14 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 JS 10.06 m1 Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report (SFP-30 Client Sample Name: Matrix: Soil I The following test was conducted by: Analytica - Anchurage Lab Sample Number: A0403205-06A Prep Date: 3/23/2004 Analytical Method ID: ADEC AKI02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt.lvol: 11.26 g Analvte CASNo Result Fla!!s Units Diesel Range Organics n/a ND mg/Kg Surro!!ate CASNo Result Fla!!s Units o-Terphenyl 84-15-1 10 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-06A ' Prep Date: 3/23/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A04032400 1 Report Basis: As Received Sample prep wt.lvol: 11.72 g Analvte Moisture CASNo na Result 70 Page 8 of 18 Fla!!s !l!!!!! % Analytica Alaska Inc. ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 29 4.5 POL 1.4 MDL SDike 0.28 15 % Recov 70.8 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.018 0.0036 3/21/2004 3:00:00PM 3/23/2004 7:32:00PM Woof W4032363.D 1 70 GD 1.00 ml Rerun #: 1 LCL VCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 IS 4.21 ml Rerun #: 1 ( Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report ISFP-27 Client Sample Name: Matrix: Soil The followmg test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-07 A Prep Date: 3/23/2004 Analytical Method ill: ADEC AKl 02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt./vol: 10.24 g Analvte CASNo Result Fla!!s !l!!i!! Diesel Range Organics nJa ND mglKg Surro!!ate CASNo Result Fla!!s !l!!i!! 0- Terphenyl 84-15-1 7.7 mglKg [ I The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-07 A Prep Date: 3/23/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040324001 Report Basis: As Received Sample prep wt./vol: 10.91 g Analvte Moisture CASNo na Result 44 Fla!!s !l!!i!! % I I l Page 9 of 18 ( Analytica Alaska Inc. ~ Collection Dàte: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 18 2.7 POL MDL Spike 0.82 0.16 8.8 % Recov 87.6 AÌ1alysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL~ 0.030 0.0060 3/21/2004 3:05:00PM 3/23/2004 8:01 :OOPM Woof W4032364.D 1 44 GD 1.00 ml Rerun #: 1 LCL VCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 JS 6.51 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403205 Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: ~one Client Sample Report ISFP-31 Client Sample Name: Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-08A Prep Date: 3/23/2004 Analytical Method ID: ADEC AKI02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323004 Report Basis: Dry Weight Basis Sample prep wt.lvol: 11.94 g Analvte CASNo Result Fla2:S Units Diesel Range Organics n/a 28 mg/Kg Surro2:ate CASNo Result Fla2:s Units 0- Terphenyl 84-15-1 4.4 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403205-08A Prep Date: 3/23/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040324001 Report Basis: As Received Sample prep wt.lvol: 11.23 g Analvte Moisture CASNo na Result 25 Fla2:s !l!!.!!! % Page 10 of 18 Analytica Alaska Inc. ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 11 1.7 POL MDL SDike 0.52 0.10 5.6 % Recov 77.9 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL M!!L 0.039 0.0077 3/21/2004 3:10:00PM 3/23/2004 8:29:00PM Woof W4032365.D 1 25 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 18 8.66 ml Rerun #: 1 ( Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Method Blank Report 1MB Client Sample Name: Matrix: Solid I' The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040323004-MB Prep Date: 3/23/2004 Analytical Method ill: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040323 004 Report Basis: Dry Weight Basis Sample prep wt./vo1: 25.33 g Analvte CASNo Result Fla!!s Units Diesel Range Organics nla ND mgIKg SUIToeate CASNo Result Fla!!s Units 0- Terpheny1 84-15-1 2.0 mglKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A04032400 I-MB Prep Date: 3/23/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ill: D2216 Prep Batch Number: A04032400 1 Report Basis: Dry Weight Basis Sample prep wt./vo1: 11.00 g Analvte Moisture ~ na Result ND Fla2s !I!!i!! % Page 11 of 18 Ana1ytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 3.9 0.61 POL MDL Suike % Reeov 0.19 0.037 2.0 101 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.050 0.010 3/23/2004 12:00:00AM 3/23/2004 3:42:00PM Woof W4032355.D 1 NA GD 1.00 m1 Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/24/2004 10:00:50PM SCALE 1 NA JS 10.99 m1 Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None Tests Run at: Analytica Environmental Laboratories - Anchorage, Alaska W orkorder (SDG): A0403205 Project: Pt. Storkersen #1 Project Number: Prep Batch: QUALITY CONTROL REPORT A040324001 Analysis: ASTM D2216 - % moisture SAMPLE DUPLICATE REPORT Base Sample:A0403205-08A Prep Date: 3/23/2004 Samp. Anal. Date: 3/24/2004 10:00:50PM DUP Anal. Date: 3/24/2004 10:00:50PM Units: Matrix: % Soil Analyte Name Moisture SampResult DUPRes. 25.1 23.8 RPD 5.3 RPDLim 20 Flag Prep Batch: A040323004 LCS/LCSD REPORT Analysis: ADEC AKI02 - w/ silica gel cleanup MB: Prep Date: Units: 4:39:00PM Matrix: A040323004-MB 3/23/2004 mglKg Solid MB Anal. Date: 3/23/2004 3 :42:00PM LCS Anal. Date: 3/23/2004 4: 11 :OOPM LCSD Anal. Date: 3/23/2004 Analyte Name Diesel Range Organics SampResult LCSRes. SDRes. SPLev SPDLev Recov.. SD Recov RPD Recov Lim RPDLim Flag ND 74.8 74.0 79.6 78.6 94.0 94.1 1.1 60-120 20 FOOTNOTES TO QC REPORT Note 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. Note 3: For sample duplicates, ifthe result is less than the PQL, the duplicate RPD is not applicable. Ifthe sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Note 4: For serial dilutions, if the result is less than the PQL, the duplicate RPD is not applicable. If the sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 12 of 18 (' Detailed Analytical Report Workorder (SDG): A040320S Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None SURROGATE RECOVERY SUMMARY REPORT Page 13 of 18 Detailed Analytical Report W orkorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None Test Method: ADEC AK102 - wI silica ~el cleanup Lab Sample #: A0403205-01A Dilution: 1 Analysis Date: 3/23/2004 5:08:00PM Client Sample: SFP-019 Batch Number: A040323004 Data File: W4032358.D AnalvteName SSRecov LCL !E& SSFla2 Result Status o-Terphenyl 83 50 150 Complete Lab Sample #: A0403205-02A Dilution: 1 Analysis Date: 3/23/2004 5:37:00PM Client Sample: SFP-020 Batch Number: A040323004 Data Ftle: W4032359.D AnalvteName SSRecov LCL UCL SSFla2 Result Status 0- Terphenyl 73 50 150 Complete Lab Sample #: A0403205-03A Dilution: 1 Analysis Date: 3/23/2004 6:06:00PM Client Sample: SFP-021 Batch Number: A040323004 Data File: W4032360.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 75 50 150 Complete Lab Sample #: A0403205-04A Dilution: 1 Analysis Date: 3/23/2004 6:34:00PM Client Sample: PS- W ell-03 Batch Number: A040323004 Data File: W4032361.D AnalvteName SSRecov LCL UCL SSFla2 Result Status 0- Terphenyl 67 50 150 Complete Lab Sample #: A0403205-05A Dilution: 5 Analysis Date: 3/23/2004 7:03:00PM Client Sample: PS- Well-03D Batch Number: A040323004 Data File: W4032362.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 109 50 150 Complete Lab Sample #: A0403205-06A Dilution: Analysis Date: 3/23/2004 7:32:00PM Client Sample: SFP-30 Batch Number: A040323004 Data File: W4032363.D AnalvteName SSRecov LCL UCL SSFla2 Result Status 0- Terphenyl 71 50 150 Complete Lab Sample #: A0403205-07 A Dilution: 1 Analysis Date: 3/23/2004 8:0 1:00PM Client Sample: SFP-27 Batch Number: A040323 004 Data File: W4032364.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 88 50 150 Complete Lab Sample #: A0403205-08A Dilution: 1 Analysis Date: 3/23/2004 8:29:00PM Client Sample: SFP-31 Batch Number: A040323004 Data File: W4032365.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 78 50 150 Complete Lab Sample #: A040323004-MB Dilution: Analysis Date: 3/23/2004 3:42:00PM Client Sample: MB Batch Number: A040323004 Data File: W4032355.D AnalvteName SSRecov LCL UCL SSFla2; Result Status Page 14 of 18 ( f Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None Test Method: ADEC AK102 - wI silica gel cleanup Lab Sample #: A040323004-MB Dilution: 1 Analysis Date: 3/23/2004 3:42:00PM Client Sample: MB Batch Number: A040323004 Data File: W4032355.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 101 60 120 Complete Lab Sample #: A040323004-LCS Dilution: Analysis Date: 3/23/2004 4: 11 :OOPM Client Sample: LCS Batch Number: A040323004 Data File: W4032356.D AnalvteName SSRecov LCL UCL SSFla!! Result Status 0- Terphenyl 109 60 120 Complete Lab Sample #: A040323004-LCSD Dilution: Analysis Date: 3/23/2004 4:39:00PM Client Sample: LCSD Batch Number: A040323004 Data File: W4032357.D AnalvteName SSRecov LCL UCL SSFla2 Result Status o-Terphenyl 110 60 120 Complete Page 15 of18 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None QC BATCH ASSOCIATIONS - BY METHOD BLANK Lab Project ID: 26,237 Lab Project Number: A0403205 Prep Date: 3/23/2004 Lab Method Blank Id: Prep Batch ID: Method: A040323004-MB A040323 004 ADEC AKI02 - w/ silica gel cleanup This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A040323004-LCS LCS W4032356.D 3/23/2004 4: II :OOPM A040323004-LCSD LCSD W4032357.D 3/23/2004 4:39:00PM A0403205-01A SFP-019 W4032358.D 3/23/2004 5:08:00PM A0403205-02A SFP-020 W4032359.D 3/23/2004 5:37:00PM A0403205-03A SFP-021 W4032360.D 3/23/2004 6:06:00PM A0403205-04A PS-Well-03 W4032361.D 3/23/2004 6:34:00PM A0403205-05A PS-Well-03D W4032362.D 3/23/2004 7:03:00PM A0403205-06A SFP-30 W4032363.D 3/23/2004 7:32:00PM A0403205-07A SFP-27 W4032364.D 3/23/2004 8:01:00PM A0403205-08A SFP-31 W4032365.D 3/23/2004 8:29:00PM Prep Date: 3/23/2004 Lab Method Blank Id: Prep Batch ID: Method: A040324001-MB A040324001 ASTM D2216 - % moisture This Method blank and sample preparation batch are associated with the following samples; spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A0403205-01A SFP-019 3/24/2004 10:00:50PM A0403205-02A SFP-020 3/24/2004 10:00:50PM A0403205-03A SFP-021 3/24/2004 10:00:50PM A0403205-04A PS- W ell-03 3/24/2004 10:00:50PM A0403205-05A PS- Well-03D 3/24/2004 10:00:50PM A0403205-06A SFP-30 3/24/2004 10:00:50PM A0403205-07 A SFP-27 3/24/2004 10:00:50PM A0403205-08A SFP-31 3/24/2004 10:00:50PM A0403205-08A-DUP DUP 3/24/2004 10:00:50PM Page 16 of 18 ( Detailed Analytical Report Workorder (SDG): A0403205 Project: Pi. Storkersen #1 Client: CH2M Bill of Alaska Analytica Alaska Inc. Client Project Number: None DATA FLAGS AND DEFINITIONS The PQL is the Method Quantitation Limit as defined by USACE. Reporting Limit: Limit below which results are shown as "ND". This may be the PQL, MDL, or a value between. See the report conventions below. Result Field: ND = Not Detected at or above the Reporting Limit ;:) NA = Analyte not applicable (see Case Narrative for discussion) Qualifier Fields: . LOW = Recovery is below Lower Control Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E = Reported concentration is above the instrument calibration upper range Organic Analysis Flags: ) B = Analyte was detected in the laboratory method blank J = Analyte was detected above MDL or Reporting Limit but below the Quant Limit (PQL) Inorganic Analysis Flags: J = Analyte was detected above the Reporting Limit but below the Quant Limit (PQL) W = Post digestion spike did not meet criteria S = Reported value determined by the Method of Standard Additions (MSA) Other Flags may be applied. See Case Narrative for Description l. 1- Page 17 of18 Detailed Analytical Report Workorder (SDG): A0403205 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client :Project Number: None Analytica Alaska Inc. REPORTING CONVENTIONS FOR THIS REPORT A0403205 TestPkeName AK102/3550B (Solid) - wI silica gel cleanup ASTMD22161 ASTMD22 I 6 (Solid) - % moisture Page 18 of 18 Basis Dry Weight Basis As Received ) # Sie Fies 2 2 Reportine Limit Report to PQL Report to PQL , ";" ",' :," H'i""'.' :". "', .I!, ...,,'.. ¡~,.,~'Y'.,: ,'. ",:. :,:~':".~, " ::} ,'..., ,..~..'. ' , ,.,.',;..:.!.."..:, .:::¡. . :" :',' 't '" :, ,', ' , " ;, ;'1 ;'. : " ,\" :, ,,: " ~"Ii:: ".', ': ,".- ., " .- ::.-: :''- WI~'" "~', 3,Q,;A 3 5' ',:';. ' , ,.. P,., . :,c<:-r,~ ~,:::~ ,;,~', ,::'L;::,7;;.. .~¡;~~~~~t ',".:.,.:~~~~f: "<,~~~~~~~:~~rëëí:"j~~;~~~~~:'~;Í)~~. 'Â' '"; ;:,;A~A¡.r';F~ç~i \"~'::~;'!9ij7¡ ~1~~i" ,'~" .!' ~ /xecm~~P,~ '.', ,~,;; :::'! ~., ,i~j'~!l9c8l!~~~,.... ',. ,. 'â~oi.: .c' " ' '.', ;'. ð}.,~1 , ..,: . '. ::- ..' .:; :~q, ~: 9 l~ P<,;:~:;, '7 r"'x:, (907)~~~6:W.. .. !~; :. ,:F~:'~?,~~70,;: .~':. ?A}(' 1SOB~.~9~4,'. 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"" ,:>: ,ø~",..",,';:":.~'wr.;~~.CbbJers'. ," '""., ~",,'L " :. . .' ::.F;!I!r!:':'" . ,:'.,::,.'&"~ H;~~,'~:. ;"'~ÌJ!1L? ::\'f, r,>: :{ ~ ,: '.; :f.t.iÍ,;¡I,: ~., ~,:::. ,t ,;, :i' ,l'I!¡I:.:;; r :;', """.: ..." '.; .,:: ":' "j;/Si "*t:~ . -, :::. ,"f;.:' '. .,;¡, ,,::.- " " ; ".y::.rt;;...'J"L;', ,:ï.~Jrl""'(.',h~:".:::..';", ':.' ,,',' T '':'''..: , .. , , 'I' 1;; ", ¡!,IL ~M1... "~~1.~., .~~"" ,," .,.:''1'', ,., .",',.r,' "."~..'" . r~ ",.",,',' , .. .."- '..' , "",,"¡; .0'...1"- ,.,\.~" :':,""1 ,,,,;.. "" "~ '.. ',',', ' ,.,.".~t'Ç.~,;:m't'~'!:'r >':~ . ,.' ".: l ,','. :'.':"'" ;:".;':;.',';"::\ ';;:' ,,;~tiJ ;",¡¡¡¡:~~":' "~"'I::' :":: ",',""'r":;'::;'''~:''~'';- ,"!,:',i.;';,,:,.', ,",~ :'1'::", -ç "".;,r':ii'"";,,,,~:-:; ,;- i ,:!': ¡...i,,~"i\:',;~:-,-:.', ::. ,.';'" ,.;'" 1/ '. .~~o't ":';:: :~:;.; ,6å~~ld.¥ !B,oi~;i, ,. '.~~1J.€o~.:@Ølà~< ';' '~t{'~&:4:~(\3~'~.~~~'~DtJwêrYj~:~~,~.~ " ': , ,',: .,.:< ,.~ '~~... -..'J¡:~:::~ ... , .'. ¡: ;~, ,. ." ,',,:',:.,',. "::'~' .::',~"'::-.., '<: ,:.,' ,'\.:. ~>lt'? ,:...~ .':., ,:::"::~t.~':.",', ,.~. ,:, ¡';". '.:, .. I"~ A ANALYTIcA cUènt: CH2M Hill of Alaska Project: Pt. Stòrkersen #1 Cooler ID: 1 A. Preliminaiv 'Exafninatlón Phase: 1. Was alrblll Ättached? 2. 'Custody Seals? Yes Yes 3. Seals intact? Yes 4. Screened for radiation? NlA 5~ cac Attached? Yes 6. Project Identificatión from cuStody paper: 7. Preservative: 81ueGel ( Cooler Receipt Form Client Code: 006120 . Date cooler opened: Coòler opened by: Airbill #: 6263 9006 How many? 1 Properly Completed? Pt. Storkersen #1 COMMENTS: Desigñated. person initial here to acknowledge receipt: Temperature: 3/2312004 AH Order #: A0403205 Signature: ()W\n, +Jtin,,, ~ ~ Yes 8 N/A Location: lid Carrier Name: Other Seal Name: JP Yes Signed by AEl employee? Yes Date: 5-f~/ð'1' 4.0 Pï~ B. LOQ-In Phase: SampleS Log-in Date: 3/2312004 Log-in By: AH Signature: ().l"t\"'f ~ ~~ 1. Packln.9 Type: 2~ Weré samples in separate 'bags? 3. Were containers intact? 4. Number of bottles received: 5. Correct containers Used? 6. Sufficient sa~ple volume? Bubblewrap Yes Yes 8 Yës Labels agree with COO? Number of samples received: Yes Correct pre$ervatives. added? 7. Bubbles in VOA samples? N/A 8. Was Project manager called and status discussed? 9. 'Was anyone'called? No Who was called? CÒNlMENTS: No By whom? Date: Page 1 of ( Analytica International, Inc. 5761 Silverado Way, Unit N Anchorage, AK 99518 Phone: 907-258-2155 Fax: 907-258-6634 ANf\LYTICA Environmental Laboratories 4/5/2004 CH2M Hill of Alaska 301 W. Northern Lights Suite 601 Anchorage, AK. 99503 Attn: Rob Crotty Work Order #: A0403204 Date: 4/5/2004 Work ID: Pt. Storkersen #1 Date Received: 3/22/2004 Sample Identification Lab Sample Number A0403204-01 A0403204-03 A0403204-05 Client Description SFP-16D SFP-09 PS-GP-07 Lab Sample Number A0403204-02 A0403204-04 Client Description SFP-16 Trip Blank Enclosed are the analytical results for the submitted sample(s). Please review the CASE NARRATIVE for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided at the end of the report. Sincerely, Jason Gray Project Manager "The Science of Analysis, The Art of Service" Case Narrative Analytiea Alaska Inc. Work Order: A0403204 Samples were prepared and analyzed by EPA or equivalent methods outlined in the following references: Test Methods for Evaluating Solid Waste, USEPA SW-846, Third Ed., Rev. 4, Dec. 1996. SAMPLE RECEIPT: Samples for Pt.Storkensen were received at Analytica-Anchorage (ADEC Laboratory Approval Number: UST-014) on 3/22/2004 at a temperature of 3.0°C. Samples were received in good condition and in order per chain of custody. DRO samples from this delivery were included on expedited report A0403197. Samples for 8270 SVOC were transferred for analysis at Analytica Environmental C Laboratories (AEL); 12189 Pennsylvania St. Thornton, CO 80241 where they were received at a temperature of 3.SoC in good condition and in order per chain of custody. Custody seals were not present on the cooler when received by the laboratory. REVIEW FOR COMPLIANCE WITH ANALYTICA QA PLAN A summary of our review is shown below, organized by test: Test Method: Aromatic VOCs by GC/FID via method 8021B HOLDING TIMES: Holding times were met for this Test. INSTRUMENT CALIBRATIONS: Initial calibration and CCV samples met method criteria. SURROGATE RECOVERIES: Sample SFP-09 had low recovery for BFB field surrogate, likely due to excessive sample matrix that was collected relative to the methanol p~eservative volume utilized to preserve this sample and due to high moisture content of the sample. There were no other surrogate outliers. METHOD BLANK OUTLIERS: There were no MB outliers. LCS/LCSD OUTLIERS: There are no LCS/LCSD outliers. Test Method: SW8270C - Semivolatile Organics by GC/MS - PAH - Solid HOLDING TIMES: Holding times were met for this Test SAMPLE PREPARATION ISSUES AND OBSERVATIONS: There were no unusual observations. INSTRUMENT PERFORMANCE CHECKS: Instrument checks were within method criteria. INITIAL CALIBRATIONS: Initial calibrations were within method 'criteria. ( Case Narrative Analytica Alaska Inc. . Work Order: A0403204 (continued) ( OPENING CONTINUING CALIBRATIONS: A few of the targets show %D values greater than 20% in the opening CCV shown below~ The CCC's and the SPCC's are in control. The average %D in the.CCV is less than 15%. Thus this CCV meets criteria. The results out of the 20% window are.shown below. RunDate 4/2/2004 4/2/2004 4/2/2004 4/2/2004 Data File 04040125.D 04040125.D 04040125.D 04040125.D 1:37:00 AM 1:37:00 AM 1:37:00 AM 1:37:00 AM Analyte Benzo(g,h,i)perylene D14-Terphenyl Indeno(1,2,3-cd)pyrene Pyrene CLOSING CONTINUING CALIBRATIONS: There is a CCC out of limits in the closing CCV, as shown below. that closing CCVs meet criteria for internal standard analytical The calibration standard information is included to indicate the system degradation caused by the analysis of the samples. There consequences for data usability. . Run Date 4/2/2004 10:43:00 AM 4/2/2004 10:43:00 AM 4/2/2004 10:43:00 AM Data File 04040141.D 04040141.D 04040141.D Analyte D14-Terphenyl Fluoranthene Pyrene INTERNAL STANDARD AREAS: There were no Internal Standard outliers. SURROGATE RECOVERIES: Th~re were no surrogate outliers. METHOD BLANK OUTLIERS: There are no method blank outliers. Recovery 74.7 129. 77.9 126. LCL 80 80 80 80 DCL 120 120 120 120 SW-846 does not require methods such as these. degree of analytical are no negative Recovery LCL 140. 80 -C 77.7 80 138. 80 0 LCS OUTLIERS: The LCS shown below have a number of targets outside of control windows. UCL 120 120 120 Type BatchNumber Analyte Recovery LCL UCL Status LCS T040326008 Fluorene 56.2 58 130 Complete LCS T040326008 Anthracene 57.1 59 131 Complete LCS T040326008 Benzo(g,h,i)perylene 35.2 50 125 Complete LCS T040326008 Benzo (a) anthracene 54.2 58 118 Complete MS/MSD and DUP OUTLIERS: The matrix spike and matrix spike duplicate recoveries shown below indicates a possible matrix effect. Type Client MS SFP-16D MS SFP..,.16D MS SFp:"'16D MS SFP-16D MS SFP-16D MS SFp:"'16D Sample LabSample A0403204-01B A0403204-01B A0403204-01B A0403204-01B A0403204-01B. A0403204-01B Analyte Naphthalene Anthracene Fluoranthene Benzo(a)anthracene Chrysene . Benzo(g,h,i)perylene Recovery 42.9 54.7 46.3 50.7 49.9 40.9 LCL UCL Parent 45 136 2880 59 131 0.00 51 140 0.00 58 ,118 0.00 55 139 0.00 50 125 0.00 Spike 4500 4500 4500 4500 4500 4500 MS SFP-160 MS SFP-160 MSO SFP-160. MSO SFP-160 MSO SFP-160 MSO SFP-160 MSO SFP-160 MSO SFP-160 A0403204-01B A0403204-01B A0403204-01B A0403204-01B A0403204-01B A0403204-01B A0403204-01B A0403204-01B Case Narrative Analytica Alaska Inc. Work Order: A0403204 (continued) Benzo(g,h,i)perylene 40.9 Fluorene 51.7 Fluorene 53.0 Anthracene 54.6 Fluoranthene 42.0 Benzo(a)anthracene 49.5 Chrysene 51.0 Benzo(g,h,i)perylene 34.4 50 58 58 59 51 58 55 50 125 130 130 131 140 118 139 125 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 4500 4500 4500 4500 4500 4500 4500 4500 ( Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Sample Name: None Client Sample Report SFP-l6D ~ Collection Date: 3/20/2004 9:30:00AM Client Project Number: Report Section: Matrix: Soil Thefollowing test was conducted by: Analytica - Anchorage Lab Sample Number: A0403204-01A Prep Date: 3/23/2004 Analytical Method ID: Aromatic VOCs by GCIFID via method 802lB - BTEX Prep Method ID: 5035 Prep Batch Number: A040323006 Report Basis: Dry Weight Basis Sample prep wt./vol: 39.54 g Analyst Initials: Prep Extract Vol: 3/23/2004 1:19:00PM Natasha N4032307.D 1 63 SG 25.00 ml Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analvte CASNo Result Flat!s Units POL MDL Benzene 71-43-2 ND mg/Kg 0.027 0.0030 Ethy1benzene 100-41-4 0.67 mg/Kg 0.027 0.0028 Toluene 108-88-3 0.062 mg/Kg 0.027 0.0037 0 Xylenes, Total 1330-20-7 4.2 mg/Kg 0.055 0.0078 Surrot!ate CASNo Result Flat!s Units POb MDL Spike Bromofluorobenzene(PID) 1072-85-1 2.6 mg/Kg 0.68 0.086 4.3 Difluorobenzene(PID) 540.;36-3 2.1 mg/Kg 0.027 0.0034 2.1 Rerun #: 1 % Recov . LCL UCL Rerun #: 60.0 50 150 1 101 50 150 The following test was conducted by: Analytica - Thornton Lab Sample Number: A0403204-01B Analysis Date: 4/2/2004 5:45:00AM Prep Date: 3/26/2004 Instrument: MSIBNA Analytical Method ID: SW8270C - Semivolatile Organics by GCIMS- P AH File Name: 04040 132.D Prep Method ID: 3550B Dilution Factor: 1 Prep Batch Number: T040326008 Percent Moisture 63 Report Basis: Dry Weight Basis Analyst Initials: bs Sample prep wt./vol: 30.02 g Prep Extract Vol: 2.00 ml Analvte CASNo ~ Flat!s Units POL .MI!L Rerun #: Acenaphthene 83-32-9 ND ug/Kg 450 70 1 Anthracene 120-12-7 ND ug/Kg 450 71 Benzo(a)anthracene 56-55-3 ND ug/Kg 450 46 Benzo(a)pyrene 50-32-8 NP ug/Kg 450 52 Benzo(b )fluoranthene 205-99-2 ND ~g/Kg 450 62 Chrysene 218-01-9 ND ug/Kg 450 50 Dibenzo( a,h)anthracene 53-70-3 ND ug/Kg 450 140 Fluorene 86-73-7 ND ug/Kg 450 67 Indeno( 1 ,2,3-cd)pyrene 193-39-5 ND ug/Kg 450 130 Naphthalene 91-20-3 2,900 ug/Kg 450 54 Pyrene 129-00-0 ND ug/Kg '450 75 Surrot!ate CASNo Result Flat!s Units POL MDL Spike % Recov LCL UCL Rerun #: 2-Fluorobiphenyl 321-60-8 3,700 ug/Kg 450 55 6,800 55.3 36 121 1 D 14- Terphenyl 92-94-4D 4,600 ug/Kg 450 55 6,800 68.0 . 30 134 D5-Nitrobenzene 98-95-3D 3,600 ug/Kg 450 68 6,800 52.7 30 122 Page 50f 22 Detailed Analytical Report Workorder (SDG): A0403204 Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: Report Section: None Client Sample Report ISFP-16 ~ Collection Date: Client Sample Name: Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403204-02A Prep Date: 3/23/2004 Analytical Method ID: Aromatic VOCs by GC/FID via method 802lE - BTEX Prep Method ID: 5035 Prep Batch Number: A040323006 Report Basis: Dry Weight Basis Sample prep wt.lvo1: 41.23 g Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep E~tract Vol: Analvte CASNo Result FIa!!s Units POL MDL Benzene 71-43-2 ND mg/Kg 0.027 0.0030 Ethylbenzene 100-41-4 0.70 mg/Kg 0.027 0.0028 Toluene 108-88-3 0.056 mg/Kg 0.027 0.0036 Xylenes, Total 1330-20-7 4.3 mg/Kg 0.054 0.0077 Surroeate ,) CASNo ' Result Fla!!s Units POL MDL Spike % Recov Bromofluorobenzene(PID) 1072-85-1 2.8 mg/Kg 0.67 0.084 4.2 66.2 Difluorobenzene(pID) 540-36-3 2.2 mg/Kg 0.027 0.0034 2.1 103 3120/2004 9:25:00AM 3/23/2004 1 :48:00PM Natasha N4032308.D 1 64 SG 25.00 m1 Rerun #: I 0 LCL UCL Rerun #: 50 150 I 50 150 . The following test was conducted by: Analytica - Thornton Lab Sample Number: A0403204-02B Analysis Date: 4/2/2004 7:31:00AM Prep Date: 3/26/2004 Instrument: MSIBNA Analytical Method ill: SW8270C - Semivolatile Organics by GC/MS - P AH File Name: 04040135.D Prep Method ID: 3550B Dilution Factor: 1 Prep Batch Number: T040326008 Percent Moisture 64 Report Basis: Dry Weight Basis Analyst Initials: bs Sample prep wt.lvol: 30.05 g Prep Extract Vol: 2.00 ml Analvte CASNo Result FIa!!s Units POL MDL Rerun #: Acenaphthene 83-32-9 ND ug/Kg 470 71 1 Anthracene 120-12-7 ND ug/Kg 470 73 Benzo(a)anthracene 56-55-3 ND ug/Kg 470 47 Benzo(a)pyrene 50-32-8 ND ug/Kg 470 53 Benzo(b )fluoranthene 205-99-2 ND ug/Kg 470 64 Chrysene 218-01-9 ND ug/Kg 470 51 Dibenzo(a,h)anthracene 53-70-3 ND ug/Kg 470 140 Fluorene 86-73-7 ND ug/Kg 470 69 Indeno(l ,2,3-cd)pyrene 193-39-5 ND ug/Kg 470 130 Naphthalene 91-20-3 3,600 ug/Kg 470 55 Pyrene 129-00-0 ND ug/Kg 470 76 Surroeate CASNo Result FIa!!s Units POL MDL Spike % Recov LCL VCL ReÌ'1In #: 2-Fluorobipheny1 321-60-8 4,500 ug/Kg 470 56 6,900 65.6 36 121 1 Dl4-Terphenyl 92-94-4D 6,200 ug/Kg 470 56 6,900 89.8 30 134 D5-Nitrobenzene 98-95-3D 4,400 ug/Kg 470 70 6,900 63.7 30 122 Page 6 of 22 i( Detailed Analytical Report VVorkorder (SDG): A0403204 Project: Pt. Storkersen #1 Cli~nt: CH2M Hill of Alaska ( Analytica Alaska Inc. Client Project Number: Report Section: Client Sample Name: None Client Sample Report ISFP-09 , Collection Date: Matrix: " Soil The followmg test was conducted by: Analytica - Anchorage Lab Sample Number: A0403204-03A Prep Date: 3/23/2004 Analytical Method ID: Aromatic VOCs by GCfFID via method 8021B - BTEX Prep Method ID: 5035 Prep Batch Number: A040323006 Report Basis: Dry Weight Basis Sample prep wt.lvol: 55.32 g Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: 3/19/2004 10:40:00AM 3/23/2004 2:17:00PM Natasha N4032309.D 1 68 SG 25.00 ml ~ Rerun #: 1 Analvte CASNo Result Fla!!s Units POL MDL Benzene 71-43-2 0.031 mg/Kg 0.022 0.0025 Ethylbenzene 100-41-4 0.74 mg/Kg 0.022 0.0023 Toluene 108-88-3 0.080 mg/Kg 0.022 0.0030 Xylenes, Total 1330-20-7 6.1 mg/Kg 0.045 0.0064 Surroeate CASNo Result Fla!!s Units POL MDL Spike % Recov Bromofluorobenzene(PID) 1072-85-1 1.5 mg/Kg 0.56 0.070 3.5 44.3 Difluorobenzene(PID) 540-36-3 1.7 mg/Kg 0.022 0.0028 1.7 97.2 The following test was conducted by: Analytica - Thornton Lab Sample Number: A0403204-03B Analysis Date: 4/2/2004 8:06:00AM Prep Date: 3/26/2004 Instrument: MSIBNA Analytical Method ID: SW8270C - Semivolatile Organics by GC/MS - P AH File Name: 04040 136.D Prep Method ID: 3550B Dilution Factor: 1 Prep Batch Number: T040326008 Percent Moisture 68 r" Report Basis: Dry Weight Basis Analyst Initials: bs I Sample prep wt.lvol: 30.00 Prep Extract Vol: 2.00 m1 g Analvte ~ !!m!!! Fla!!s Units POL~ Rerun #: Acenaphthene 83-32-9 ND ug/Kg 520 79 1 Anthracene 120-12-7 ND ug/Kg 520 81 Benzo(a)anthracene 56-55-3 ND ug/Kg 520 52 Benzo(a)pyrene 50-32-8 ND ug/Kg 520 59 Benzo(b )fluoranthene 205-99-2 ND ug/Kg 520 71 Chrysene 218-01-9 ND ug/Kg 520 57 Dibenzo(a,h)anthracene 53-70-3 ND ug/Kg 520 160 Fluorene 86-73-7 ND ug/Kg 520 76 Indeno( 1 ,2,3-cd)pyrene 193-39-5 ND ug/Kg 520 140 Naphthalene 91-20-3 220 J ug/Kg 520 62 Pyrene 129-00-0 ND ug/Kg 520 85 Surroeate CASNo Result Fla!!s Units POL M!lli Spike % Recov LCL UCL Rerun #: 2-Fluorobiphenyl 321-60-8 5,100 ug/Kg 520 62 7,700 66.0 36 121 1 D 14- Terphenyl 92-94-4D 6,300 ug/Kg 520 62 7,700 82.5 30 134 D5-Nitrobenzene 98-95-3D 5,500 ug/Kg 520 78 7,700 70.9 30 122 Page 7 of 22 LCL UCL Rerun #: 50 Ì50 1 LOW 50 150 Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Name: Method Blank Report 1MB Matrix: Solid The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040323006-MB Prep Date: P 3/23/2004 Analytical Method ill: Aromatic VOCs by GC/FID via method 8021B - BTEX Prep Method ID: 5035 Prep Batch Number: A040323006 Report Basis: Dry Weight Basis Sample prep wt.lvol: 25.00 g Analytica Alaska Inc. ~ Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: Analvte CASNo Result Fla!!s Units POL MDL Benzene 71-43-2 ND mgIKg 0.016 0.0018 :) Ethylbenzene 100-41-4 ND mgIKg 0.016 0.0016 Toluene 108-88-3 ND mgIKg 0.016 0.0021 Xylenes, Total 1330-20-7 ND mgIKg 0.032 0.0046 Surroe:ate CASNo :) Result Fla!!s UnÏts POL MDL Spike % Recov Bromofluorobenzene(PID) 1072-85-1 2.9 mgIKg 0.40 0.050 2.5 117 Difluorobenzene(PID) 540-36-3 1.3 mgIKg 0.016 0.0020 1.3 103 The following test was conducted by: Analytica - Thornton Lab Sample Number: T040326008-MB Prep Date: 3/26/2004 Analytical Method ill: SW8270C - Semivolatile Organics by GC/MS - P AH Prep Method ID: 3550B Prep Batch Number: T040326008 Report Basis: Dry Weight Basis Sample prep wt.lvol: 30.02 g Analvte CASNo ~ Fla!!s !!!!!!! Acenaphthene 83-32-9 ND ugIKg Anthracene 120-12-7 ND ugIKg Benzo(a)anthracene 56-55-3 ND ugIKg Benzo(a)pyrene 50-32-8 ND ugIKg Benzo(b )fluoranthene 205-99-2 ND ugIKg Chrysene 218-01-9 ND ugIKg Dibenzo( a,h)anthracene 53-70-3 ND ugIKg Fluorene 86-73-7 ND ugIKg Indeno(1.2,3-cd)pyrene 193-39-5 ND ugIKg Naphthalene 91-20-3 ND ugIKg Pyrene 129-00-0 ND ugIKg Surroe:ate CASNo Result Flae:s Units 2-Fluorobiphenyl 321-60-'8 1,900 ugIKg D 14- Terphenyl 92-94-4D 2,300 ugIKg D5-Nitrobenzene 98-95-3D 1,700 ugIKg Page 10 of22 POL MDL 170 26 170 26 170 17 170 19 170 23 170 18 170 51 170 25 170 47 170 20 170 28 POL' 170 170 170 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: MDL Spike 20 2,500 20 2,500 25 2,500 % Recov 75.6 90.5 66.2 3/23/2004 12:00:00AM 3/23/2004 10:11:00AM Natasha N4032304.D 1 NA SG 25.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 50 150' 4/1/2004 9: 16:00PM MSIBNA 04040117.D 1 NA bs 2.00 m1 Rerun #: 1 LCL UCL Rerun #: 36 121 1 30 134 30 122 ( Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Analytica Environmental Laboratories, Inc. None Tests Run at: Analytica Environmental Laboratories - Anchorage, Alaska W orkorder (SDG): A0403204 Project: Pt. Storkersen #1 Project Number: Prep Batch: Analysis: MB Anal. Date: LCS Anal. Date: Analyte Name Benzene Toluene Ethylbenzene Xylenes, Total QUALITY CONTROL REPORT A040323006 ') LCS/LCSD REPORT Aromatic VOCs by GC/FID via method 8021B - BTEX MB: Prep Date: 3/23/2004 10: 11 :OOAM Units: 3/23/2004 10:40:00AMLCSD Anal. Date: 3/23/2004 11 : 09: OOAM Matrix: A040323006-MB 3/23/2004 mglKg Solid 0 SampResult LCSRes. SDRes. SPLev SPDLev Recov. SD Recov RPD Recov Lim RPDLim Flag ND 0.372 0.372 0.345 0.345 107.9 107.9 0.0 60 - 120 20 ;) ND 2.19 2.11 2.11 2.11 103.6 99.9 3.7 60 - 120 20 ND 0.565 0.542 0.507 0.507 111.4 106.9 4.2 600 120 20 ND 2.89 2.78 2.48 2.48 116.6 112.1 3.9 60 - 120 20 FOOTNOTES TO QC REPORT Note 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement, variability of the sample result itself. Note 3: For sample duplicates, if the result is less than the PQL, the duplicate RPD is not applicable. If the sample and duplicate results are not five times t~e PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. . Note 4: For serial dilutions, ifthe result is less than the PQL, the duplicate RPD is not applicable. If the sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 11 of 22 Detailed Analytical Report Workorder (SDG): A0403204 Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Tests Run at: Analytica Environmental Laboratories - Thornton, Colorado Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Project Number: Prep Batch: T040326008 Analytica Environmental Laboratories, Inc. QUALITY CONTROL REPORT Analysis: LCS REPORT SW8270C - Semivolatile Organics by GC/MS - P AH MB Anal. Date: LCS Anal. Date: Analyte Name Naphthalene Acenaphthene Fluorene Anthracene Pyrene Benzo( a)anthracene Chrysene Benzo(b )fluoranthene Benzo( a)pyrene Indeno( 1 ,2,3-cd)pyrene Dibenzo( a, h) anthracene 4/1/2004 9:16:00PM 4/1/2004 9:51 :OOPM SampResult ND ND ND ND ND ND ND ND ND ND ND LCSRes. 881 899 936 952 1,010 903 944 956 980 832 902 SPLey 1,670 1,670 1,670 1,670 1,670 1,670 1,670 1,670 1,670 1,670 1,670 Recoy. 52.9 54.0 56.2 57.1 60.6 54.2 56.7 57.4 58.8 49.9 54.1 Analysis: MS/MSD REPORT SW8270C - Semivolati1e Organics by GC/MS - P AH MB: Prep Date: Units: Matrix: Parent: Prep Date: Units: Matrix: Samp. Anal. Date: 4/2/2004 5:45:00AM MS Anal. Date: 4/2/2004 6:20:00AM MSD Anal. Date: 4/2/2004 6:56:00AM Analyte Name Naphthalene Acenaphthene Fluorene Anthracene Pyrene Benzo( a)anthraeene Chrysene Benzo(b )fluoranthene Benzo( a)pyrene Indeno(I,2,3-ed)pyrene Page 12 of22 SampResult 2,880 ND ND ND ND ND ND ND ND ND MSRes. 4,820 2,340 2,330 2,460 2,860 2,280 2,250 2,330 2,500 2,730 MSDRes SPLey 5,390 4,500 2,400 4,500 2,390 4,500 2,460 4,500 3,270 4,500 2,230 4,500 2,300 4,500 2,320 4,500 2,440 4,500 2,820 4,500 SPDLey Reeoy. 4,500 4,500 4,500 4,500 4,500 4,500 4,500 4,500 4,500 4,500 MSD Ree. RPD Reeoy Lirn RPDLirn 55.7 11.2 45 - 136 40 lowMS 53.3 2.5 43 - 122 40 53.1 2.5 58 - 130 40 /owMS lowMSD 54.6 0.0 59 - 131 40 lowMS lowMSD 72.6 13.4 46 - 135 40 49.5 2.2 58 - 118 40 lowMS lowMSD 51.1 2.2 55 - 139 40 lowMS lowMSD 51.5 0.4 41 - 133 40 54.2 2.4 40 - 138 40 62.6 3.2 48 - 125 40 43.1 52.0 51.7 54.6 63.5 50.6 50.0 51.7 55.5 60.6 T040326008-MB 3/26/2004 uglKg Solid Reeoy Lirn RPDLirn Flal! 45 - 136 43 - 122 58 - 130 59 - 131 40 - 127 58 - 118 55 - 139 41 - 133 40 - 138 48 - 125 50 - 129 low low low A0403204-01B 3/26/2004 uglKg Soil Flag: ( Detailed Analytical Report Workorder (SOO): A0403204 Project: pt. StorkerSen #1 Client: CH2M Hill of Alaska Client Project Number: None Tests Run at: Analytica EnVironmental Laboratories - Thornton, Colorado W orkorder (SDG): A0403204 Project: Pt. Storkersen #1 Project Number: . Prep Batch: Analytica Environmental Laboratories, Inc. QUALITY CONTROL REPORT T040326008 Analysis: MS/MSD REPORT SW8270C - Semivolatile Organics by GC/MS - P AH Parent: Prep Date: Units: Matrix: Samp. Anal. Date: 4/2/2004 5:45:00AM MS Anal. Date: 4/2/2004 6:20:00AM MSD Anal. Date: 4/2/2004. 6:56:00AM A0403204-01B 3/26/2004 ug/Kg Soil Analyte Name SampResult Dibenzo( a,h)anthracene ND MSRes. MSDRes SPLev SPDLev Recov. MSD Rec. RPD Recov Lim RPDLim 2,750 2,810 4,500) 4,500 61.1 62.4 2.2 50 - 129 40 Flag FOOTNOTES TO QC REPORT :) Note 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result. . should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. Note 3: For sample duplicates, ifthe result is less than the PQL, the duplicate RPD is not applicable. If the sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for othermanices. . Note 4: For serial dilutions, ifthe result is less than the PQL, the duplicate RPD is not applicable. If the sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 13 of22 Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Tests Run at: Analytica Environmental Laboratories - Thornton, Colorado W orkorder (SDG): A0403204 Project: Pt. Storkersen #1 Project Number: Prep Batch: Analytica Environmental Laboratories, Inc. QUALITY CONTROL REPORT T040326010 Analysis: ASTM D2216 - Pmoist SAMPLE DUPLICATE REPORT Base Sample:A0403204-01B Prep Date: 3/26/2004 Samp.. Anal. Date: 3/27/2004 8:58:06AM DUP Anal. Date: 3/27/2004 8:58:06AM Units: Matrix: % Soil Analyte Name Moisture SampResult DUPRes. 63.0 62.1 RPD 1.4 RPDUm 20 Flag FOOTNOTES TO QC REPORT . ~ N ate 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. Note 3: For sample duplicates, ifthe result is less than the PQL, the duplicate RPD is not applicable. If the sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Note 4: For serial dilutions, ifthe result is less than the PQL, the duplicate RPD is not applicable. If the sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 14 of22 Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None SURROGATE RECOVERY SUMMARY REPORT Page 15 of22 ( Analytica Environmental Laboratories, Inc. 0 0 Detailed Analytical Report Analytica Environmental Laboratories, Inc. W orkorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Test Method: Aromatic VOCs by GCIFID via method 8021B - BTEX Lab Sample #: A0403204-01A Dilution: 25 Analysis Date: 3/23/2004 1: 19:00PM Client Sample: SFP-16D Batch Number: A040323006 Data File: N4032307.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pID) 60 50 150 Complete Difluorobenzene(pID) 101 50 150 Complete Lab Sample #: A0403204-02A Dilution: 25 Analysis Date: 3/23/2004 1:48:00PM Client Sample: SFP-16 Batch Number: A040323006 Data File: N4032308.D AnalvteN ame SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pID) 66 50 150 Complete Difluorobenzene(pID) 103 50 150 Complete Lab Sample #: A0403204-03A Dilution: 25 Analysis Date: 3/23/2004 2: 17:00PM Client Sample: SFP-09 ') Batch Number: A040323006 Data File: N4032309.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pTID) 44 50 150 LOW Complete Difluorobenzene(PID) 97 50 150 Complete Lab Sample #: A0403204-05A Dilution: 25 Analysis Date: 3/23/2004 2:46:00PM Client Sample: PS-GP-07 Batch Number: A040323006 Data File: N4032310.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pTID) 88 50 150 Complete Difluorobenzene(pID) 104 50 150 Complete Lab Sample #: A0403204-04A Dilution: 25 Analysis Date: 3/23/2004 3:15:00PM Client Sample: Trip Blank Batch Number: A040323006 Data File: N4032311.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pID) 111 50 150 Complete Difluorobenzene(pID) 99 50 150 Complete Lab Sample #: A040323006-MB Dilution: 25 Analysis Date: 3/23/2004 10: 11 :OOAM Client Sample: MB Batch Number: A040323006 Data File: N4032304.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pTID) 117 60 120 Complete Difluorobenzene(pID) 103 . 60 120 Complete Lab Sample #: A040323006-LCS Dilution: 25 Analysis Date: 3/23/2004 10:40:00AM Client Sample: LCS Batch Number: A040323006 Data File: N4032305.D AnalvteName SSRecov LCL VCL SSFlae Result Status Bromofluorobenzene(pTID) 103 60 120 Complete Difluorobenzene(pTID) 87 60 120 Complete Page 16 of22 ( Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CB2M Bill of Alaska Client Project Number: None Test Method: Aromatic VOCs by GCIFID via method 8021D - DTEX Lab Sample #: A040323006-LCSD Dilution: Analysis Date: 3/23/2004 11 :09:00AM Client Sample: Batch Number: A040323006 Data File: AnalvteName SSRecov ,LCL UCL Bromofluorobenzene(pID) 100 60 120 Difluorobenzene(pID) 84 60 120 Analytica Environmental Laboratories, Inc. Page 17 of22 25 LCSD N4032306.D SSFIae; Result Status Complete Complete ':> 0 Detailed Analytical Report Analytica Environmental Laboratories, Inc. Workorder (~DG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Test Method: SW8270C - Semivolatile Organics by GCIMS - PAD Lab Sample #: A0403204-01B Dilution: 1 Analysis Date: 4/2/2004 5:45:00AM Client Sample: SFP-16D Batch Number: T040326008 Data File: 04040132.D AnalvteName SSRecov LCL DCL SSFlag Result Status 2-Fluorobiphenyl 55 36 121 Complete D14-Terphenyl 68 30 134 Complete D5-Nitrobenzene 53 30 122 Complete Lab Sample #: A0403204-02B Dilution: Analysis Date: 4/2/2004 7 :31 :OOAM Client Sample: SFP-16 Batch Number: T040326008 Data File: 04040135.D AnalvteN ame SSRecov LCL UCL SSFlag Result Status 2- Fluorobiphenyl 66 36 121 Complete D14-Terphenyl 90 30 134 Complete :; D5-Nitrobenzene 64 30 122 Complete Lab Sample #: A0403204-03B Dilution: ~ Analysis Date: 4/2/2004 8:06:00AM Client Sample: SFP-09 Batch Number: T040326008 Data File: 04040136.D AnalvteName SSRecov LCL DCL SSFlag Result Status 2-Fluorobiphenyl 66 36 121 Complete D14-Terphenyl 83 30 134 Complete D5-Nitrobenzene 71 30 122 Complete Lab Sample #: A0403204-05B Dilution: 1 Analysis Date: 4/2/2004 8:41 :OOAM Client Sample: PS-GP-07 Batch Number: T040326008 Data File: 04040137.D AnalvteN ame SSRecov LCL UCL SSFlag Result Status 2-Fluorobiphenyl 67 36 121 Complete D14-Terphenyl 95 30 134 Complete D5- Nitrobenzene 121 30 122 Complete Lab Sample #: T040326008-MB Dilution: Analysis Date: 4/1/2004 9:16:00PM Client Sample: MB Batch Number: T040326008 Data File: 04040117.D AnalvteName SSRecov LCL DCL SSFlag Result Status 2- Fluorobiphenyl 76 36 121 Complete D14-Terphenyl 91 30 134 Complete D5- Nitrobenzene 66 30 122 Complete Lab Sample #: T040326008-LCS Dilution: Analysis Date: 4/1/2004 9:51 :OOPM Client Sample: LCS Batch Number: T040326008 Data File: 040401l8.D AnalvteName SSRecov LCL DCL SSFlag Result Status 2-Fluorobiphenyl 70 36 121 Complete D 14- T erphenyl 84 30 134 Complete D5-Nitrobenzene 68 30 122 Complete' Page 18 of22 ( Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Test Method: SW8270C - Semivolatile Or~anics by GC/MS - PAD Lab Sample #: A0403204-01B-MS Dilution: Analysis Date: 4/2/2004 6:20:00AM Client Sample: Batch Number: T040326008 Data File: AnalvteName SSRecov LCL DCL 2-Fluorobiphenyl 64 36 121 D14-Terphenyl 81 30 134 D5-Nitrobenzene 62 30 122 ( Analytica Environmental Laboratories, Inc. MS 04040133.D SSFJa2 Result Status Complete Complete Complete SSRecov 70 94 67 LCL 36 30 30 Dilution: Client Sample: MSD Data File: 04040134.D DCL SSFlag 121 134 122 Result Status Complete Complete Complete Lab Sample #: Analysis Date: Batch Number: AnalvteName 2- Fluorobiphenyl D 14- Terphenyl D5- Nitrobenzene A0403204-01B-MSD 4/2/2004 6:56:00AM T040326008 ø Page 19 oi22 Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Lab Project ID: Lab Method Blank Id: Prep Batch ID: Method: Analytica Environmental Laboratories, Inc. None QC BATCH ASSOCIATIONS - BY METHOD BLANK 26,234 A0403204 Lab Project Number: Prep Date: 3/23/2004 A040323006-MB A040323006 Aromatic VOCs by GC/FID via method 8021B - BTEX This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A040323006-LCS A040323006-LCSD A0403204-0 lA A0403201-02A A0403204-03A A0403204-05A A0403204-04A LCS LCSD SFP-16D SFP-16 SFP-09 PS-GP-07 Trip Blank 3/23/2004 10:40:00AM 3/23/2004 11 :09:00AM 3/23/2004 1: 19:00PM 3/23/2004 1 :48:00PM 3/23/2004 2: 17:00PM 3/23/2004 2:46:00PM' 3/23/2004 3:15:00PM :) N4032305.D N4032306.D N4032307.D N4032308.D N4032309.D N4032310.D N4032311.D Prep Date: 3/26/2004 Lab Method Blank Id: T040326008-MB Prep Batch ID: T040326008 . Method: SW8270C - Semivolatile Organics by GCfMS - P AH This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalvsisDate T040326008-LCS LCS 04040118.D 4/1/2004 9:51:00PM A0403204-01B SFP-16D 04040132.D 4/2/2004 5:45:00AM A0403204-01B-MS MS 04040 133.D 4/2/2004 6:20:00AM A0403204-0 IB-MSD MSD 04040 134.D 4/2/2004 6:56:00AM A0403204-02B SFP-16 04040135.D 4/2/2004 7:31:00AM A0403204-03B SFP-09 040401 36.D 4/2/2004 8:06:00AM A0403204-05B PS-GP-07 040401 37.D 4/2/2004 8:41:00AM Lab Method Blank Id: Prep Batch ID: Method: Prep Date: 3/26/2004 T0403260 1 O-MB T040326010 ASTM D2216 - Pmoist This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A0403204-01B SFP-16D 3/27/2004 A0403204-02B SFp.16 3/27/2004 A0403204-03B SFp.09 3/27/2004 A0403204-05B PS-GP-07 3/27/2004 A0403204-01B-DUP DUP 3/27/2004 Page 20 of 22 8:58:06AM 8:58:06AM 8:58:06AM 8:58:06AM 8:58:06AM (' Detailed Analytical Report Workorder (SDG): A0403204 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska . Analytica Environmental Laboratories, Inc. Client Project Number: None DATA FLAGS AND DEFINITIONS The PQL is the Method Quantitation Limit as defined by USACE. . Reporting Limit Limit below which results are shown as "ND". This may be the PQL, MDL, or a value between. See the report conventions below. Result Field: 0 ND = Not Detected at or above the Reporting Limit NA = Analyte not applicable (see Case Narrative for discussion) Qualifier Fields: LOW = Recovery is below Lower Control Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E = Reported concentration is above the instrument calibration upper range Organic Analysis Flags: 0 B = Analyte was detected in the laboratory method blank: J = Analyte was detected above MDL or Reporting Limit but below the Quant Limit (PQL) 0 Inorganic Analysis Flags: J = Analyte was detected above the Reporting Limit but below the Quant Limit (PQL) W = Post digestion spike did not meet criteria . S = Reported value determined by the Method of Standard Additions (MSA) Other Flags may be applied. See Case Narrative for Description r ' l Page 21 of22 Detailed Analytical Report Workorder (SDG): A0403204 Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Analytica Environmental Laboratories, Inc. REPORTING CONVENTIONS FOR TmS REPORT A0403204 TestPkf!Name 8021/5035 (Solid) - BTEX c 8270C/3550B (Solid) - P AH ASTMD2216/ASTMD2216 (Solid) - Pmoist Page 22 of 22 Basis Dry Weight Basis Dry Weight Basis As Received # Sif! Fif!s 2 2 3 Reportinf! Limit Report to PQL Report to MDL, J qual below PQL Report to MDL, J qual below PQL ) \ ~ n--{ r- , " ¡ ~r"'''' ~--: h, - .;/ , .. ~ f\!1(J¿t::.> , AI¿ff? I v 7'/ N~ 3 " 6 ;3 6 (7 r I,ç-ú -s£. d \ '-)CLf-f) w (hle, Ioe\h CÀ ,'Ó I or ~~,~./~\! ~."1S~-,,-- _-.~'"--_./ l.C,1'1 rOt:- ~IZ-" N\ 1 AI,..,. ,-,_...-,.". - . '., "-"-A' ""N-----"'A'-""" "L" .. '~'T' ~ 1'- ..C' -' ..' 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Nttl.Db~'1ZX<I/ d-I At. >- ~! -I \ .J i-qo.J- 'l-::¡ß-..:.5Sf ,I ~- II.- \"J ....Q ,.Q \ ~I \ 0J ' Fax: -; r"~. 7 Ái"'-, 'g -g 0 \ 0 \ 'rv ~ :J, ~ õ õ # Containers "- \J.' ><, I ,,,,,..- Emall: Q H (; C K2!\ (.On :11:11 ~ J :i ~ \ 31 - ~U~~/ . ~ : - -~ .-- . - :-~cf<:2. \ :¡' j ¿ Sç:ç -CXo~~lfLID .' .c"-~lA.5 5 I 'x .'. :;L.~,.. --~~ S'Çç; - '0 6~2D (f.¡éD S f X r 5fr-¡bO . ó1§ð f ~ X~X tD x ~(r- l~ 1 dr¡51 Y, X -?f'P- ¡{¡; O?>.,W C5J2S " :? X 6Qx. X x: ~ X ~(f-6'1 6~1C¡ IDiD ~ X(f.;X~j. ~~~(r..,()q\?) ''', ,."', .j[Jlf) ,l, "X ,X.~-_. '. X~ StP- 0'2- "~ ~ /oo? I X ~ Sw- O~. O~~tq la~ I f X j. '0 ~ l\b (j) 1"Q\p ßLA~~ O~~10 1&')0 W, )(, 1/:0' COMMENTS . ::~l L ICA GEL CLEJ::dVUP (f}-- ~ S.Á\/'í /-)LES Þ \.f!:J C/~,LL I-Cfo1-iLtö-C(():Jl ~<..\ 'ìÚ+-2)8-L'S-:->I. G.S .~ 145 YOU ' tc..~úw Q,ëSC:/cTð ~r- D-.11 ?AÞ-IPL~ L.V\Lt:.. C?G <. 2..CúÒ(n,: 11:) "CX2D. (;0 AÞ...J AL Y"LG SF'P- O~ C\~,<:\ .-/' P..-¡~ - A"? A<7 POS'?I f?LG"'". . . NE'i2C> <. '1t..t \Je. --'\~ l\-{~\J'< ~Q\>'\- "'7íf\iV01Nb (?)'{ 'rt>r Q~0t-1""J), ép:-fTBL- =.~SH:;~ ::X::D ;~ð - iR~LJ:.:~;;BY.., ;:~. ::::~ BY: ~... Temp Received: :5. D /7 k/ á~ /~/' lirJt fjtIP7 ~ë'~ . ~ ' CÌJv\kltL \--\.itM h'~\ ~.J{ "\ P,/,:!l~,Namy: , .K , /fri~ ~ame: II ¡lpri "Namef2 Ih /1 hrinted Name: ---.. Temp Received: f?-.J ÚJl!/ . j Jr:rlJllÞ/ttl1 V ];¡~Yt;/. (fll/III ~~-- !ta~h'ìMlk"'\h-rr Coolers: t OF.IIJTI~ , . .' FI'"1J .r Firm: rrJ~ Firm: Seals: If , IJ/1/-/íLL¡" , .ll)--I . /~',G ~~n-' r'~~~ ~':;~/i - O'.í",~. (:- /ð3. ~.;' D~~e~í~moe:1 (ff / Ot'! 1'. D::¿, a~J,'¡,¡¡lin:(Je:'It? 110' (J Datel Time: Means ofpelivery I Way Bill f /' J.-r.. ,V- I...-/ ..J L - .J tK'ot' V ) 0 7' II ~ J d 0"-/ () '1 f) '. :7:/) L, 1; r () \j ~« I h 0 ( ri (;7 Tl ~t:'1y( --', .-... ~tl~ . ~ ~\'V)~ (2gv'" ' I :-- . 1 t .;. ,,-, ~ .. ,31::L":f/OI{f~Ci)~M ~. :: fi~ 1AQ(¥:: ¡ 1-1")0 Sè ,!g jg ~ /~ C ¡ -~ ~ ,~ u C) oc: CÐ ~ - ....... CI) .(: Q) ~ .t ~1:5 " , i¡ ,( ð ~ Lf fj \f ..,-,. ~ "~ -¡ ~ ~, . ~ . i !-\J26: ~'.= ¡ ':t \ t \ et) 1P\QE: ~::: IjlCcó .,., ,. -6:.1it-- -- ,'-v -' ----'~-- ,~ . .. (,,70 I . 010 Business Days <1 t-f tv\'" w{ 0 15 Business Days tT\\t\CÙ J}tvft, œr:J~ ;t:(other: , # Business Days (Prior Authorization Required.) Cooler Receipt Information ¡; .C .C III . , ,.". -":::'~":::i"'-'i,:",~:,:,.:~"I~":':':'";"":;\':;:"':":<"...:::':'\';:":";'\""':':,,,,':'. .."..,..".:.. ' . ':"""~"';:,,,' ,A,NA.lS¥17TCA ......'...'..':.."..;;;,:'"i;::)i!i ',.'~?na~i~g~U:.góm ..'.'" , .- ,., . '",: ; 81,1:;W::8ttl AVlJ"::,:: '::',' ,Ar1ç~orage;:AK,::9950'1 ," ..' (907) 258-2j5!) FAX:' (907) 258-6634 Corn~y.,'Name::'(:"~l'2,;~~~ ,H\~'~. ~~ný1;~b~!~~d ,Pr()J~t Name: \ .~.(;; : . ~,' "., ,~ ~'!..J/t;J ilL, (';;;.'" \ Report To: .:;' J- . L".., ., .,-t(~' ,.' ," '\:.. '".._, . :"". .,' i . Inv6¡ce'.To:t~~'r\Í1 \,.','$' f-'L. ". ~Þ.:~åp'bei--;¡'J1Þ\\.\.\" 01- , 13 ' ~-" "I.':.);; ,Ii ",I, jl¡~J~~ ' ,'" :~!' "r-:;;5fj ':':~2,:"1,'76:1':.~:t:/j' ,.: .';' ". ';~~:"A~U~~~;Ä.\".;~~" "'.~:~;:~j[~/D '., .-,;;' , ' ,.... . , ."1 . ,I , : 5438Sháune, Drive : JurteaÙ;ÄK 99801 ,. - (907) 78,0-6668 ' :~A~::(907) 780~6670 ::N.g::'3' .1'~t!":3' :4: .,:,'.;. , '... ~,. .. "~I: ... '\~Z"'. D'~ ~~.'... ~. ' :\..;;c ",fot:::;..(}t\ r- ',. ~..,ii" ~G~:;~,;~;3¡'19i,;;, ,..' , Quote:~i\Q::5:JdY~..'..~ .Proje:ctID #: ,,¡" ," ,,' '~ 1:.Ana,;,lysi:s:..'Re:q~ést , ' I ~ e 12189,Pennsylv,ania Street " ihornton,C080241 ' ~..... (303) 469-8868 , ,,':'..' .'.:: ...",". . ..'.' ,- . .tx: (303)469-5254 ...:.,.. 'S:.'.'.'..hal.".:' ,.'of' Custody' Record /""') "." ...... . ' \~.f....' ..' .. .;,... 'Vt. "., , ' ,~ ~ ~ ,-, ,,~:s .::!! . .n"l"'& :~~~:~ ."1"1. . . (10.. 'E' .; :i;.. ::;"',,:: :l Q' :¡". "6' >"',:~::~ ',"i:':": ',~:~:: -:"~' :Y)I,! '~ 01;( "::~, :,; ':, ~ ': '::r;,' ,..J , .. I ;), ,'J; ,..... 86 '~/:",,,,' ",", "",'",' ': :.~.,'¡....:.f.ry.....'1í\) ~'~~. '0 , ' ~ \". ..,. ~ , , ,I", t!Þ~ 1\..£ L," ~,/. '.',.' ,-,~... ' , , ., ' . ~-~~r:;~es~'~:~;':'..~~'.~,,:,0:....@ )Þoth~r. .fJ5. .... , #:lfJpsf1Jf!Ss"o.ays'~,:", , (Prior ~uthonz~t¡onfJÎiq~il8d;},-:: . . , ~ECEJV~D BY: ç~,ò!:erRl!fè;pt In'orm~~;9~, ,'.. " ",. Slgri~turfJ: "--~--..... .,.' '~'.'~~~,er:,:' ,.' ',', Q.. :.'.. .\-. . 1\ ^ ' ., '-"", . Temp Received:, .. " "': 'C",'-'.', . ... Jrl'\ 'l~.li--P'. )-rxP1CL.1 -,-- .'.,:"', ' ," ", , '. rintê'dName:' ~"- :;, , TempFleceivEfC/:':':" ~(..~' "[\C\.M~'~ hi,., i::;:~~<' ~LfJ.. , ,'.';;~!.t r(J~ ,;.m~L. .:: "''''iI'f'''~ '¡ON, B I< 191;c M£.í.-¡..t.: " *- ~ ê:' 4 ~~Ii:.~ S 'RE:~NQUJS1fçDBY.", ;', '.S' /1 .¡J'd" , ~í9f1::e:.,:, , " ~r¡'fÞ/fA. .F/~1JX([ ::" ::,' 'D;ttt:Ó'i&llOb :"., :REH~9~!$H;p',:~r:~~¥PLER: '" ' ,- ~~fð..:"'",..',, , .. . . . . "::~tJ:-N~~:,:.,:,),,,,' , "-;;g/!¿r~S2 ~~h7~e YlDù ,RECÐVEb BY:.. '.,. ifi' .'..:M' ' Sigi]átUre:/ :¡;i~1-t ' ::'4:~,:;1 gh.:,:.álpt'~~.';'~;Ã.~...'.'.' ; tJ.~""t/(II'";J'T ¡.' '" Vp " '!Î ~øflt~ç~ao/e~; ..~. !,,' - r '.",~,\~,;;',J:.,. (' .'.. 1<...'.'./'r.~ ," "J.::..I~i¡r 'f"ol_:'! ': ~.,:,!({;,~,; Fi[~'~{lbf, Date! Tïrm~:' ':"r:fc'. ;)Ve , , !}ÇO' '.' ~, -~ ,~ , . Datel Time: ?'¡.t") 1'"\ .':-~' J-l ;::';J~, ry-, ¡ , ~a. nS.~lD~l...~~e.fl f\1. ,'PJ. Y. :'~í"./~f'...~.~f't1c.. . ,,-Ot> pfJ¿ It:1P: d;': .f'" " , ,'..' , . . ('. . f~;" . .;0 t~¡ 1\ A ~YrICA ~lient: CH2M Hill of Alaska 'roject: pt. Storkersen #1 Cooler ID: 1 \. Preliminarv Examination Phase: 1. Was airbill Attached? No Yes 2. Custody Seals? 3. Seals intact? Yes 4. Screened for radiation? N/A 5. COC Attached? Yes 7. Preservative: BlueGel 6. Project Identification from custody: paper: Cooler Receipt Form Client Code: 006120 Date cooler opened: Cooler opened by: Airbill #: How many? 1 Properly Completed? pt. Storkersen #1 Temperature: . 1. COMMENTS: Designated person .initial here to acknowledge receipt: l B. LOQ-In Phase: 3/22/2004 AH Location: lid Yes (\-~ Samples Log-in Date: 3/22/2004 Log-in By: AH 1. Packing Type: 2. Were samples in separate bags? 3. Were containers intact? I 4. Number of bottles received: 5. Correct containers used? r. 1.1 6. Sufficient sample volume? 7. Bubbles in VOA samples? Bubblewrap Yes Yes Order #: A0403204 Signature: QM~lL~d. J Carrier Name: Other Seal Name: JP Signed by AEL employee? Yes 3.0 7 Yes Labels agree with COC? Number of samples received: Correct preservatives added? Yes N/A No 9. Was anyone called? COMMENTS: No .8. Was Project manager called and status discussed? Who was called? By whom? Date: . 3fj)àJDt.J Signature: ~\r~~~ Yes 4 Yes Date: Page 1 of ( (' Analytica International, Inc. 5761 Silvera do Way, Unit N Anchorage, AK 99518 Phone: 907-258-2155 Fax: 907-258-6634 ANALYTICA Environmental laboratories 3/23/2004 CH2M Hill of Alaska 301 W. Northern Lights Suite 601 Anchorage, AK. 99503 Attn: Rob Crotty Work Order #: A0403197 Date: 3/23/2004 Work ID: Point Storkersen Date Received: 3/22/2004 Sample Identification :) 0 Lab Sample Number A0403197-01 A0403197-03 Client Description PS-GP-03 PS-GP-07 Lab Sample Number A0403197 -02 Client Description PS-GP-06 Enclosed are the analytical results for the submitted sample( s). Please review the CASE NARRATIVE for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided at the end of the report. Sincerely, Jason Gray Project Manager "The Science pf Analysis, The Art of Service" Case Narrative Analytica Alaska Inc. Work Order: A0403197 Samples were prepared and analyzed by methods in the following references: ADEC Method AKl02 For the Determination of Diesel Range Organics. SAMPLE RECEIPT: Samples for Pt.Storkensen project were received at Analytica-Anchorage (ADEC Laboratory Approval Number: UST-014)on 3/22/2004 at a temperature of 3.0°C. Samples were received in good condition and in order per chain of custody. As per client request, EPA method Method 3630C silica gel clean-up of the DRO sample extracts was performed on the sample extracts in order to minimize the influence of potential background biogenic hydrocarbon from the sample matrix. Please note that silica gel clean-up is not currently approved as a part of the standard AKI02 methodology. DRO samples reported on Rush 24-hr basis, remainder of results from this delivery ,to be reported later on standard turn around time. REVIEW FOR COMPLIANCE WITH ANALYTICA QA PLAN A summary of our review is shown below, organized by test: Test Method: ADEC AKI02° - (DRO w/ Silica Gel Cleanup) ::> HOLDING TIMES: Holding times were met for this test. INSTRUMENT CALIBRATIONS: Initial calibration and CCV samples met method criteria. SURROGATE RECOVERIES: There were no surrogate recovery outliers. METHOD BLANK OUTLIERS: There were no MB outliers. LCS/LCSD OUTLIERS: There are no LCS/LCSD outliers. Detailed Analytical Report W orkorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report IpS-G~-03 , , Client Sample Name: Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403197-01A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: DIY Weight Basis Sample prep wt./vol: 25.53 g Analvte CASNo Result Fla~s Units Diesel Range Organics nJa 3,800 mg/Kg Surro2ate CASNo Result Fla2s Units o-Terphenyl 84-15-1 2.6 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403197-01A Prep Date: 3/22/2004 . Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt.lvol: 12.31 g Analvte Moisture CASNo na ~ 30 Fla2s Units % Page 3 of 11 ( Analytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 56 8.6 POL 2.6 MDL Spike 0.52 2.8 % Recov 94.8 Analysis pate: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.036 0.0073 3/17/2004 1 :OO:OOPM 3/23/2004 7:40:00AM Woof W4032286.D 10 30 GD 1.00 ml Rerun #: 1 Ci) LCL UCL Rerun #: 50 150 1 3/23/2004 10:18:32AM SCALE 1 GD 8.96 ml Rerun #:' 1 Detailed Analytical Report W orkorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report IpS-GP-06 Client Sample Name: Matrix: Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403197 -02A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKl 02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt./vol: 25.29 g Analvte CASNo Result J Diesel Range Organics n/a 2,200 Surro2ate CASNo Result o-Terphenyl 84-15-1 2.4 The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403197 -02A Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt./vol: 10.63 g Analvte Moisture CASNo na Result 13 Page 4 of II FIa{!s Units mg/Kg . Fla{!s Units mglKg FIa{!s Units % Analytica Alaska Inc. ~ Collection Date: 3/17/2004 1:50:00PM Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 46 7.1 POL 2.1 MDL Spike 0.43 2.3 % Recov 105 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.044 0.0088 3/23/2004 8:09:00AM Woof W4032287.D 10 14 GD 1.00 LCL 50 ml Rerun #: 1 UCL Rerun #: 150 1 3/23/2004 10:18:32AM SCALE 1 GD 9.33 ml Rerun #: 1 ( Detailed Analytical Report W orkorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hlll of Alaska Client Project Number: Report Section: None . Client Sample Report IpS-GP-07 Client SampJe Name: Matrix: , Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403197 -03A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKI02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt.!vol: 25.98 g Analvte CASNo Result FJa!!s Units Diesel Range Organics nla 1,900 mg/Kg Surroeate CASNo Result Flal!s Units o-Terphenyl 84-15-1 2.0 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: . A0403197 -03A Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt.lvol: 10.61 g Analvte Moisture CASNo na Result 15 Page 5 of 11 Fla1!s !l!!!!! % Analytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 23 3.5 POL 1.1 :M!& Spike 0.21 2.3 % Recov 90.3 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MÌ>L 0.043 0.0087 3/17/2004 1 :30:00PM 3/23/2004 8:37:00AM Woof W4032288.D 5 15 GD 1.00 ml Rerun #: ()1 LCL UCL Rerun #: 50 150 1 3/23/2004 10: 18:32AM SCALE 1 GD 9.19 ml Rerun #: 1 Detailed Analytical Report W orkorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: Report Section: None Method Blank Report 1MB Client Sample Name: Matrix: Solid The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040322004-MB Prep Date: 3/22/2004 Analytical Method ID: ADEC AKl 02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt./vol: 27.06 g Analvte CASNo Result FIal?:s Units -) Diesel Range Organics n/a ND mg/Kg Surrol!;ate CASNo Result Flal?:s Units o-Terphenyl 84-15-1 1.7 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040323001-MB Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A04032300 1 Report Basis: Dry Weight Basis Sample prep wt.lvol: 10.12 g Analvte Moisture CASNo na Result ND Page 6 of 11 Flal?:s Units % Analytica Alaska Inc. , Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 3.7 0.57 POL MDL Spike 0.17 0.035 1.8 % Recov 94~1 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.050 0.010 3/22/2004 12:00:00AM 3/22/2004 5:15:00PM Woof W4032261.D 1 NA GD 1.00 LCL 50 ml 0 Rerun #: 1 :¡ UCL Rerun #: 150 1 3/23/2004 10:18:32AM SCALE 1 .NA GD 10.12 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403197 Analytica Alaska Inc. Project: Client: Point Storkersen CH2M Hill of Alaska Client Project Number: None Tests Run at: Analytica Environmental Laboratories - Anchorage, Alaska Workorder (SDG): A0403197 Project: Point Storkersen Project Number: Prep Batch: QUALITY CONTROL REPORT A040322004 LCS/LCSD REPORT Analysis: ADEC AKI02 - wi silica gel cleanup MB: A040322004:.MB 3/22/2004 mg/Kg Solid Recov Lim RPDLim Flag 60 - 120 20 "I MB Anal. Date: LCS Anal. Date: Analyte Name Diesel Range Organics Prep Date: 3/22/2004 5:15:00PM Units: 3/22/2004 5:44:00PMLCSD Anal. Date: 3/22/2004 6:13:00PM Matrix: SampResult LCSRes. SDRes. SPLev SPDLev Recov. SD Recov RPD ND 74.4 71.1 79.7 76.9 93.3 92.5 4.5 FOOTNOTES TO QC REPORT () Note 1: Results are shown to three significant figUres to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. . Note 3: For sample duplicates, if the result is less than the PQL, the duplicate RPD is not applicable. Ifthe sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Note 4: For serial dilutions, ifthe result is less than the PQL, the duplicate RPD is not applicable. Ifthe sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 7 of 11 Detailed Analytical Report Analytica Alaska Inc. W orkorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: None SURROGATE RECOVERY SUMMARY REPORT Test Method: ADEC AK102 - wI silica gel cleanup Lab Sample #: A0403197 -0 lA Dilution: 10 Analysis Date: 3/23/2004 7:40:00AM Client Sample: PS-GP-03 Batch Number: A040322004 Data File: W4032286.D AnalvteN ame SSRecov LCL UCL SSFla2; Result Status 0- Terphenyl 95 50 150 Complete Lab Sample #: A0403197 -02A Dilution: 10 Analysis Date: 3/23/2004 8:09:00AM Client Sample: PS-GP-06 Batch Number: A040322004 Data File: W 4032287.D AnalvteName SSRecov LCL DCL SSFla2; Result Status ") 0- Terphenyl 105 50 150 Complete Lab Sample #: ) Dilution: A0403197 -03A :> 5 Analysis Date: 3/23/2004 8:37:00AM Client Sample: PS-GP-07 Batch Number: A040322004 Data File: W4032288.D AnalvteName SSRecov LCL DCL SSFla2; Result Status 0- Terphenyl 90 50 150 Complete Lab Sample #: A040322004-MB Dilution: Analysis Date: 3/22/2004 5:15:00PM Client Sample: MB Batch Number: A040322004 Data File: W 4032261.D AnalvteName SSRecov LCL UCL SSFla2; Result Status 0- Terphenyl 94 60 120 Complete Lab Sample #: A040322004-LCS Dilution: Analysis Date: 3/22/2004 5:44:00PM Client Sample: LCS Batch Number: A040322004 Data File: W4032262.D AnalvteN ame SSRecov LCL DCL SSFla2; Result Status 0- Terphenyl 102 60 120 Complete Lab Sample #: A040322004-LCSD Dilution: Analysis Date: 3/22/2004 6:13:00PM Client Sample: LCSD Batch Number: A040322004 Data File: W4032263.D AnalvteName SSRecov LCL UCL SSFla2; Result Status o-Terphenyl 100 60 120 Complete Page 8 of 11 Detailed Analytical Report Workorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: Lab Project ID: Lab Method Blank Id: Prep Batch ID: Method: Analytica Alaska Inc. None QC BATCH ASSOCIATIONS - BY:METHOD BLANK 26,205 Lab Project Number: A0403197 Prep Date: 3/22/2004 A040322004-MB A040322004 ADEC AKI02 - w/ silica gel cleanup This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A0403 22004- LCS A040322004-LCSD A0403197 -0 lA' A0403197 -02A A0403I 97-03A LCS LCSD PS-GP-03 PS-GP-06 PS-GP-07 5:44:00PM 6: 13:00PM 7:40:00AM 8 :09:00AM 8:37:00AM W4032262.D W4032263.D W4032286.D W4032287.D W4032288.D 3/22/2004 3/22/2004 3/23/2004 3/23/2004 3/23/2004 0 Prep Date: 3/22/2004 Lab Method Blank Id: A040323001~MB Prep Batch ID: A04032300 I Method: ASTM D2216 - % moisture This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A0403196-08A Batch QC 3/23/2004 10:18:32AM . A0403197-01A PS-GP-03 .3/23/2004 10:18:32AM A0403197-02A PS-GP-06 3/23/2004 10:18:32AM A0403197-03A PS-GP-07 3/23/2004 10:18:32AM A0403196-08A-DUP DUP 3/23/2004 10:18:32AM . Page 9 of 11 Detailed Analytical Report Workorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None DATA FLAGS AND DEFINITIONS The PQL is the Method Quantitation Limit as defined by USACE. Reporting Limit: Limit below which results are shown as "ND". This may be the PQL, MDL, or a value between. See the report conventions below. . Result Field: ND = Not Detected at or above the Reporting Limit NA = Analyte not applicable (see Case Narrative for discussion) Qualifier Fields: LOW = Recovery is below LowerControl Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E = Reported concentration is above the instrument calibration upper range Organic Analysis Flags: 0 B = Analyte was detected in the laboratory method blank J = Analyte was detected above MDL or Re¡rorting Limit but below the Quant Limit (PQL) Inorganic Analysis Flags: J = Analyte was detected above the Reporting Limit but below the Quant Lim:it (PQL) W = Post digestion spike did not meet criteria S = Reported value determined by the Method of Standard Additions (MSA) Other Flags may be applied. See Case Narrative for Description Page 10 of 11 ( Detailed Analytical Report Workorder (SDG): A0403197 Project: Point Storkersen Client: CH2M Hill of Alaska Client Project Number: None ( Analytica À1aska Inc. REPORTING CONVENTIONS FOR TillS REPORT A0403197 TestPkgName AKI02/3550B (Solid) - wi silica gel cleanup ASTMD22161 ASTMD2216 (Solid) - % moisture .1> Page 11 of 11 Basis Dry Weight Basis As Received # Sig Figs 2 2 Reporting Limit Reportto PQL Report to PQL 811 W. 8th Ave. Anchorage. AK 99501 (907) 258-2155 FAX: (907) 258-6634 ^ ANALYTICA GROUP www.analyticagroup.com Company Name: C -tt'2.. ""\. .\..\. \ L L Project Name: Company Address: A~ora.'t- ) A~ Telephone: '2-1-~ '" 2-SS \ 't; 25'1-2..000 Emall: r~ G. ~2-~ . c..o"V\. Sample ID ~.-~P- 03 ~-GP-ob P; - GP -0+ ~ ~ u ~ Õ (,,) C!> tü a ~ ~ u ~ Õ u C!> .§ ¡...;: .~ I 3Irt!ö1 l~6 5 l-l L35Ò \\ U l :, '2>0 \.1 "1.. COMMENTS ð # Containers ,j¡!I,,,..,. 5438 Shaune Drive Juneau. AK 99801 (907) 780-6668 FAX: (907) 780-6670 12189 Pennsylvania Street Thornton. CO 80241 (303) 469-8868 FAX: (303) 469-5254 N~ 3 1 6 3 4 ì..-Crr ~ ro~ O~..\ ''/ D c..ol;;. ,LGN: 110 '-i 03 ¡ei-¡ Quote: Project tD #: , Chain of Custody Record I Analysis Request Q~ \(Jl a u ."~ '~;" -'" ~ :~._~ ~ ~ ~ £ 0 ~ v - <t <t i&~ '; )( ~ )( '" X) i- S 1l-1c.A ~ß.¿.... <:::..Lfi.A-r-.JD~ ~ Â"-lcL ~T=Htb - J.tt-¿"... 'St:t-M.RP--S ~Ö\~" ~~(\ Report To: Q-d~ Q.....otl-'1 Invoice To: J""':'. \. 0 rL "-Or"'V fÁ.; . S I P.O. Number 3l'-\~\ .~l.ö1.. RELINOUlSHED BY SAMPLER: .~tL RELINQUISHED BY: ,. Slg ure: ¡JIll tPf$# ~7Jf;me: ~//etJ FI""lJr] D3e:¡~Ô1 & III/f) ¡¡¡:;"'R;!" " FÕfrtfl1 fttl-t- Da!fo/~L( 1760 ('.. ~ ~ ~ t: ~ ('.. c:: @ ¡ 0 ~ ~ (,,) C ~ ~ - ...... CI) .c: CD ~ æ r :s ¡ v~ V-J; ~~ Pr-6" l- ,:~(J Dusmess ¡Jays ~ 0 15Busin~ays ~1t...C .~ 'f¡( other: <... I J # Business Days lPrior Aqthorizatlon Required.) Cooler Receipt InformatIon RECEIVED BY: Slgnatur(J: '1 ~ ()->rl\'~U', \\i).)~\"V\Ci ~ Temp Received: v. v 'lrinted Name: Temp Received: ~\t.u,,-, t\-o t'r\~~~it~f' Coolers: I Firm: seals:1 p ~LL. Date/ Time: Means of De/Ivery / Way Bill # 3ItJ.~/()'-l ð"6C'~ COt)fJ~ l &old~'W('\é- .C .C A ANALYI'ICA Client: CH2M Hill of Alaska Project: Point Storkersen Cooler I D: 1 A. Preliminarv Examination Phase: 1. Was airbill Attached? 2. Custody Seals? No Yes 3. Seals intact? Yes N/A 4. Screened for radiation? .. 5. COC Att~cQed? . Yes 1. Preservative: BlueGel i 6. Project Identificafon from custody paper: Cooler Receipt Form I Clien} cot: 006120 ¡ Qate cooler opened: qooler opened by: . Þ¡i rbill #: i How many? 1 , ( ¡: :~~ Prop~¡'ly Completed? Point Storkersen Temperature: I . Designated person inifal here to acknowledge recei~t: COMMENTS:! . ! \ i 3/22/20041 AH I t Order #: A0403197 Signature: ~\Z~V- /tltrn~ ¡ I Carrier Name: Other ! Seal Name: JP Location: lid B. LOÇl-ln Phase: ! Samples Log-in Date: 3/22/2004 Log-in By: AH 1. Packi~g Type: 2. Were samples in separate bags? 3. Were containers intact? 4. Number of bottles received: 5. ; Correct containers used? \ 6. Sufficient'sample volume? 1. Bubbles in VOA samples? Bubblewrap Yes Yes Yes Signed by AEL employee? Yes I j ~ ~.o F-'J- , Date: ~~?.IÛ 4 Signature: . ~It.lt tULvì~ \ 3 Yes Labels ag.ree with COC? NÙmber rf samp¡les received: Correct preservatives added? Yes N/A No 9. Was anyone called? CO JlMENJ"S: I No 8. Was Project manager called and status discussed? Who was called? . t i ¡ ¡ ¡By ~hom? Yes 3 N/A Date: Page 1 of ~ (' Analytica International, Inc. 5761 Silverado Way, Unit N Anchorage, AK 99518 Phone: 907-258-2155 Fax: 907-258-6634 ANALYTICA Environmental laboratories 3/23/2004 CH2M Hill of Alaska 301 W. Northern Lights Suite 601 Anchorage, AK 99503 Attn: Rob Crotty Work Order #: A0403196 Date: 3/23/2004 Work ID: Pt. Storkersen #1 Date Received: 3/22/2004 .} Sample Identification Lab Sample Number A0403196-0 1 A0403196-03 A0403196-05 A0403196-07 Client Description SFP-06D SFP-16D SFP-16 SFP-02 ('\ Lab Sample Number A0403196-02 A0403196-04 A0403196-06 A0403196-08 Client Description SFP-10. SFP-13 SFP-09 SFP-06 Enclosed are the analytical results for the submitted sample( s). Please review the CASE NARRATIVE. for a discussion of any data and/or quality control issues. Listings of data qualifiers, analytical codes, key dates, and QC relationships are provided at the end of the report. Sincerely, Jason Gray Project Manager "The Science of Analysis, The Art of Service" Case Narrative Analytica Alaska Inc. Work Order: A0403I96 Samples were prepared and analyzed by methods in the following references: ADEC Method AKI02 For the Determination of Diesel Range Organics. SAMPLE RECEIPT: Samples and VOC trip blank for Pt.Storkensen project were received at Analytica-Anchorage (ADEC Laboratory Approval Number: UST-014)on 3/22/2004 at a temperature of 3.0°C. Samples were received in good condition and in order per chain of custody. As per client request, EPA method Method 3630C silica gel clean-up of the ORO sample extracts was performed on the sample extracts in order to minimize the influence of potential background biogenic hydrocarbon from the sample matrix. Please note that silica gel clean-up is not currently approved as a part of the standard AKI02 methodology. REVIEW FOR COMPLIANCE WITH ANALYTICA QA PLAN A summary of our review is shown below, organized by test: Test Method: ADEC AKI02 - (ORO w/ Silica Gel Cleanup) HOLDING TIMES: Holding times were met for this test. 0 INSTRUMENT CALIBRATIONS: Initial calibration and CCV samples met method criteria. SURROGATE RECOVERIES: Samples shown below had surrogate recovery slightly below method control limit, indication of matrix effects inherent to the sample inhibiting extraction. Sample LabID Surrogate Recovery LCL UCL SFP-09 A0403196-06A o-Terphenyl 43 50 150 SFP-06 A0403196-08A o-Terphenyl 48 50 150 likely an METHOD BLANK OUTLIERS: There were no MB outliers. LCS/LCSD OUTLIERS: There are no LCS/LCSO outliers. ( Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report ISFP-06D Client Sample Name: Matrix: Soil ( .. ..x~~, .;~.\ ;:~, ...., _.~-;- ._.þ ¡t..,.~~...~ - The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-0 lA Prep Date: 3/22/2004 Analytical Method ill: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 . Report Basis: Dry Weight Basis Sample prep wt./vo1: 25.18 g Analvte CASNo Result Flal!s Units Diesel Range Organics nJa 74 mg/Kg Surroe:ate CASNo Result Flal!s Units o-Terphenyl 84-15-1 3.4 mg/Kg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-01A Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt.lvol: 11.43 g Analvte Moisture CASNo na Result 56 Flal!s Units % Page 3 of 18 ( Ana1ytica Alaska Inc. ~ Collection Date: ".' ~~~.""<. . ''''''-(!:~:'':~''''''. t"''''''1'",,,,,~,,,,~,~~,,,,'',,,,,...<:,,,,,,.~'~~'7~~'1':iI~\.-..-.Á.- Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: ') ) POL MDL 8.9 1.4 POL MDL Spike 0.42 . 0.084 4.5 % Recov 76.5 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.025 0.0049 3/19/2004 10:28:00AM :~,. '.' ..~,.. .""" .~~ 3/22/2004 11:57:00PM Woof W4032275.D 1 56 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/23/2004 10:18:32AM SCALE 1 GD 5.62 m1 Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CB2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report SFP-IO Client Sample Name: Matrix: Soil ~ ----'~~ The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-02A Prep Date: 3/22/2004 Analytical Method ill: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt./vol: 26.10 g Analvte CASNo Result Fla!!s Units Diesel Range Organics n/a 57 mglKg Surroe:ate CASNo Result Fla!!s Units 0- Terphenyl 84-15-1 3.1 mglKg 1\e following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-02A Prep Date: 3/22/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt./vol: 10.01 g Analvte Moisture CASNo na Result 64 Fla!!s Units % Page 4 of 18 Analytica Alaska Inc. ""'.-CT'__} . Collection Date: YUi"\ :~i(fnl1r\ '.''';';:';'.(;L>;JW:'''' Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL j 11 1.7 POL 0.51 MDL Spike 0.10 5.4 % Recov 58.2 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.021 0.0042 3/20/2004 9:00:00AM 'i'.'- 3/22/2004 6:41 :OOPM Woof W4032264.D 1 65 GD 1.00 ml Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/23/2004 10:18:32AM SCALE GD 4.18 ml Rerun #: 1 (' Detailed Analytical Report Workorder (SDG): A0403196 . Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report SFP-16D Client Sample Name: Matrix: Soil '1( W~ Y','.:'.;-''-)'' ,.W:"'~'==';:'~jo'".,~-::otiÄ..',-i.'~',:"..~'-:;"'~""~~~"",,,:~,"*,,'3.!="¡;'.l-~'" . The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-03A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKl 02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt.!vol: 26.36 g Analvte Diesel Range Organics Surrol!ate 0- Terphenyl , CASNo n/a CASNo 84-15-1 Result 62 Result 2.4 The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-03A Prep Date: 3/22/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A04032300 1 . Report Basis: As Received Sample prep wt.!vol: 10.14 g Analvte Moisture ~ na Result 61 Page 5 of 18 Flal!s Units mg/Kg Flal!s Units' mg/Kg Flal!s Units % ( Analytica Alaska Inc. ~ Collection Date: ~,~--",""...~'!I,""~, Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials:. Prep Extract Vol: POL MDL 9.8 1.5 POL MDL . Suike 0.46 0.092 4.9 0/'0 Recov 50.0 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.022 0.0045 3/20/2004 9:30:00AM .~:'..,::^'.Ì"'-" --i1 3/22/2004 7:1O:00PM Woof W 4032265.D 1 61 GD 1.00 ml ,:) Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/23/2004 10:18:32AM SCALE 1 GD 4.52 ml Rerun #: 1 . Detailed Analytical Report Workorder (SDG): A0403196 Project: pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report SFP-13 Client Sample Name: Matrix: Soil' .: . I' :'t," -\~' .. '..,.. : The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-04A Prep Date: 3/22/2004 Analytical Method ID: ADEC AK102 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt./vol: 26.04 g Analvte CASNo Result F1at!s Units Diesel Range Organics n/a 71 mg/Kg Surrot!ate CASNo Result Flat!s Units 0- Terphenyl 84-15-1 2.8 mgfKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-04A Prep Date: 3/22/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt./vol: 12.03 g AnaIvte Moisture Result 63 Flat!s Units % CASNo na Page 6 of 18 Analytica Alaska Inc. _J Collection Date: ,\ --.- r,,~'Ii;,;-' - ,....I iI~'~...' ~"'. -.. ~ \ 3/20/2004 9: l5:00AM .'1; ," .~it'<6!I: :-':".'\"1,' Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 10 1.6 POL MDL Spike 0.49 0.098 5.2 0/0 Recov 54.2 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL !ill& 0.021 0.0042 'i,-~ ,:;~......."~,..:-~- 3/22/2004 7:39:00PM Woof W4032266.D 1 63 GD 1.00 LCL 50 ml Rerun #: . 1 UCL Rerun #: 150 1 3/23/2004 10:18:32AM SCALE 1 GD 5.02 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report SFP-16 Client Sample Name: Matrix: Soil '-''';.' "j( -. --:'i.~-,"/~'i#~~';~ J, ,- , n- t::. ;..~-;f.i.J.....,....¡~~i,!"...$. .' ,(\I~M~~--- '<-' The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-05A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKI02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: DryWeighl Basis Sample prep wt./vo1: 26.44 g Analvte CASNo Result Fla~s Units Diesel Range Organics n/a 130 mglKg Surro2ate CASNo Result Fla~s Units o-Terphenyl 84-15-1 3.6 mglKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-05A Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt.lvo1: 10.17 g Analvte Moisture CASNo na ~ 64 Fla~s !l!!!!! % Page 7 of 18 (' Analytica Alaska Inc. ~ Collection Date: . :.~~~,-~~ ",,,,:-,~,,'''....'''-.hy,-,...,.,....... ;,.~,.,~' ~~~.~.,-:.I.\'¡'''~''''' . Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: () POL MDL 10 1.6 POL MDL Spike 0.49 0.098 5.2 0 % Recov 68.2 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.021 0.0042 3/20/2004 9:25:00AM . ~~~,~.:.__.. .. 3/22/2004 8:07:00PM Woof W 4032267.D 1 64 GD 1.00 1111 Rerun #: 1 LCL UCL Rerun #: 50 150 1 3/23/2004 10: 18:32AM SCALE 1 GD 4.30 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report ISFP-09 Client Sample Name: Matrix: Soil ~ . ~ .I,-":-J ," .~,'''''J!'' ",4i'IIi-¡.!:1"f.lp:",~-¥'f~ . ,'-~-->t.o"~-"'!IÎt'I\'<!<"',~'!>";""'-'~"""~'¡'''' The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-06A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKI 02 - wi silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry Weight Basis Sample prep wt.!vol: 27.96 g ) :» Analvte CASNo Result FIa2s Units Diesel Range Organics n/a 65 mglKg Surro~ate CASNo Result Fla2s UnitS 0- Terphenyl 84-15-1 1.1 mglKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-06A Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt./vol: 10.66 g Analvte Moisture CASNo na Result 32 FIa2s Units % Page 8 of 18 Analytica Alaska Inc. ) Collection Date: ", :,:,-,."<".::;,..",~~~.,~~,,,~~.......o(,i ' 3/19/2004 1 0:40:00A~1 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 5.2 0.81 POL MDL Soike 0.25 0,049 2.6 % Recov 43.6 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.036 0.0071 3/22/2004 8:36:00PM Woof VV 4032268.D 1 32 GD 1.00 m1 ) Rerun #: 1 LCL UCL Rerun #: 50 150 1 LOW 3/23/2004 10:18:32AM SCALE 1 GD 7.57 m1 Rerun #: 1 I' Detailed Analytical Report W orkorder (SDG): A0403196 Project: PL Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: None Client Sample Report rSFP-02 Client Sample Name: Matrix: Soil ~-- ---. ,- .\'('.~':~~-~:~!'v-:~*,'~*\~'~-;'d$~.~~;'J~~,..t- _° "'~, ...: The following test was conducted by: Analytica - AnchorDgc Lab Sample Number: A0403196-07 A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKI 02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: . Dry Weight Basis Sample prep wt.!vol: 26.87 g I Analvte CASNo Result Fla2s Units Diesel Range Organics n/a 20 mg/Kg Surrof!ate CASNo Result Flal!s Units 0- Terphenyl 84-15-1 2.1 mg/Kg 0 ¡ The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-07A Prep Date: . 3/22/2004 Analytical Method ID: . ASTM D2216 - % moisture Prep Method ID: D2216 Prep,Batch Number: A04032300 1 Report Basis: As Received Sample prep wt./vol: 10.18 ( g, Analvte Moisture ~ na ߣ!!!!! 47 ( [ Page 9 of 18 Flal!s Units % . Analytica Alaska Inc. , Collection Date: 3/19/2004 10:05:00AM ...,.I..:o..~ .~~.~,':'.":'~\,,:'.. - -~~';"¡"~~"1;<>-':""~";""~'ð~:\~.... Analysis Date: Instrument: File Namc: Dilution Factor: Percent Moisture Analysllnitials: Prep Extract Vol: POL MDL 7.0 1.1 POL MDL Spike 0.33 0.065 3.5 % Recov 59.3 Analysis Date: InstIinnent: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.029 0.0058 3/22/2004 9:04:00PM Woof W4032269.D 1 47 GD 1.00 LCL 50 ml Rerun #: 1 UCL Rerun #: 150 I 3/23/2004 10:J8:32AM SCALE 1 GD 5.90 ml Rerun #: 1 Detailed Analytical Report W orkorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: Client Sample Name: Matrix: None Client Sample Report ISFP-06 :J!I.;~.,-HJat:~:~-':I!t"",~"~"';"'''''"',*:~;I,~''~''%I'o>'~~''~¡;';;'''~1':,.,:..,,,,~1t'~ijI'.",;¡'¡:;~:;-:-(M"'1 '. '( :-r",. c:, Soil The following test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-08A Prep Date: 3/22/2004 Analytical Method ID: ADEC AKl 02 - wI silica gel cleanup Prep Method ID: 3550 Prep Batch Number: A040322004 Report Basis: Dry W cight Basis Sample prep wt./vol: 28.22 Analvte Diesel Range Organics Surroeate o-Terphenyl g CASNo Result Flaes Units n/a 79 mglKg CASNo Result Fla!!s Units 84-15-1 2.7 mglKg The fol1owing test was conducted by: Analytica - Anchorage Lab Sample Number: A0403196-08A Prep Date: 3/22/2004 Analytical Method ill: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A040323001 Report Basis: As Received Sample prep wt./vol: 12.34 Analvte Moisture Page 10 of 18 g CASNo Result 69 Flaes Units % na Analytica Alaska Inc. ~ Co]]ection Date: 3/19/2004 10:15:00AM Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 11 1.7 POL 0.53 MDL Spike 0.11 5.7 % Recov 48.5 .j Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL MDL 0.018 0.0037 3/22/2004 10:02:00PM Woof \V4032271.D 1 69 GD 1.00 LCL 50 ml Rerun #: 1 UCL Rerun #: 150 1 LOW 3/23/2004 10: 18:32AM SCALE 1 GD 4.53 m1 Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Report Section: Client Sample Name: Matrix: L None Method Blank Report 1MB Solid ~~ - .'-, . _. . 6 ..",,"¿;""+i~~o<'!I';";-~,'-!l~ . (' Analytica Alaska Inc. ~ -- ~ ':i",:,;:;'':.<.i!-'~ ",.~,;.-,. ";:i:~¡;'¡":;'~~.<,,¡' .:, ,.~..;.;:;;,'¡',:".ii' ,-,;",;1>.:,;. ~ .~. ,-:<,~ ~~,;¡...",~ 3/22/2004 l2:00:00AM. .~ The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040322004-MB Prep Date: 3/22/2004 Analytical Method ID: ADEC AK 102 - wi silica gel c1canup Prep Method ID: 3550 Prep Batch Number: A040322004 Repon Basis: Dry Weight Basis Sample prep wt./vo1: 27.06 Analvte Diesel Range Organics Surrogate 0- Terphenyl g CASNo Result Fla!!s Units nla ND mglKg CASNo Result Fla!!s Units 84-15-1 1.7 mglKg The following test was conducted by: Analytica - Anchorage Lab Sample Number: A040323001-MB Prep Date: 3/22/2004 Analytical Method ID: ASTM D2216 - % moisture Prep Method ID: D2216 Prep Batch Number: A04032300 1 Report Basis: Dry Weight Basis Sample prep wtJvol: 10.12 g Analvte Moisture Page 11 of 18 ~ na Result ND FIa!!s !!!!ill. % Collection Date: Analysis Date: Instrument: File Name: Dilution Factor: Percent fvfüistllrc Analyst Initials: Prep Extract Vol: POL MDL 3.7 0.57 POL MDL Spike 0.17 0.035 1.8 % Recov 94.1 Analysis Date: Instrument: File Name: Dilution Factor: Percent Moisture Analyst Initials: Prep Extract Vol: POL M!!L 0.050 0.010 3/22/2004 5:15:00PM \V oof \V4032261.D 1 NA GD LOO LCL 50 1111 Rerun #: 1 UCL Rerun #: 150 1. 3/23/2004 10:18:32AM SCALE 1 NA GD 10.12 ml Rerun #: 1 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None Tests Run at: Analytica Environmental Laboratories - Anchorage, Alaska W orkorder (SDG): A0403196 Project: Pt. Storkersen #1 Project Number: Prep Batch: QUALITY CONTROL REPORT A040323001 Analysis: ASTM D2216 - % moisture SAMPLE DUPLICATE REPORT Base Sample:A0403196-08A Prep Date: 3/22/2004 Samp. Anal. Date: 3123/2004 10: 18:32AIvI DUP Anal. Date: 3/23/2004 10:18:32AM Units: Matrix: % Soil Analyte Name Moisture SampResult DUPRes. 68.7 67.3 RPD 2.1 RPDLim 20 Flag 0 Prep Batch: A040322004 LCSILCSD REPORT Analysis: ADEC AKI02 - w/ silica gel cleanup MB: Prep Date: 3/22/2004 5:15:00PM Units: 3/2212004 5:44:00PM LCSD Anal. Date: 3/22/2004 6: 13:00PM Matrix: A040322004-MB 3/22/2004 mg/Kg Solid MB Anal. Date: LCS Anal. Date: Analyte Name Diesel Range Organics SampResult LCSRes. SDRes. SPLev SPDLev Recov. SD Recov RPD Recov Lim RPDLim Flag ND 74.4 71.1 79.7 76.9 93.3 92.5 4.5 60 - 120 20 FOOTNOTES TO QC REPORT Note 1: Results are shown to three significant figures to avoid rounding errors in calculations. Note 2: If the sample concentration is greater than 4 times the spike level, a recovery is not meaningful, and the result should be used as a replicate. In such cases the spike is not as high as expected random measurement variability of the sample result itself. Note 3: For sample duplicates, if the result is less than the PQL, the duplicate RPD is not applicable. If the sample and duplicate results are not five times the PQL or greater, then the RPD is not expected to fall within the window shown and the comparison should be made on the basis of the absolute difference. Analytica uses the criterion that the absolute difference should be less than the PQL for water or less than 2XPQL for other matrices. Note 4: For serial dilutions, if the result is less than the PQL, the duplicate RPD is not applicable. If the sample result is not 50 times the MDL or greater, then the fact that the RPD does not meet the 10% criterion has little signifcance. Otherwise it indicates that a matrix bias may exist at the analytical step. Page 12 of 18 Detailed Analytical Report W orkorder (SDG): . A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None SURROGATE RECOVERY SUMMARY REPORT v Page 13 of 18 Detailed Analytical Report Analytica Alaska Inc. Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Test Method: ADEC AKI02 - wI silica gel cleanup Lab Sample #: A0403196-02A Dilution: 1 Analysis Date: 3/22/2004 6:41 :OOPM Client Sample: SFP-l 0 Batch Number: A040322004 Data file: \V4032264.D AnalvteName ssnccov LCL VCL S ,:,~~ ~~~ l'..1 2 Rl:s 1t Status 0- Terphe.!!yl 58 50 150 ----.; ::_.~-",-=-,.~,._~~~~J~!,~---- _..~"~"... ."-'--------..." Lab Sample #: A0403196-03A DilLltion: Analysis Date: 3/22/2004 7: 10:00PTvl Client Sample: SFT' -1 ('D Batch Number: A040322004 Data File: \V4032265,D AnalvteName SSRecov LCL DCL SSFbg ResnH Status 0- T erphç]1 y 1 50 50 150 Complete Lab Sample #: A0403196-04A Dilution: Analysis Date: 3/22/2004 7:39:00PM Client Sample: SFP-13 Batch Number: A040322004 Data File: W4032266.D AnalvteN ame SSRecov LCL VCL SSFlag Result Status 0- TerQhenyl 54 50 150 Complete Lab Sample #: A0403196-05A Dilution: Analysis Date: 3/22/2004 8:07:00PM Client Sample: SFP-16 Batch Number: A040322004 Data File: W 4032267.D AnalvteName SSRecov LCL VCL SSFlag Result Status o-Terphenyl 68 50 150 Complete Lab Sample #: A0403196-06A Dilution: Analysis Date: 3/22/2004 8:36:00PM Client Sample: SFP-09 Batch Number: A040322004 Data File: W 4032268.D AnalvteName SSRecov LCL VCL SSFlag Result Status 0- Terphenyl 44 50 150 LOW Complete Lab Sample #: A0403196-07 A Dilution: Analysis Date: 3/22/2004 9:04:00PM Client Sample: SFP-02 Batch Number: A040322004 Data File: W4032269.D AnalvteN ame SSRecov LCL VCL SSFlag Result Status o-Terphenyl 59 50 150 Complete Lab Sample #: A0403196-08A Dilution: Analysis Date: 3/22/2004 10:02:00PM Client Sample: SFP-06 Batch Number: A040322004 Data File: W4032271.D AnalvteName SSRecov LCL VCL SSF1ag ResuH Status 0- Terphenyl 49 50 150 LOW Complete Lab Sample #: A0403196-0 lA Dilution: 1 Analysis Date: 3/22/2004 11:57:00PM Client Sample: SFP-06D Batch Number: A040322004 Data File: W4032275.D AnalvteName SSRecov LCL VCL SSFlag Result Status o-Terphenyl 77 50 150 Complete Lab Sample #: A040322004-MB Dilution: Analysis Date: 3/22/2004 5: 15:00PM Client Sample: MB Batch Number: A040322004 Data File: W4032261.D AnalvteName SSRecov LCL VCL SSFlae Result Status Page 14 of 18 , ( Detailed Analytical Report W orkorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Test Method: ADEC AK102 - wI silica gel cleanup Lab Sample #: A040322004-:MB Analysis Date: 3/22/2004 5: 15:00PM Batch Number: A040322004 AnalvteName o-Terphenyl Lab Sample #: Analysis Date: Batch Number: A040322004- LCS 3/22/2004 5:44:00Plv1 A040322004 Am)!vteNflme 0- Terpheny 1 Lab Sample #: Analysis Date: Batch Number: AnalvteName 0- Terphenyl A040322004-LCSD ~/22/2004 6:13:00PM A040322004 Page 15 of 18 SSRccnv 94 '-'-~'~-",'-" -..- SSRecov 102 SSRecov 100 Analytica Alaska Inc. ( Dilution: Client Sample: MB Data File: \V4032261.D LCL 60 DCL 120 - -----~-- - ,n. ~ -.--...---. .........-....-.- -- 1 S SF1 :~-~ --,-._-- .-.----.-....-.-.. ----_._---- . ._.__._.-'~.---_.- .. . Dilution: Client Sample: LCS Data File: \V4032262.D LCL 60 VCL ]20 Dilution: tHent Sample: Data File: LCL DCL 60 120 SS Flag LCSD W4032263.D SSFlag R (' 2.~lt--s.ta tus Cornn] cte Result Status Complete 0 Result Status Complete Detailed Analytical Report W orkorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: Lab Pro.iect ID: Lab Method Blank Id: Prep Batch ID: Method: Analytica Alaska Inc. None QC BATCH ASSOCIATIONS - BY METHOD BLANK 26,204 A0403196 J~ah Project Number: ----.-"-.- " Prep Date: 3/22/2004 A040322004- :NID A040322004 ADEC AKI02 - wi silica gel cleanup This Method blank and sample preparation bateh are associated with the following s,lInpks, spikes, <I ill! dupljealcs: SampleNum ClientSamp1eNamc DataFile Analysispat~ A040322004-LCS A040322004-LCSD A0403196-02A A0403196-03A A0403196-04A A0403196-05A A0403196-06A A0403196-07 A A0403196-08A A0403196-0IA Lab Method Blank Id: Prep Batch ID: Method: LCS LCSD SFP-I0 SFP-16D SFP-13 SFP-l~ SFP-09 SFP-02 SFP-06 SFP-06D 3/22/20U4 5:44:00PM 3/22/2004 6: 13 :OOPM 3/2212004 6:41:00PM 3/22/2004 7:10:00PM 3/22/2004 7:39:00PM 3/22/2004 8:07:00PM 3/22/2004 8:36:00PM 3/22/2004 9:04:00PM 3/22/2004 10:02:00PM 3/22/2004 11 :57 :OOPM W4032262,D W4032263.D , W4032264.D W4032265.D W4032266.D W4032267.D W4032268.D W4032269.D W4032271.D W4032275.D Prep Date: 3/22/2004 A040323001-MB A04032300 1 ASTM D2216 - % moisture This Method blank and sample preparation batch are associated with the following samples, spikes, and duplicates: SampleNum ClientSampleName DataFile AnalysisDate A0403196-01A SFP-06D A0403196-02A SFP-I0 A0403196-03A SFP-16D A0403196-04A SFP-13 A0403196-05A SFP-16 A0403196-06A SFP-09 A0403196-07 A SFP-02 A0403196-08A SFP-06 A0403196-08A-DUP DUP 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM 3/23/2004 10:18:32AM Page 16 of 18 ( Detailed Analytical Report W orkorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Analytica Alaska Inc. Client Project Number: None DATA FLAGS AND DEFINITIONS The PQL is the Method Quantitation Limit as defined by USACE. Rqcrting Limit: Limit below \\.h¡,~h ]"C:;:I]:,; Jrc :ihùwn ~b "NO", Th;:; m:-1Y ~c ~11C r~: '; :, ~J-::", or J V:¡]UC t1C!\\,cc"1, C',~ the report conventions below. Result Field: ND = Not Detected at or above the Reporting Limit NA = Analyte not applicable (see Case Narrative for discussion) Qualijjcr Fields: LOW = RecovelY is below Lower Contro! Limit HIGH = Recovery, RPD, or other parameter is above Upper Control Limit E= Reported concentration is above the instrument calibration upper range :) Organic Analysis Flags: B = Analyte was detected in the laboratory method blank J = Analyte was detected above MDL or Reporting Limit but below the Quant Limit (PQL) Inorganic Analysis Flags: J = Analyte was detected above the Reporting Limit but below the Quant Limit (PQL) W = Post digestion spike did not meet criteria S = Reported value detennined by the Method of Standard Additions (MSA) Other Flags may be applied. See Case Narrative for Description Page 17 of 18 Detailed Analytical Report Workorder (SDG): A0403196 Project: Pt. Storkersen #1 Client: CH2M Hill of Alaska Client Project Number: None Analytica Alaska Inc. REPORTING CONVENTIONS FOR TmS REPORT A0403196 TestPkgName AKI02/3550B (Solid) - wi silica gel cleanup ASTMD2216/ASTMD2216 (Solid) - % moisture " Page 18 of 18 Basis Dry Weight Basis As Rcceived # Sig Figs 2 2 Reporting Limit Report to PQL Report to PQL "'--" -~-'-',-",-. . ~ "--- - - ---....... . ?le£t~i. Ò \~(L ,~S :¡--Ç\\2(}Oe>\~ CIY-Jlor ß\AD As St:xJAJ AS S~f1pLt;> Mre¡¡)p' N~ 316.36 / .J ~. . ~. ... '/ ì.. G N F~t. ~2-0 ON \v ,---,-------~ ------~. Ath Ave; ---- 5438 tihaune Dnve 12189 P~It\!.ylvania Street:1 I NA ..rY111 ,---. A Anchorage, AK 99501 Juneau, AK 99801 Thornton, CO 80241 LGN: A-c t..f.03 , Cc ~ u '--' . (907) 258-2155 (907) 780-6668 (303) 469-8868 Quote: . G R O. U P FAX: (907) 258~6634 FAX: (907) 780-6670 FAX: (303) 469-5254 Project ID #: www.sna.;.1icagroup.com Chain of Custody, Record I Analysis Request Company' Name: Project Nome: C{-\2-11 \-\\LL- Pé, ,<)~rD2.I(EQSE:"N ~l . 1fJ:\ Company Address: i / ~i O\J FILG t~~~ C1Z-Oíf'1 ât r \ . ~o~ð3 CR-òTT ý ~ ù '5 ~. Telephone: '-9tA- - ':}&.. ß... 9'{;:r':. CÅ",c..\ . P.O. þ!l')!JJbe372R.1/ -d. { "-.J.:J ~ ' - l-qo1 - ry-~ß-2;51 -- \-' I 5 '-N -6- 4' Lu' ~ ~ ax: 2<~..'1AN'\ ~ ~ ~. ~ . ('\.1 ~. ..., ¡".u. }J (.) (J # Containers V') ;X \aJoo C'- .... _Êmall:o.vo~e G {U~,(Of1 ~ ~. I .I:j ~6 \ ~ ~ ~ 1 ~ ~ .0ç;.Ç; _c:£o~Ple IV -Øl¥LJß7-'b 5 I X... ~J ~ ~ s: r IS ..S~r-fD 6~2D 5(ø s , X ~ - 1 5 f9 - JÓO b1ØØ ~ X Y-. )( X iAf¿~* = I ~no .8 ,') W - 1 ~ { do L . f Y. X Lf ,-S1P- I(IJ ~w C5fis:3 X X X X 1Aú2tf t'::; 1'3- 11-'1 . 6 5~f-. 0'1 Ó3/11 (010 5- X X)( X &) i~Q.E 'ft= /=tlrøó tp ~)1r.. óqD ,"--"....._-,..,-- lotI) 2- )( X X. (oJ~ -ß..- S~p~ 07 - \ 7é/J? I X 'j. GJ7f) '1 Sf?- () ~ O?>lq /Õl? / t X 'A l\ß ~ '- CD "1((\1' ßL~ML Oô 10 /6']0 w )(.. 1?ì--.... . 9 COMMENTS 51 LlU-\ G FL CL~Nu P e0-- ~t I-. SAN PLES, ~ CALL r- D 10 Business Days <1..., Iv\. wI /-'Dr-i-Lfß-C{o:tl C.\~d C¡O+-2ì-8-L.S'SI .6.4"> ~ Aß '-(DtJ . «.~LV Q,ðUL-ï5 Fõ D15BuslnessDays Il\l.\.c.\ ()h:rc. II<¡ ~1I?AMPL,," Lv\æ-~r; < 2..(X)Df'rìC;;I~ D<2~.- @ AtvALY'L~ Sr-=P-O~ C\T\C:\ SFP-jCó )(other: #SusindssOays Œ\) Ä ~ . A~ PtY;S' ~~. .. N eø::> < ').Li \-\<2,. ",AT (~~-J'( ~Q\>\. c:;tÍf\l\J01Nb Q,~ fD\' 0 ~0t-'P;) . (Prior Authorization Required.) :~. ~;:;S::7;;. .7 ~R~C=:':~ ;;~d~'Æ. ;;L.:~re#h ..~. :SHED BY: ~::::~ ~Y:~... ::~=:n;:~Non 'C /' rØ7U~ '/Ø1f:tØP/ .. ~ ~klC' \4il\-t\tv\(,\ . '1"J'1 Nslf)Ø'. ri~ Name:. " Pri NBrneJ1. II.A Printed Name: - ~ 1 Temp ReceIVed: 'C ~ (/?:) y . J8!1 $/(t11 t . ~ midi ~~g ¡W.MMMt-r~ COOIeT!i: I , Öi2J1/.jILL .. FlitJI. . Fir/fiN 'f;Tr" seak<:_\;f Õ3:2í-?c../C>35 3~aPð:'I§. /~j() j~7":ð1€WÔP ~7;;iðY ??'..~ ~ (~~:J:;~;ba~idç+rt'~~ ~ ~ Date. oler opened: cool1opened by: :' ',-')iPfr . ~¡C'N mßny? ,. ~ t(, Ä~ ANALYTlCA, ' Client: ICH~I\" Hill of Alaska Project: Pt. St~rkersen #1 ! i Cooler ID: 1 A. Preliminary ~amination Phase: l i 1. Was airbi!l!Attached? 2. Custody S~als? No Yes 3. Seals intact? Yes 4, Screen2d for ndi3.tion? N/A ~ oler Receipt Form OQ6120 3/22/2004 AH 1 Location: lid Yes Order #: A0403196 S i 9 n å tu re: ("1 r...", i . ,.- ~, !.t \. '~"'!\/ ~~"~",.. \..../ 1. -.;\ t t. t2.à .~, ,- - ~ Signature: Yes' 8 N/A Other Seal Name: JP Signed by AEL employee? Yes ! 3.0 ~ . ~ ~ Samples Log-in Date: 3/2~O04 1 Log-in By: AH Bubblewra~ Labels agree with COC? ; Number of samples received: . Correct preservatives added? No By whom? C J rrier Name: Date: 3!~/Ôl~ ~if Dr~ -r.. ,.~.,[ Comn!r.ter!." 5. cae Attached? Yes ¡ uf.;",;;;;}) " j-' t; . u [ . , .. we i 6. Project Id~ntfic,ation from custody paper: ~Pt. Storkersen #1 l ~ rt l 7. preseïatlrj BlueGel ~ Temperature: Designated pe~9.n initial here to acknowledge receipi Ir ; COMMENTS: t:f ö in separate bags? Yes Yes ; ~ 8 -i: 5. Co,",-ct cO'~iners used? Yes ~ 6. SuffiCient Sl. :.ple volume? Yes ¡ ~ 7. Bubbles in,' . A samples? . N/A i ! 8. Was Proje , ~anager called and status disc~se~~ 9. Was anYOn.alled? No Who wrs c~led? COMMENTS: I. . i ~.! ,'; I ~ 1'1 ~, I .~ \~ .. I ~ ~ Î I ~\v.þ ~~ Date: Page i of MEMORANDUM CH2MHILL Review of Quality Assurance/Quality Control Laboratory Data for Pt. Storkersen 1 TO: Mike Barker /ExxnMobil COPIES: Project Notebook FROM: Rob Crotty DATE: July 21, 2004 Summary , Overall, the data is usable for the purpose of the confirmation sampling as described 'in Pt. Storkersen 1 Corrective Action Plan (CH2M HILL, October 2003) Non-conformances are. identified and discussed in this report. Introduction A review has been conducted on data submitted for confirmation sampling undertaken at Pt. Storkersen I, an inactive drill pad onshore of Gwydyr Bay on Alaska's North Slope. This report summarizes the results of the quality assurance/ quality control (QA/QC) data associated with the analysis of diesel-range organics (DRO), PQlynuclear aromatic hydrocarbons (PAHs),and aromatic volatile organic compounds (VOC) in confirmation samples collected from the Pt. Storkersen 1 flare pit and well cellar during and after remedial closure activities. Samples were collected in March 2004. This review focuses on criteria for the following QA/ QC parameters and their overall effect on the data, including: . Holding times . Sample handling (chain-of-custody) . Method blanks . Sensitivity . Surrogate spike recovery . Spike / spike recovery . Field QA/ QC (trip blanks and field duplicates) A total of 21 samples were received by Analytica, Inc., in Anchorage, Alaska and subsequently analyzed for DRO by State of Alaska (AK) Method 102. Several samples also were analyzed for VOCs as represented by benzene, toluene, ethylbenzene, and xylenes (BTEX) by EP A Method 8020B, and for P AHs by EP A Method 8270. All samples were analyzed in accordance with the EP A Test Methods for Evaluating Solid Waste, (USEP A SW-846, September 1986, Third Edition, Update I, July 1992). The QA/QC criteria were taken from the quality assurance program plan (QAPP) which was included as an appendix and the CAP. EPA Laboratory Program National Functional Guidelines for Organic Data Review (February 1994) provided guidelines for data qualification, where applicable. The level of reporting from Analytica was Level I; which includes sample and method blank results, field QC sample results, and surrogate recoveries. Other quality control data (such as spike recoveries), chromatograms, and quantitation reports were not required in the data deliverable. Consequently, results of spike recovery results were not reviewed and calculations from raw data were not verified. The report also did not include instrument performance check results or calibration data. This data was not required in the Level I deliverable. The laboratory case narrative stated that all acceptance criteria for calibrations, method blanks, surrogates, spikes, and samples were met and that all analyses proceeded normally. Holding Times Holding time criteria monitor sample integrity that may be compromised over time. All samples were extracted within their respective holding times. Sample Handling Proper sample handling and chain-of-custody procedures help monitor the integrity of the samples. The chain-of-custody and laboratory case narrative were reviewed to determine if any sample handling procedures might affect the integrity of the samples and the quality of the resulting data. Samples were delivered to Analytica in several coolers over the course of several weeks. It is important to note that all samples were collected in mid-March and were frozen. The temperatures inside the coolers ranged from 3 to 4°C. The coolers were within the desired criteria of 4°C + \- 2°C. Method Blanks Method blank criteria monitor the existence and magnitude of contamination resulting from sample handling processes and/ or ins~ent carryover. Method blanks are prepared and analyzed with each set of 20 or fewer samples of like matrix. Method blanks should not contain compounds of interest above the Practical Quantitation Limit (PQL); however, it is common and acceptable for the blank to contain analytes between the method detection limit (MDL) and the PQL. When this case applies and a result is between the MDL and PQL, laboratories will report values as estimated, and flag the data with a qualifier.- Method blanks were not required as all sampling equipment was disposable. Sensitivity Sensitivity criteria monitor achievement of method reporting limits. All samples met their respective method reporting limits. AN\DOCUMENT2 2 Surrogate Spike Recovery Surrogate spike recovery monitors instrument specificity and accuracy. Samples routinely have surrogate recoveries out of range. This is due either to a high native analyte concentration or to matrix effects. Samples with high native concentrations require several dilutions to be analyzed accurately. This results in the surrogate being diluted to a concentration too low to analyze. This is a common and acceptable practice in highly contaminated samples. No discrepancies were noted in which surrogate recovery values were outside the higher or lower acceptance levels. Field QAlQC Field QA/ QC monitors for sample contamination and overall sampling and analytical precision. Trip blanks and field duplicates were the field QA/ QC samples. Trip Blanks Trip blanks are shipped in coolers containing samples for volatiles analysis. Trip blanks should not contain analytes of interest above the method reporting limit. . Trip blanks were supplied by the laboratory for BTEX analysis. No BTEX analytes were detected in the trip blank. Field Duplicates . Three field duplicates were submitted. This met the QA/QC goal of 1 duplicate sample per 10 field samples collected. AN\DOCUMENT2 3 lIWO StlOdN :> x!puaddv , .> 600090~tO\:>oa' LO~Sl:>\:>NV ) NAME: ExxonMobil Refining and Supply Company ADDRESS: 3301 CStreet, Suite 400 National Pollutant Discharge Elimination System (NPDES) DISCHARGE MONITORING REPORT (DMR) AKG-33-0059 003 PERMIT NUMBER DISCHARGE NUMBER Anchorage, Alaska 99503-3935 FACILITY: Point Storkersen No.1 Site Closure MONITORING PERIOD FROM YEAR MONTH DAY TO YEAR MONTH 2004 01 01 2004 12 Quantity or Loading Quality or Concentration Average Maximum Units 7 -day 30-day Maximum Average Average MGD 3 MGD LOCATION: North Slope, Alaska A TTN: Mike Barker Parameter Flow Sample Measurement Permit Required pH Sample Measurement Permit Required 6.5 - 8.5 Settleable Solids Sample Measurement Permit Required 0.2 Oily Sheen Sample Measurement. Permit Required None None Sample Measurement Permit Required Sample Measurement Permit Required Sample Measurement Permit Required NamelTitle Principal Executive Officer Mike Barker Project Manager F- FI NAL Major or Minor DAY EFFLUENT 31 NO DISCHARGE X Units Standard Units Standard Units , milL milL None None I certify under penalty of law that I have personally examined and am familiar with the information submitted herein; and based on my inquiry of those individuals immediately responsible for obtaining the information, I believe the submitted information is true, accurate and complete. I am aware that there are significant penalties for submitting false information including the possibility of Signature of princi 1al execu~ ffic er or fine and imprisonment. See 18 U.S.C. § 1001 and 33 U.S.C. § 1319. (Penalties under these authorized agent II \.. statutes may include fines up to $10,000 and/or maximum imprisonment of between 6 months and . . ., ,:&. l .5yoars.) . Comment and Explanation of any Violations (Reference all attachments here) No discharges occurred during this period. . # Frequency of Sampleø~e of Analysis Ex. 0 Daily Estimate 0 Daily Estimate 0 Weekly , Grab 0 . Weekly Grab 0 Weekly Grab 0 Weekly Grab 0 Daily Visual 0 Daily Visual -. Date: 9-November-2004 Telephone: 1-907-561-5331 Reserve Pit Closure Approvals for Canning River and Pt Storkersen ') ) Subject: Reserve Pit Closure Approvals for Canning River and Pt Storkersen From: "Peterson, Judd" <Judd - Peterson@dec.state.ak.us> Date: Fri, 05 Nov 2004 08:12:28 -0900 To: "'Mike (Exxon) Barker (mike.barker@exxonmobi1.com)'" <mike.barker@exxonmobi1.com> CC: "'Gary (DNR) Schultz (Schultz, Gary (DNR))'" <gary_schultz@dnr.state.ak.us>, "'Tom (AOGCC) Maunder (Maunder, Tom (AOGCC))'" <tom_maunder@admin.state.ak.us>, "'Webb Bruce (Webb, Bruce)'" <bmce_webb@dnr.state.ak.us>, "'Winters Jack Gack_winters@dnr.state.ak.us)'" <j ack - winters@dnr.state.ak.us>, "Nuechterlein, Linda" <Linda - Nuechterlein@dec.state.ak. us>, "'Louise Smith (E-mail) (Louise Smith (E-mail))'" <Louise_Smith@fws.gov>, "'Robert (CH2MHill) Crotty (Crotty, Robert (CH2MHill))''' <rcrotty@CH2M.com>, "'Okakok Rex (NSB) (Okakok, Rex (NSB))'" <Rex.Okakok@north-slope.org>, "'Terry (COE) Carpenter (Carpenter, Terry (COE))'" <Terry.A. Carpenter@poa02.usace.army.mil> Mike, Please find attached final closure approval for the reserve pits at Canning River A-1 and pt. Storkersen # 1. The signed copy is in the mail. «final closure approvals Nov 2004, ExxonMobil.doc» Regards. Judd Peterson Reserve Pit Closure Coordinator Alaska Department of Environmental Conservation (907) 269-7622 closure approvals N ov 2004, Content-Type: application/msword Content-Encoding: base64 1 of 1 11/5/2004 8: 17 AM FRANK H. MURKOWSKI, GOVERNOR 555 Cordova Street Anchorage, Alaska 99501 PHONE: (907) 269-7590 FAX: (907) 269-7655 http://www.state.ak.us/dec/ DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM November 3, 2004 Mr. Mike Barker Senior Staff Environmental Scientist ExxonMobil Production Company P.O. Box 196601 Anchorage, Alaska 99519-6601 Reference: Issuance óf Permanent Closure Approval for drilling waste reserve pits at exploration sites Canning River A-I and Point Storkersen # 1 on the North Slope Dear Mr. Barker: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for permanent closure approval of the inactive reserve pits at the above referenced exploration drilling sites located on the North Slope. The closure applications and corrective action plans provided the required information describing the history and conditions of the reserve pits, results of required water sampling, and an assessment of the potential risks posed by the drilling waste to human health and the environment. Both sites were inspected by ADEC and the landowner after completion of the corrective actions to confirm the work was completed in accordance with the approved plans. At Canning River A-I, the reserve pit cap was repaired to fill in a surface pond and at Point Storkersen #1, the surface of the previously capped reserve pit was re-contoured and all waste was excavated from the flare pit and the pit backfilled. ADEC has determined that excavated and/or capped pits at these sites do not present a material or probable risk to the public health or the environment. Public notice requesting comments on closure approval was published September 29 and 30, 2004 in the Anchorage Daily News and posted on the ADEC web site September 29th 2004. No public comments objecting to closure approval were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure requirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 G), ADEC grants permanent closure approval to ExxonMobil for all inactive reserve pits at the following sites: Drill Site Name \ ~ ~,~ \:J ~ 1 Canning River A-I \<OC\-O-;"3 Pt Storkersen # 1 API Number(s) 50-179-20005-00 50-029- 20016-00 Location SecI9,T3N,R24E,UM Sec 7, TI2N, RI4E, UM Landowner DNR DNR SCANNEC NOV 0 5 2004 ') ) Mr. Mike Barker ExxonMobil Corporation November 3 2004 Page 2 of2 Terms and Conditions This permanent closure approval is subject to the following terms and conditions: 1) 2) In accordance with 18 AAC 60.440(1), the Department will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. The approval granted by this letter is for the inactive drilling waste reserve pits only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with this decision may request an adjudicatory hearing in accordance with 18 AAC 15.195- 18 AAC 15.340 or an informal review by the Division Director in accordance with 18 AAC 15.185. Informal review requests must be delivered to the Division Director, 555 Cordova, Anchorage, Alaska, 99501 within 15 days of the permit decision. Adjudicatory hearing requests must be delivered to the Commissioner of the Department of Environmental Conservation, 410 Willoughby Avenue, Suite 303, Juneau, Alaska 99801, within 30 days of the permit decision. If a hearing is not requested within 30 days, the right to appeal is waived. cc: Sincerely, Transmitted Electronically Leslie F. Simmons Solid Waste Program Coordinator South Central/Western Alaska electronic only Gary Schultz, ADNR, Fairbanks (Gary_Schultz@dnr.state.ak.us) Tom Maunder, AOGCC, Anchorage (Tom_Maunder@admin.state.ak.us) Bruce Webb, ADNR, O&G Division, Anchorage (Bruce- Webb@dnr.state.ak.us) Jack Winters, ADF&G, Fairbanks (Jack- Winters@dnr.state.ak.us) Linda Nuechterlein, ADEC, Anchorage (Linda_Nuechterlein@dec.state.ak.us) Terry Carpenter, COE, Anchorage (Terry.A.Carpenter@poa02.usace.army.mil) Louise Smith, USFWS, Fairbanks (Louise_Smith@fws.gov) Sheldon Adams, NSB, Barrow (Sheldon.Adams@north-slope.org) Rex A. Okakok, Sr. NSB, Barrow (Rex.Okakok@north-slope.org) Rob Crotty, CH2M Hill (rcrotty@ch2m.com) ~ ExxonMobil Production Com~ .'1 Alaska Interest Organization 3301 "C" Street, Suite 400 Anchorage, Alaska 99503 P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 907 564 3789 Facsimile r-.. April 8, 2004 EJf(on Mobi I Production Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Report of Sundry Well Operations: Hamilton Brothers Point Storkersen #1 Dear Mr. Norman, On behalf of ExxonMobil Exploration Co., we hereby submit its Report of Sundry Well Operations for the wellhead removal and final re-capping of the Hamilton Brothers Point Storkersen # 1 well on the North Slope. This work was conducted in accordance with the AOGCC's Sundry Approval dated February 7, 2004, and was witnessed by the AOGCC's representative, Mr. Jeff Jones. The well was originally abandoned in 1971 by Hamilton Brothers with the wellhead and well marker remaining prominently above the level of the original gravel drilling pad as required by the regulations at the time. Exxon later became the operator of the lease. Thereby, ExxonMobil has undertaken final remediation of the drilling location and, in the process, has cut the well more than five feet below the original tundra level, filled the revealed void spaces in the casing annuli with permafrost cement and welded on an identification plate. The remaining well stump with identification plate is now buried under clean gravel. Attached please find: Form 10-404: Report of Sundry Well Operations Daily Report of Well Operations Photographic documentation of the well before, during and after the work ExxonMobil intends to host an agency inspection trip to the Point Storkersen #1 site in late summer 2004. AOGCC is invited to participate in that trip. ExxonMobil will contact AOGCC staff in the next few months to confirm this trip. If you have any questions or require additional information, please contact me at 564-3691. Sincerely, llL '¿p.L-- Mike Barker Environmental Associate enclosures RECEIVED APR - 9 2004 OR\G\NAL Alaska Oil & Gas Cons. Commission Anchorage A Division of Exxon Mobil Corporation 1. Operations Abandon SUSpend ?""""'ed, A'" Casing 0 e."". We" 0 Change Approved Program 0 Pull TUbing 0 2. Operator ExonMobil exploratIon Company Name: 3. Address: p.O. Sox 196601 AnChorage, AK 99519-6601 7. KB Elevation (ft): r'\ STATE OF ALASKA ,.-." ALA, 'OIL AND GAS CONSERVATION COM~. .clION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development 0 Stratigraphic 0 Perforate Waiver Other .,/ Stimulate 0 Time Extension 0 See Sox 12 below Re-enter SUspended Well 0 - 5. Permit to Drill Number: 169-033 8. Property Designation: 26.5 ExPloratory 0 ServiceD 8:.APl Number: . 50-029-20016-00 9. Well Name and Number: PoInt Storkersen #1 AOL 34623 11. Present Well Condition Summary; Total Depth Effective Depth Casing Structural Conductor SUrface intermediate PrOduction Liner Perforation depth: 10. Field/POOI(S): measured 11.473 feet - - true Vertical 11.470 feet measured 0 feet - - true vertical 0 feet EXPloratory Plugs (meaSUred) Plugged at surface Junk (measUred) - N/A - - length 65' 275' 2.031' 10.792' Size 16" x 24" (thermos) 11-3/4" 8-5/8" 5-1/2" MD 65' 275' 2,031' 10,792' ND 65' 275' 2,031' 10,792' Burst CoUapse Measured depth: N/A RECEIVED APR - 9 2004 Alaska Oil & Gas Cons. Commission Anchorage - True Vertical depth: Tubing: (size, grade, and measured depth) - N/A Packers and SSSV (type and measured depth) N/A 12. StimUlation Or cement squeeze summary; Intervals treated (measUred): N/A T'.elment """",",", indudlng VO~m.. 'oed and fine, .",,"re, ,"..." C"'nos ..... CUt off.t S' below """'na' fund.. ...de'nd," ann.." e..... "".. - _en! '<om the e.<fa... PIA....,..,. pie.. Ine.."... 13. "-"""'IIve Dany A""...a Prod"",," O"';-" Da.. Oi/-Bbl Gas-Met Water-Sbl Casing PresSure TUbing Pressure Prior to well operation: 0 0 0 0 0 SUbsequent to Operation: 0 0 0 0 0 14. Attachments; 15. Well Class after proPOsed Work; COpies of Logs and Surveys Run NIA ExPloratory0 Development 0 Service 0 Daily Report of Well Operations - - 16. Well Status after proposed work; Plugged and Abandoned Attached - - Oi/O Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 17. '-Y "",ty !ha!/he to"SoJng;s "". and ""'"" to /he.... nf my~. ¡Sundry Number or N/A if C.O. Exempt: 304-034 Contact Mike Sarker Printed Name MikeSarker S~natu", "lt1.: ~ .~ Form 10-404 Revised 12/2003 Title Phone Environmental ASSocIate 564-3691 Date k¡ 4.. 9,bo'l- R9DMs BFl A~ 1 , ?nn4 ~ /"""""\ Daily Log Pt. Storkersen #1 Wellhead Cutoff Day I - Tuesday, March 16,2004 Arrived Deadhorse at 1300 ills. Visited site to ensure access to wellhead was unobstructed - OK. Visited GBR, arranged for welder to attach weld-o-Iet to 8-5/8" casing for hot tapping. Took custody of hot tapping equipment from Jack Keener (Fairweather field foreman). Met welder at site at 1900 ills. Welder attached weld-o-Iet to 8-5/8" casing exposed at wellhead and departed. Hot tapped the 8-5/8" and 5" casing strings. Both were empty of cement, fluids and ice and contained no pressure. AIC night supervisor dug out hole around wellhead. Day 2 - Wednesday, March 17,2004 Visited GBR, arranged to have a welder at the site in early afternoon. Took custody of gas sniffer from Jack Keener. Purchased additional sniffer hose at Brooks Range Supply. Visited AIC offices. Met with Mike Waddell- safety rep. Went over safety issues and agreed on which parts of the wellhead removal JSA each of us would write. Traveled to site. Held safety meeting with all hands. Checked exposed annuli at hot tap with gas sniffer. At 1600 hrs, welder commenced cutting on casing at 6' BGL. Job complete at 1900 hrs. Annulus contents observed at surface: 24" x 16" Insulation 16" x 11-3/4" Cement 11-3/4" x 8-5/8" Ice 8-5/8" x 5" Ice 5" Top 20' empty, cement below Day 3 - Thursday, March 18,2004 Arranged for Halliburton batch cementing unit. Consulted with AOGCC, both in Deadhorse and in Anchorage, regarding how to re-abandon the well with cement. Got AOGCC concurrence and agreed on plan. Discussed with ExxonMobii. Visited site. Chipped out and cleaned up casing stump as well as possible. Visited Halliburton to check on status of cementing unit. Went over cementing plans and anticipated volumes with Halliburton personnel. Halliburton cementing unit and AlC water truck and vac truck arrived on site at 1930 hrs. Rigged up to cement, hold P JSM. Mixed and pumped 100 sx (17 bbls) of Class C permafrost cement. Most cement went into the 5" casing and the outer annulus (insulated conductor). CIP at 2210 hrs. Cleaned up and rig down. Off location at 2330 hrs. ,,-..., ~ Day 4 - Friday, March 19,2004 Met AOGCC rep and welder on site at 0800 hrs. AOGCC rep Jeff Jones inspected cement on/in the well and approved it. He then had the welder set the well marker plate in place and photographed it. He arranged with ExxonMobil rep, Mike Barker (also present) for an AOGCC rep to be included in a planned August field trip to the site with DNR and ADEC personnel so that he could inspect the site in general and recommend AOGCC's approval of final site close-out. AOGCC left the site and the welder welded on the marker plate. Inspected welding job, approved job. 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' i ~ ~ ~~ . ~~ !~@ ~~. c X~^ ~ ~.S` ~ 1~.' ~r 1 ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg, Î?-41 41b (tA P. I. Supervisor DATE: March 19, 2004 FROM: Jeff Jones P. I. Supervisor SUBJECT: Surface Abandonment Point Storkerson #1 Exxon PTD #169-033 March 19,2004: I traveled to Exxon's Point Storkerson #1 well location to inspect the casing cut off and abandonment of this well. This well was originally drilled by Hamilton Bros. Oil Co. in 1969 and permanently abandoned on 9/29/1971. On 6/1/1973 Exxon became the operator of record. Fairweather E &P Inc. engineer Bill Penrose was the Exxon representative at the site today. The well has 16"x 24" double wall insulated, 11 3/4",85/8" and 5 1/2" casing strings at surface. I verified that all casing strings had been cut off at approximately 5+ feet below mud line datum and all were found to be full of cement. A 3/8" thick marker plate was welded to the outermost 24" conductor with the required information bead welded to it. Because the fill was possibly contaminated with debris and unknown material it will be remediated prior to backfilling and the excavation was not filled at this time. I made arrangements for the on-duty AOGCC inspector to be present during a planned visit in August 2004 for a final location clearance inspection to verify compliance with AOGCC regulation 20 AAC 25.172. Summary: I inspected the surface cement plug, casing cut off depth, and the P&A marker plate on Exxon's Point Storkerson #1 well and found all to be in compliance with AOGCC regulation 20 AAC 25.120. Attachments: pt. Storkerson #1 cutoff.JPG pt. Storkerson #1 marker plate.JPG pt. Storkerson #1 well head.JPG x Unclassified Classified Unclassified with Document Removed .~ ~: w ~:~ ~ _ ' - ` a ~ Wellhead and Marker Post Below ground level cutoff Marker Plate • Point Storkerson #1 (ExxonMobil) Surface Abandonment Inspection Photos from AOGCC Inspector Jeff Jones March 19, 2004 /&1-033 ~ "IT ffi~ 1]" Œ (ID~ í~\ '1 /~ (~ '{( I~\ lrù ~u~u æJ~. ûu Û , j ¡ ¡ I I ! f I /' í ¡ I FRANK H. MURKOWSKI, GOVERNOR A',A~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 March 17,2004 Mr. Mike Barker Environmental Advisor ExxonMobil Production Company P.O. Box 196601 Anchorage,AJ( 99519-6601 Dear Mr. Barker, By letter dated January 16, 2004, the Alaska Oil and Gas Conservation Commission ("Commission") responded to ExxonMobil Production Company ("ExxonMobil") plans for the final site closeout of the Pt. Storkersen #1. The Commission specifically addressed plans to dispose of excavated wastes fÌ"om the flare pit and existing well marker in the BP-operated Grind and Inject (GNI) facility at Prudhoe Bay. On March 15, 2004, ExxonMobil requested reconsideration of the requirement to test "any materials excavated from the re-abandonment" of Pt. Storkersen # 1, an effort the Commission requested to determine the content of excavated materials and to confirm they are not hazardous. In support of the request, ExxoMobil provided a copy of correspondence involving similar abandonment work at Sag Delta #1 and #2, where the Commission has previously allowed excavated waste "proximate to the wells" to be disposed at GNI. The Commission has reconsidered the plan for re-abandonment and disposal of excavated materials and we concur that testing of the recovered material is not required prior to disposal at GNI. As noted in the Sag Delta # I and #2 approvals, the contaminant in gravel proximate to the well is likely from downhole or was in contact with fluid that came from downhole, making it eligible for disposal in the Class II GNI wells. < cc: Mike Bill, BPXA (P.O. Box 196612, Anchorage, AK 99519-6612) , ., . "~'MÅR.J5:2ÒO4' 9~Ö-3at;::',>EixoNMOBIL J ':,'1 ;'¡~~:~£i"5~~~¿;<';':" :.' , J' ,'., ", ",:.:,' ,~, '~O.Vf5K'~ P."', 1,'/' ,', ; " " ,,!,; " , <'" , , ", , ;~;',; í:XxOnMobil ;'>~:d' ',. ,P.O. Box 1965Qf, ':' ' , Anchorage~~ ~.~51' 9~6601 ,'" , " , " .;, , . ""~¡ <, <', ~, ,: " '> , ; "':Çj;~~", , , 'At ' , ~tJ , " rJlR 1 "',: " ' , ' Aif...o.., ' ..( '$" ? ' , ' , ,~Qt,~' , <VO,r' ",'" " ' ", ',~"" " ,°", ' ,', . , , , " ',' '" " , Fax Cover Sheet " . TO: ~ " "'Company' , : 'Fax: Phone: ' ~; IY\ . ,R-~5"." A 0. 6 ~ Q... ", ". ", ;¡ 710 :.. Î 542-' , '- , " ',' . ,FROM: ,A{ i 1<.t. Va.A ~ , Company.:~' Exxort~obil "" :-~ , Fax: (907) 564-:3789 Phone: (907) 561.5331 Date: M 0-i/1,h- l '5 I lroo L.{ - Totar PaGes: :3" ì f\ ~ Iv d., ")J ~()\f-(r '.! " , , Commetits~ CONfJDENTIALITY.,NOTICE: THIS TRANSMliTAL IS INTENDED ONLY FOR THe USE OF 'THE INDIVIDUAUENTITY TO WHOMIWHICH IT IS ADDReSSED, AND MAY CONTAIN INFORMATION THAT IS PRIVILEGED, CONFIDENTiAl, AND/OR EXEMPT FROM AGENT RESPONSIBLE FOR DELIVERING THE TRANSMITTAL TO THE INTENDED RECIPIENT. OR THE EMPLOYEE OR RECIPEINT, THEN YOU ARE HEREBY NOTIFIED THAT ANY EXAMINATION, DISCLOSURE. COPYING, DISTRIBUTION. OR THE TAKING OF #4Y ACTION IN RELIANCE ON. OR WITH . RESPECT TO, THE CONTENTS OF THIS TElECOÞIEO INFORMATION IS STRICTLY PROHIBITED. ' IF YOU HAVE RECEIVED, THJSTRANSMITTAL IN ERROR, THEN PLEASE IMMEDIATELY NOTIFY THE SENDING PERSON BY COLLECT PÈRSONpTO.PEF{SON TELEPHONE CALL TO ARRANGE FOR RETURN OF THE ORIGINAL TRANSMITTAL DOCUMENTS TO US AT OUR eXPENSE. THANK YOU. H;\Data\DocG\F;x CoverSheel8\S ()(onMobII F&JC COver Sheetdoc 10/15/02 .~",O3,~1~~AR. 15. 20041 9:O~AMbö,4 ~EXXüNMOBIL I ',' , ' " - , ,; , " , ¡,' ' ,'!O " ,--, , .' ',~ " ,'" , \ jrD n~"1"'CIo,,",,"1o , ' - Nü.9255 : '!Þ¡-\t .~g Monerleft. J,.son M ' ,;,,\r~_-,:,._.. -- -, , "" -::;, To: Cc: ',SJlbJect; , Kany, Geoffrey S. - , 'Saturday. February 23, 200211:17 AM Moncrieff. Jason M - , , ,Chatham, James R~ GPB, Environ Advisor (Services) - -c~ /:W:AQGCO Conflf'n'lation -~ Sag Delta 1 and 2 - ' - -. ,- Ii Card fot' Tom M3under cc: '---,--Original M88sa;e-...--- . Pr9œ: Tom Maunder [mailto:to~underaaâmdn.state.ak.us) ~ent: Frida)', 'rèbrúary 22i' 2002-5:31 PM To: Chatham, James R ' " Cc: Kany, GeoUrey S.; Cat!imy Oechdi ' - Subject: Re: AOGCC Confirmation - Sag Delta 1 and 2 c' Jim and Geof, , Thanks for meeting w,ith me ~esterQay. ! do apprec:ì,ate your coming ove:r:' op such short no~ice. AS I indicated, I had wanted to revisit the information ~e~arding the oil contaminated wa$te looated prOXimàtè to the wellbores at the Sag Delta 1 and Sag Delta 2. - Following our meeting I was able to discuss the mQtte~ with commissioner Taylor. . I remember reviewing the report you hàd prepared regarding the remediation and recovery project. Areas of cont.fJt\ination had bBl':i!n loèated at about 3 d1fferent loci\tions at each pad, The waste areas not pro,,5.mate to tho wells (-15000 cu yds) is planned to be tbèrmally ~emeàiated and that is appropriate. ,¡,1ie .waste proxi~t.A~o: tne tiel1-s-t-,90ÐO :/ZU yds) .is-wasbtr.e$ultant. from E&P t:~~!~~~~9 -. :~:. "'~~1: ;:~;::~=:~.~f~i ~~6i:l å~~~~; :~~ cÜ;hi~~~ c~¡ ~rd U~~d in unåe~balance thè-wellto.f'low. -It. i-slLIJelY thã.ttne contaminant was from â~'bol, or was in. -cønt.~Gt-with tlu.ielJ;h&téame fxom d.o ollIÙlole. On:--¿thbbas1St t1\.~planYO\\'haVé'fbr'.4bþOa-~ng. of-the '$o1:id$ thàt were proxilft4\-te to' 'DJe 'Wèllbòre:.~t-.Q'6io! iÌ;l:iiþþ~riäti'e~; . 'l'hank~ for providing the information with regax:dl:.o this matter. Good luck. wj.th the :remediation project. . . Tom Maunder, PB .. Sr. Petroleum Engineer AOGCC .Chatham, James R" wrote: > Jason, > > I spoke with Tom Maunder (AOGCC) ~his morn~ns regarding hia voice-mail > response to Geaff Kãny, seeking eon!irmation of our intention to P&A the Sag > Delta 1 and 2 wells. I assUred Tom that the wells would be fkA'ð, as part of > the pad abandonment process, and that the Sundry Notices had been submitted. > I also confirmed with Tom our intorp~Qtatìon of the diesel-contaminated > g~avel associated with the well-bores as Class II eligible. and our > intention to grtnâ-and-inject the material at the G&I p1ant (DS 4 facility). > ~y other diesel contaminated material would be thermally treated. Tom > confirmed that the well-bore associated material could he delivered to the > G&I plant for injection. , > > Jim Chatham > ~ BPXA Remediation Advisor 1 >, ',' " ",.' l . . 1Î~l!MAR. 15, 2004~ 9:ÔjÁMJ!LEXXONMOBIL~rÞ IIIANJ\\¡r,t¡JIS~ru . . . ..,'...' . "'0 ' . . ~ ~, t' ,~ "'" "i ~ . ~, '- .... ~, ~ '- ~..;. -" NO, 9255 p, r' '. ,"" bp~' , " ' , "0'" " , " , . , .. ' , . ,', ,,' ê ,'f ~' . ;' , , .,..' ,,' SP EJIpI0f6t1on ~llfIC. I!OO e.~ BOlIIIòn BoUIMrd 1'.0, 'OK 18tJ1i12 .QtICI\o~gt. AIUki MG1ø.aG\2 18071 &81-5111 December 17. 2001 ' " " , ' Mr. TomM'lunder' , . '. ' ' . Alaska Oí~ and Gas Coosèrvatiol'\ COmmission,' ' 333 W, r"Ave.No.100 .' ' AnchorageJ AK 9956-$539 Certified Man No. 7001 0360 0000 6101 5989 $\I~roittal 9f Corr,p~v,'Actlon Plio. fór aaa D,Ita 1 and 2J2A Drill Sites Dear Mr. Maunder: BP Exploration (Alaska) Inc. CBPXA) respectfUlly submits the attached plan for corrective action at the Sag DettA 1 and 2I2A inactive e)(fJloration drill sites. The plan was previously $ubmitted to the Alaska Department of Environmental Conservation (AOËC) November 28,2001. Site cleanup and closure will be performed under the AOeC Solid Waste program regulations. The proposed correotive action is described in only one document since the two sites are very simílar in construction layout and wast. distribution, they are separated by a distance of only 1.2 mile. and will be excavated .tmul.neou¡ly, and they wm be accessed via thli! same iëe rqac;i. The activity is planned for this Spring (February and/or March, 2002.) and wilt include excavation 01 the waStes from the reserve pits and flare pits I and removal of the gravel pàds and berms frol'\") each location. Permit aþplications have be1n submitted to thG appropriate agencies; all permits will be acquired prior to the initiation of field activities. As díscuased in the plan, the exempt drilling wa$te is scheduled for UIC Class \I injection via grind and injection (G&') at the Drill Site 4 facility. Diesel-contaminated gravel is al$o present on the pad. The source of the diesel appears to be assocIated with down-hole, drilling.related actiVities. It is BPXA's interpretation that this contaminilted gravel is Class 1\ etigible materia\. This document provid&s notifice.tion to the Alaska Oil and Gas Conservation Commission (AOGCC) ot our intent to inject the contaminated gravel via G&f at the Drill Site 4 facUlty. in well$ permitted in Area Injection Order No. 4-6. AI! other contaminated gravel from the pads wm be removed sod thermally treated. Please contact me at (907) 564~SS41 or Geoff Kany at (SO7) 564-4965 if you have questions or comments regarding thi9 plan or schedule. Sincerely, ' ~ fj- A¡}/Î It ~ f.,I!abfWJ.";;:' UJames R. Ch;¡¡,tham, Ph.D. Remediation Advisor. HSE-Alaska ExxonMobil Production Company Alaska Interest Organization 3301 "C" Street, Suite 400 Anchorage. Alaska 99503 P.O. Box 196601 Anchorage, Alaska 99519-6601 907 561 5331 Telephone 9075643789 Facsimile February 4, 2004 EJf(onMobil Production Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Attention: Acting Chairman Re: Application for Sundry Approval: Remove Wellhead and Install Subsurface Abandonment Marker, Hamilton Brothers Oil Company, Point Storkersen No.1 (P & A 9/29/1971) Gentlemen: The above referenced application is attached for your review and approval. Please note that the operations program includes both a "Preferred Procedure" and an "Alternate Procedure". The preferred procedure involves the use of a Wachs, Guillotine Saw, the availability of which is uncertain at the time this application /' is being submitted. In the event the Wachs Saw cannot be obtained, the alternate procedure provides a means to safely meet the project objective. Thank you for your timely review of this application. If you have any questions please contact the undersigned at 564-3691, or Bob Gardner at Fairweather E & P Services, Inc., at 258-3446. Sincerely IM~~ Mike Barker Environmental Associate Attachment (in duplicate) RECEIVE:O FEB 0 4 2004 Alaska Oil & Gas Cons. Comml5sion Anchorage S(~AlNJ~~Et.'/ \FEE 1 8 2004 ORIGINAL A Division of Exxon Mobil Corporation Abandon Alter casing 0 Change approved program 0 2. Operator Name: , ExxonMobil Exploration C~mp~ 3. Address: P.O. Box 196601 Anchorage, AK 99519-6601 7. KB Elevation (ft): 1. Type of Request: 26.5 ft 8. Property Designation:' ADL 34623 11. Total Depth MD (ft): 11473 Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): N/A Packers and SSSV Type: None WG A- z../sl 2,.00 tf /) v5 2/5/1-- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown Plug Perforations D Perforate New Pool D 4. Current Well Class: Suspend Repair well 0 Pull Tubing 0 Perforate Waiver Annular Dispos. Stimulate D Time Extension 0 .Otheri] Re-enter Suspended Well D ** See Below 5. Permit to Drill Number: Development Stratigraphic D 0 Service Exploratory ~ D 169-033 /" 6. API Number: 029-20016-00 #'/ 9. Well Name and Number: Point Storkersen No.1 r 10. Field/Pools(s): Total Depth TVD (ft): 11470 Length Exploratory PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): . See AOGCC Well file Junk (measured): See AOGCC Well file Collapse Burst 0 0 Size TVD Perforation Depth TVD (ft): RIA Tubing Size: None Tubing Grade: RIA Packers and SSSV MD (ft): N/A Tubing MD (ft): RIA 12. Attachments: Description Summary of Proposal Detailed Operations Program ~ BOP Sketch 0 14. Estimated Date for "". Commencing Operations: February 15, 2004 16. Verbal Approval: Date: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike Barker Printed Name 564- 3691 Title Environmental Associate Signature e' Date z,(t{ ÞI( COMMISSION USE ONLY 13. Well Class after proposed work: Exploratory ~ Development 15. Well Status after proposed work: oilD Gas 0 WAG D GINJ 0 0 Service 0 0 D Abandoned WDSPL @ D Plugged WINJ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D Sundry Number: .50 -t?3-1 BOP Test 0 ~ E~" C'" E...' ; \./~::.' - fi J (,.." FEB 0 4 2004 0 Mechanical Integrity Test Location Clearance Other: ~t;A¡NH~E[ì FED], B 2004 ". ,-.- ~'"':"'" J~""i."'" ~~i~~1 .~..)..tI ;..0-:" "i.~~ ',.. 1,.~~~.~"'7\" <I ..,. ~ ,". ... æ O~ 160~ 0 ~ , ~, ~,~ , Alaska Oìl & Gas Cons" Co~n::(n:1~~¡(!)n Anc:horage BY ORDER OF THE COMMISSION Date: /-'2,.. ** Cut casing, recover wellhead, and install subsurface abandonment marker plate Submit in Duplicate Operations Program Removal of Wellhead and Installation of Subsurface Abandonment Marker ExxonMobil Exploration Company (ExxonMobil) Point Storkersen No.1 PTD: 169-033 Current Well Status: Plugged and Abandoned (9/29/1971) Back~ound. and Summary of Work to be Performed The Point Storkersen No.1 well was drilled by Hamilton Brothers Oil Com~y in 1969 and suspended. The well was permanently abandoned on September 29, 1971. Effective June 1, 1973 Exxon Company, U.S.A. became the operator of record for the well. When the well was abandoned in 1971 a marker post was installed on a blind flange which was bolted to the upper wellhead section after the production tree was remov~,. The downhole plugs and abandonment procedure were approved by.the AOGCC at that time. The well has remained in this condition since 1971. A considerable amount of gravel has been scavenged from the pad to backfill the reserve pit and regrade the site to promote drainage. The net result has been that. the marker post and remaining wellhead sections are now in a residual cone of gravel that rises / above the surrounding pad surface. ExxonMobil will complete the final closure of the Point Storkersen site in early 2004. A component of the final site closure work is the removal of the marker post and remaining wellhead sections, and the installation of a subsurface marker plate. The following paragraphs describe the proposed wellwork: Detailed Operations Program All. depths referenced herein, unless otherwise noted, are original RKB, which was + 26.5 ft MSL. Figure 1 shows the details of the previously approved P &A work. The Proposed operation consists of severing four (4) strings of casing at a point no less than (5) / feet below the original tundra surface, and the installation of a subsurface steel marker plate in accordance with 20 AAC 25.120. NOTE: The work described below will be performed in a confined space environment. Personnel performing this work must be confined space trained, and an ExxonMobil approved JSA must be performed before work is started. All work shall be done in conformity with the Confined Space Entry Standard, as defined in the 2002 Alaska Safety Handbook ("ASH", or the "Yellow Book") Figure 2 shows the present condition of the upper part of the well. The casing strings to be cut are described as follows: Structural Casing: 16"x 24" double wall insulated casing cemented to surface at 65 ft. Cement placed from the top. Conductor Casing: 11 0/4", 42 lb., cemented to surface at 275 ft. Surface Casing: 8 5/8", 36 lb., cemented at 2031 ft. No record of cement returns to surface. Well record only mentions "good returns" during cement job. t'Ïotal of 1370 sxs were pumped. . Production Casing: 5 ~", 17 lb., cemented at 10792 ft with 450 sxs, and cemented to surface ,-/ through Halliburton DV tool at 4000 ft. Casing is filled with cement from 820 ft to surface (top plug). Preferred Procedure: 1. Remove blind flange from wing valve on wellhead, and prepare to check 8 5/8" x 11 0/4" annulus for pressure. If condition of original wing valve is in question, install secondary wing valve after removing blind flange, and before opening the original valve. Crack /" open both valves and bleed off any pressure in 8 5/8" x 11 %" annulus. 2. Excavate around well to approximately 9 ft below original tundra surface to provide working room for casing cuts. Have excavated material (both pad gravel and native soil) tested for hydrocarbon contamination by on-site laboratory technician. If excavated material is clean, retain in stockpile for backfill after work is completed. If the material is contaminated, handle as directed by the ExxonMobil on-site representative. 3. Rig up Wachs Guillotine Saw on 24" outer wall of insulated casing such that casing cuts will be approximately 6 ft below original tundra surface. 4. Attach slings to wellhead and make up to forklift or excavator bucket (both should be on location) such that wellhead is supported and under positive tension. 5. Activate Wachs Saw and sever all strings of casing. Remove cut-off sections and /" wellhead, and lay down same. 6. If 8 5/8"X 11 %" annulus is un-cemented, and not filled with ice and/or frozen mud, batch mix permafrost cement, and plug annulus from the top. If the annulus is cemented, or ,/ contains ice and/or frozen mud, proceed to Step 7. 7. Prepare a steel subsurface abandonment marker plate. Plate should be 24"x 24"x 'l4", and the following information bead welded on one side. Letters to be minimum of 1 " high. Hamilton Brothers Oil Company Point Storkersen No.1 PTD No. 169-033 API No. 029-20016-00 // 8. Lay plate over casing stubs and head weld the plate to the outennost (24.) casing. 9. Backfill the excavation with clean material. The pad will be regraded to provide positive drainage as part of final site closure operations. Leave a mound of material approximately 2 ft high over the backfilled excavation area to allow for future settling. Figure 3 is a schematic diagram of the completed work. (" Alternate Procedure (to be used only if Wachs Saw is unavailable) 1. Remove blind flange ftom wing valve on wellhead, and prepare to check 8 5/8" x 11 %" annulus for pressure. If condition of original wing valve is in question, install secondary wing valve after removing blind flange, and before opening the original valve. Crack open both valves and bleed off any pressure in 8 5/8" x 11 %" annulus. 2. Excavate around well to approximately 9 ft below original tundra surface to provide working room for casing cuts. Have excavated material (both pad gravel and native soil) tested for hydrocarbon contamination by on-site laboratory technician. If excavated material is clean, retain in stockpile for backfill after work is completed. If the material is contaminated, handle as directed by the ExxonMobil on-site representative. 3. Cut a 3 ft long section out of the outer wall (24") of the insulated casing to expose insulation. Bottom of section should be approximately 6 ft below original tundra surface. Break out insulation to expose inner (16") casing wall. ~ 4. Cut similar section out öf 16" inner wall of insulated casing to expose cement in 11 %"x ,,/ 16" casing annulus. Bottom of cut-out section should be level with cut in 24" outer wall. Break out cement to expose 11 0/4" casing. 5. Cut similar section out of 11 %" casing to expose cement (if any) in the 8 5/8" x 11 %" /' casing annulus. Bottom of cut-out section should be level with the two previous bottom cuts. NOTE: The reduction in working space as progressive cuts advance inward may limit the size of sections that can be removed. Make all size reductions at the top of the sections such that all bottom cuts are level. a) If there is cement in the 8 5/8" X 11 %" annulus, break out cement to expose 8 5/8" casing. If there is no cement in annulus, remove any dessicated and/or frozen /' mud, and proceed to step 6. 6. Cut similar section out of 8 5/S" casing to expose cement in 5 ~" x 8 5/8" casing annulus. The bottom of the cut-out section should be level with previous bottom cuts. Break out cement to expose 5 ~" casing. 7. Before cutting 5 ~" casing, attach slings to wellhead and make up to forklift or bucket of excavator (both should be on location), such that wellhead is supported and under slight tension. Make single cut in 5 ~" casing at a point level with all previous cuts at the bottom of removed sections. Be sure all persons are clear of excavation before "working" wellhead with forklift or excavator to break cut-off sections free. Remove cut off sections and lay down same. .".--// 8. If 8 5/S"X 11 %" annulus is un-cemented, and not filled with ice and/or frozen mud, batch // mix permafrost cement, and plug annulus from the top. If the annulus is cemented, or contains ice and/or frozen mud, proceed to Step 9. 9. Prepare a steel subsurface abandonment marker plate. Plate should be 24"x 24"x ~", and the following information bead welded on one side. Letters to be minimum of 1 " high. Hamilton Brothers Oil Company Point Storkersen No.1 PTD No. 169-033 API No. 029-20016-00 10. Dress casing cuts as necessary to allow the plate to lay flat over casing stubs. Bead weld the plate to the outennost (24") casing. 11. Backfill the excavation with clean material. The pad will be regraded to provide / positive' drainage as part of final site closure operations. Leave a mound of material approximately 2 ft high over the backfilled excavation area to allow for future settling. Figure 3 is a schematic diagram of the completed work. Figu.re 1 Wellbore Schematic Hamilton Brothers Oil Company Point Storkersen No.1 (P &'A9/29/71) PLU~GED '5-1/2" CASING FROMIJ SURFACE to 820'W/175 SKS. '.. .' , " .' .' , . . CASING LEFT WI 11.7 PPG MUD INSIDE . . . . PLUGGED 5-1/2- CASING FROM '5660-59951" . W/.IPO S,K$. Pg:~fQ~~TJ.Q~.S J.ci;~~9 -10.410i' SQUE',EZED W/.100 SKS. I ,',' .e~REQa4TI.oN,$ JO .495 -10,5p5 SQUEEZED W/75 'SKS. .' PERFORATIONS '.,0.580 -10,640' .'. SQUEEZE;D 'W/.100 SKS. , . '. I CAST IRON BRIDGE PL:UG at lO,742 .., . . , PLUG No.1: 10,912-l0;750 W/4.6 SKS. . 10,742' PBD ,', TD at 111~731 II f6"x 24;'01 65'CMT to SURFACE W/254 51 ;~-~~~"~2~~1 CMT TO SURFACE W/as/ SK . ~, . ,'. , , . . '", . ~ . . . 8-5/Såt 2031' CMT W/1370 SKS. H,ALL,aURTON DV TOOL ,of 40001 CMT TO SURFACE '.Y/550 SitS-;... ,.. '-;"'''' ' ",. ."., .. .... . .. . CUT 2-7/8" N-ao T8G. at 6000' AN,D PU'LLED . TUBING and ANNULUS CEMENTED FROM 6182 to 7350' WI 100 SKS. 10:0 SK. CMT. PLUG FROM 74201 to 8640'.. , . . ()11'S"ftÞ~''''XO 1 SID£ OÖÖR SLEEVE at 10,5431 OTIS TYPE IIN. NIPPLE 01.10.5541 W/PLUG IN PLACE ,', BAKER, MODEL liD" PACKER~t ~qp5UI \\1J re rm EN~ of TUB ING a~ IO.5fID ¡;.1Ii ~ ." IÞ UJJ' '. .. ~ MAR i. 1\9.74 . . . DMSION OF OIL AND ~S ,', ,'., '. ANCIIORAGF. - , ' . 5::'1/2" at 10,7921 CMT. WI 450 SKS. , . . ' .. R. S. 2 - 20 - 74 LEGEND ~ ~ [f] NO SCALE Cement Insulation Abandonment MarkGr Post Annulus contents unknown Blind Flange .~:: ~::~'. .:.. : . .... . T{-%~!~. ~....._N",."':.': ". . .:. 0\ 24" x 16" Double Wall Insulated C( 8lng Cemented to Surface .. :: jI~~f!; l' . l' ¡" ~..::: ,':'~J ' ?'? , : ~~'..g.i.f:'~ . Surface Shoe CD 65' 11 3/4" Cemen led to Surface from Shoe 0. 275' 8 5/8" Cêmêntêd to Unknown Depth 'from Shoe a 2031' 5 1/2" Cemented from 4000' to SyrrOce FAIR/HA~ILTON BROTHERS/PTSTORI<1.DWG 1:1 2/3/04 SSR Figure 2 Hamilton Brothers 011 Company. Point Storkersen No.1 Present Condition (1/22/04) of Upper Part of Wellbore NO SCALE LEGEND ~ Cement ~ Insulation dSÒ po~ ~~~!...(MouncJ~Yer 8xcav~o.!!. ~ea) ~~-- ----- ~- -- -~ / 24" x 16" Double Wall Insulated Casing Cemented to Surface Shoe 0 65' 11 3/4" Cemented to Surface from Shoe U» 275' a 5/8" Cemented to Unknown Depth from Shoe 0» 2031' FAIR/HAMILTON 8ROTHER5/PTSTORK2.0WC 1:1 1/2.7/04 SSR Fi gure 3 Hamilton 8ro~hers 011 Company, Poin~ Storkersen No. Fino I Co ndition DE0-17-2002 TUE 03:48 PH RK ?hURT SYSTEII , F~X NO. , i 11,n.72640720 P, . .,' IN THE SUPERIOR COURT FOR THE STATE OF ALASKA , · . , TH, IRD ]UDIC~L DISTRICT AT ANCHORAGE JACK O. I-IAKKiLA, and .' ARCTIC BASIN INDUSTRIES, . P~aintiff, . % ' I , i ¥$. , , , EXXON CORPORATION, et. ai.t , Defendant. ' ~ g, h~arin~ on plabtiff's motion for Tempora~ Res~inin~ scheddled f6r December 20t 2002 at ,[~:00 a,i~. in C6u~room 403 of the Nesbe~ CphlthOti~e: Plaintiffs shall immediately pr~vid~ notice of this ~earlng to all de~en~anb and shall be p~pamd, at the hearing, to provide proaf that such noUce was made. DAT[D at Anchorage, ~laska, this ..~2'/j?j day of December 2003. .' '/', . SuperiorCou~]udge l ~z,,r~/~ #lat on Oec~mberJ~ 2002 A copy Was ma/ted/faxed ~: T, .~70pov/~iJ RECEIVED . DEC 1 9 2002 Alaska Oil & Gas Cons. Commission Anchorage /~.' 01/01 i d IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of: Jack O. Hakkila and Arctic Basin Industries VS. Plaintiffs General American Oil Company Of Texas et al,; Defendants ) ) ) ) ) ) ) ) ) ) .,) MOTION FOR TEMPORARY RESTRAINING AND FOR PRELIMINARY INJUNCTION Case Number: 3 AN-99-9114CI Plaintiffs, by and through counsel, hereby move the court for immediate entry of a Temporary Restraining Order and for a hearing to determine whether the TRO should be converted to a preliminary injunction which enjoins the State of Alaska Division of Oil and Gas and all other defendants, their agents and their successors from terminating lease ADL 34623 or in the alternative, suspending the term of the lease until the principal action in Jack O. Hakkila and Arctic Basin Industries .v. General American Oil Company et al, Case Number 3 AN-99-9144Cl can be heard.. This motion is filed pursuant to Rule 65 of the Alaska Rules of Civil Procedure, 's supported by the Complaint filed by the plaintiffs, the affidavits filed herewith, and tl3e memorandum of points and/~authorities filed herewith. DATED, thi~..~day of December, 2002. Ted Stepovich Stepovich, Kennelly & Stepovich, P.C. 626 K Street A n ch o ra~ge~~~9~501' (907.),279-93/~2 ~Te~ Stepo~ich ' ' ABA No. 8711113 d 0 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE RECEIVED In the Matter of.' ) Jack O. Hakkila and ) Arctic Basin Industries ) Plaintiffs ) VS. ) ) General J~merican Oil Company) o£ ?e2ms et al ) ) Defendants ) DEC 1 9 2002 ,-~laska Oil & Gas Cons. Commisslo Anchorage MEMORANDUM IN SUPPOI~T OF TEMPORARY RESTRAINING AND PRELIMINARY INJUNCTION Case No.: 3 AN-99-9114 CI When the court is' considering a request for a Temporary Restraining Order and Preliminary Injunction, four factors are considered. A.O. Smith Corp. v. F.T.C., 530 F.2d 515 (3rd Cir. 1976). Those are: 1) whether the moving party has shown that it is likely to prevail on the merits, 2) whether the movant has demonstrated that he would be irreparably harmed if the preliminary injunction is denied, 3) whether the grant of the injunction would harm other interested parties to a.greater extent than it would benefit movant, and 4) whether the public interest would be served. When irreparable injury is apparent the need to show probable success on the merits becomes a less stringent standard and the Court applies a balancing approach. Am-~!gnmated Tran. U., v. Sunline Tran. After., 663 F.Supp. 1560, 1564 (D.C. Cal. 1987); See also Brenda v. Grand Lodffe, 584 F.2d 308 (9th Cir. 1978); cert dismissed, 441 U.S. 937, 99 S.Ct. 2065, 60 L.Ed.2d 667 (1979); and William Inglis & Sons Baking Co. v. ITT Continental Bakinff Co., 556 F.2d 86, 88 (gth Cir. 1975). tf balancing' the hardships shows the scales tip heavily toward plaintiffs, in that plaintiffs will be irreparably harmed, a showing of likelihood of success on the merits is less important a burden for the potentially injured party. Brenda, at 315 See also Oakland Tribune, Inc. v. Chronicle Publishin~ Co., 762 F.2d 1374 (gth ce. 1985). Plaintiffs seek a restraining order and preliminary injunction with respect to the above captioned litigation. The State of Alaska Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission are named as defendants in this action and the purpose of this motion is to prevent the termination or the lapse of lease ADL 34623 on December 8, 2002. It is submitted that a temporary injunction is required to preserve the rights of the plaintiffs prior to the hearing of the principal action, to prevent prejudice to the proper determination of the interests of the plaintiffs, to prevent any further acts which will deter any possibility of pursuing exploration and production activities with a view to extending the term of the lease and to prevent any other activities which will unduly complicate matters by introducing additional third party interests in the event that the lease is sold to a third party. As the court' is aware the legal elements for both restraining orders and preliminary injunctions are a probable right to recovery, imminent irreparable harm and no adequate remedy at law. Fasken v. Darby, 134 O & GR 302; See State v. Norene, 457 P.2d 926, 930-931 (Alaska 1969). It is submitted that the injunction are met in the particulars of this motion. The elements of temporary rights of Cliff Burglin and Thomas Miklautsch are clearly established prima facie in the documentary evidence and by the conduct of the parties in addition to the numerous breaches of fiduciary obligation owed to these parties with the result that there is a probable right to recovery. Imminent' irreparable harm will occur if the o leases are permitted to terminate and are subsequently leased to another party as any potential right to exploration and recovery will be lost and there is no adequate remedy at law to prevent the loss of rights upon termination of the lease described as ADL 34623. Where there is a bona fide dispute regarding title to an oil and gas lease a_nd any rights arising under it, issuance of a temporary injunction to maintain the status quo pending trial of the principal case is proper. Little. iohn v. Finder, 1S O & GR 72 (Texas Ct. App., 1961); and Morse v. Earnest, Inc., S40 & GR 323 (Okla. Sup. Ct., 1976). A temporary injunction is required in the case at bar to prevent the termination or lapse of lease ADL 34623 and to preserve the status quo and the rights of the plaints, which rights will be prejudiced by the termination or lapse of the lease and by any possible re-sale of the lease interests to a new third party lessee. The term of a lease may be suspended from the time that the lease's validity is brought into question by a landowner until the date when the trial court rules on the principal action. Where the primary term of an oil and gas lease is due to expire prior to the court's final decision, the term of the lease may be suspended until the final decision is rendered and then thereafter extended for a period equal to the period during which the lease term was suspended. Pennington v. Colonial Pipeline Company, 32 0 & GR 1 (U.S. Ct. App, Fifth Circuit 1968) (emphasis added). It is further submitted that reasonable time should be permitted to comply with such lease terms and what is reasonable' time depends upon the circumstances. Jones et al v. Moore et al., 10 0 & GR 963 (Okla. Sup. Ct. 1959). The title to lease ADL 34623 has been brought into question in the present case and it can be presumed that without the benefit of a temporary injunction being ordered to restrain the State of Alaska Division of Oil and Gas and the Alaska i;;,, 0 Oil and Oas Conservation Commission from terminating lease ADL 34623 or an order be issued to suspend the term to prevent it's lapse, lease ADL 34623 will be suspended prior to the hearing of the principal action. Where, as here, there is a probable right to recover either all or at least part of the tire in question, plus substantial damages through lapse of the lease term, then a temporary injunction may be issued. Garcia v. Sun Oil Company, 70 & GR 1256 (Texas Ct. of Civ. App., 1957). The present litigation has been commenced respecting proper title to lease ADL 34623. The present case was filed in 1999 and has further cast the proper ownership and title to lease ADL 34623 into doubt. The litigation has been Fried as plaintiffs have been frustrated in their attempts to pursue exploration and production of oil and gas on lease ADL 34623. In turn the litigation frustrates their attempt to explore and produce. If a lessee is prevented by litigation from commencing operations within the time stipulated in the lease,, he is entitled to an extension for the time of such hindrance if he is successful in tl~e suit, Greer v. Carter' Oil Co., 25 N.E. 2d 805 (Illinois Sup. Ct. 1940). . ..... ', It is further submitted that the wrongful decision .in October, 1993 by the Alaska Oil and Gas Conservation Commission to exclude lease ADL 34623 from the Point McIntyre Participation Area of the Prudhoe Bay Unit prevented the plaintiffs from pursuing their interest in exploring and producing oil and natural gas on lease ADL 34623. Where a lessee's failure to produce or to commence or continue drilling operations during the primary term is due to the wrongful interference by the lessor, the lessee's failure may be excused and the lease time period extended. Jones et al v. Moore et al., 100 & GR 963 {Okla. Sup. Ct. 1959}. It is the plaintiffs' position that the wrongful decision by the Alaska Oil and Gas Conservation Commission to exclude lease ADL 34623 from the operation of the Point McIntyre Participation Area in the Prudhoe Bay Unit constitutes such interference. Reasonable time should be permitted for a lessee to comply with such lease terms and what is reasonable time depends upon the circumstances. Id. Because of it's exclusion from of the Point Mclntyre Participation Area in the Prudhoe Bay Unit wells on adjacent lands which are part of the unit are draining any potential reserves which may be recovered from lease ADL 34623. A temporary injunction is necessary in order to preserve the status quo until the hearing of the principal action and to ensure that the rights of the plaintiffs' are not further prejudiced. A temporary injunction may be issued to prevent irreparable harm such as where other wells on adjoining lands are draining the lands in question. Simkins v. Maras, 9 O7GR 182 (Illin. App. Ct., 3rd Dist., 1958). It has also been held that a temporary injunction is an appropriate remedy for a lessee out of possession. Petroleum En..~ineers Producing Corp. v. White, 12 O & GR 100 (Okla. Sup. St., 1960). In the principal case, the interests of the plaintiffs .have been denied and as such, they are in effect, lessee's out of possession of their interests. Based on the foregoing it is respectfully requested that his court issue a temporary restraining order barring the State of Alaska, Division of Oil and Gas and/or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002. Additionally, plaintiffs are requesting that a hearing be held and that a preliminary injunction be issued barring the State of Alaska, Division of 0il and Gas and/or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or, in the alternative, an order suspending the term of the lease until resolution of the principal action on the grounds that the said termination will {.. prejudice the proper determination of the interests of Jack O. Hakkila and Clifford Burglin in lease ADL 34623 and will prevent any possibility of pursuing exploration and production activities with a view to extending the term of the lease and will unduly complicate matters by introducing additional third party interests in the event that the lease is sol~i, to another third party. Dated this ~/~' day of December, 2002 Ted Stepovich Stepovich, Kennelly & Stepovich, P.C. 626 K Street Anchorage, Alaska 99501 By: .. Ted §t~po-,Cich t ABA No. 8711113 d IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of.' Jack O. Hakkila and Arctic Basin Industries Plaintiffs General American Off Company of Texas et al Defendants Case No.: RECEIVED 0EC ? 9 2002 4bska Oil & 8as Cons. Commission '~.",chorags 3 AN-99-9114 CI AFFIDAVIT STATE OF ALASKA THIRD JUDICIAL DISTRICT TED STEPOVICH, being duly sworn upon his oath, deposes and states as follows: 1. I have just entered appearance as counsel for plaintiffs in the above- entitled matter. 2. I make this affidavit is support of plaint/frs' Motion for Temporary Restraining Order and Preliminary. Injunction. 3. The matter having been filed pro se and the court having granted pro se plaintiffs' leave to obtain counsel, it is counsel's understanding that the complaint in this matter has not been served on the defendants. 4. Notwithstanding the lack of service as to the complaint, plaintiffs' file for a Temporary Restraining Order and Preliminary Injunction. Counsel has had no communication with those parties, as to the present motion, due to the fact that there -1- has been no service on those defendants. A copy of the motion is to be served forthwith on the State of Alaska, Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission. 5. Notice is not necessary in the present situation based upon the case law and legal precedent as set forth in the underlying memorandum in support of the Motion for Temporary Restraining Order and Preliminm'y Injunction. The sole purpose of the underlying motion in the present case is to preserve the status quo until the present case is heard on its merits. DATED this __ day of December, 2002. Ted Stepovich ABA No. 8711113 SUBSCRIBED AND SWORN to before me this_ day of ..,2002. Notary Public for the State of Alaska My Commission expires: -2- GENERAL AFFIDAVIT FORM # US-00407 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of: Jack O. Hakkila and Arctic Basin Industries Plaintiffs VS. General American Oil Company Of Texas et al Defendants RECEIVED DEC 1 2002 ~laska 0il & Gas Cons. C0mmissi0r~ .~nchorar..~e Case Number: 3 AN-99-9114CI GENERAL AFFIDAVIT Comes' now, Jack O. Hakkila, resident of Fairbanks, Alaska, United States of America who makes his statement and General Affidavit upon oath and affirmation of belief and personal knowledge that the following matters, facts and things set forth are true and correct to the best of his knowledge: 1. I represent the joint owners of 65 percent of the interest held by Clifford Burglin (Burglin) in Alaska Oil and Gas leases ADL 36422 and ADL 34623 and have commenced litigation respecting these said leases in: Jack O. Hakkila and Arctic Basin Industries v. General American Oil Company et al, Case Number 3 AN-99-9144CI (principal action) with the State of Alaska Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission inter alia being named as defendants in that action. , I file this affidavit in support of a motion for a temporary injunction to be ordered barring the State of Alaska, Division of Oil and Gas and or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or in the alternative, suspending the term of the lease until the hearing of the principal action on the grounds that permitting the lease to lapse will prejudice the proper determination of the interests of myself and Burglin in lease ADL 34623, will prevent any possibility of pursuing exploration and production activities with a view to extending the term of the lease, will unduly complicate matters by introducing additional third party interests in the event that the lease is sold to a third party, and is necessary to preserve the status quo of the parties pending the hearing of the principal action. , Burglin is a life long resident and land owner in Fairbanks, Alaska and I have resided and am a landowner in Alaska on a continual basis since 1969, during which time we have both shared an ongoing involvement in the development of oil and gas in Alaska as well as an interest in the. rights of individual Alaskans to participate and become directly involved in the' development of oil and gas in our State. , Lease ADL 34623 is a ten year oil and gas lease which term commenced after the lanes subject to the lease were patented in 1992 and which is scheduled to lapse by expiration of it's primary term on December 8, 2002. . Lease ADL 34623 was originally purchased in a lease sale held in Alaska on January 24, 1967, becoming effective April 1, 1967 and the original lessee was Thomas J. Miklautsch(hereinafter referred to as Miklautsch) who later transferred a 20% interest in ADL 34623 to Burglin on September 27, 1968. A copy of the assignment from Miklautsch to Burglin is attached and is marked as exhibit I-A to my affidavit. . On December 3, 1968, Miklautsch and Burglin entered into a Joint Venture Agreement with General American Oil Company of Texas (GAOC) whereby 50% of the interests of Miklautsch and Burglin in leases ADL 34622 and ADL 34623 were assigned to the joint venture in exchange for shares of stock in GAOC and a production payment with Miklautsch to retain a 40% interest and Burglin to retain a 10% interest. , Pursuant to the terms of the Joint Venture Agreement, the interests of Miklautsch and Burglin were to be held by GAOC which was permitted to register a 100% interest in lease ADL 34623 and hold the interests of Burglin and Miklautsch in trust with their interests to be re-assigned to Burglin and Miklautsch upon termination of the joint venture agreement. Attached and marked as exhibits 2-A and 2-B to my affidavit are copies of the joint venture agreement and subsequent transfers to GAOC. , On September 21, 1969 GAOC assigned its entire interest, including the portion held in trust for Burglin and Miklausch in ADL 34623 to Humble Oil and Refining Company (Humble) which subsequently assigned 50% of its interest equivalent to Arco Alaska Inc. (Arco). , The joint venture was eventually terminated on June 11, 1975 by letter from Burglin and Miklautsch to Exxon Company U.S.A. (Exxon), the successor company to Humble and which termination was made in accordance with the terms of the Joint Venture Agreement that permitted the termination of the Agreement by either party on thirty days notice. Attached and marked as exhibits 3-A to my affidavit is a copy of the termination letter sent to Exxon. 10. Subsequent to the termination of the Joint Venture Agreement, Exxon failed to re- transfer the interests of Miklautsch, which was a 40% working interest and Burglin, which was a 10% working interest, back to them. 11. After the termination of the Joint Venture Agreement, the State of Alaska Division of Oil and Gas refused to register or acknowledge the interests of Miklautsch and Burglin, the original lessees, despite their efforts to do so and despite having received documented proof of their interests and disregarding the fact that Arco previously recognised that Burglin and Miklautsch had an interest and filed an assignment on behalf of Burglin which was rejected by the State of Alaska Division of Oil and Gas. Attached and marked as exhibits 4-A to my affidavit is a copy of the assignment submitted by Arco. 12. Later in an attempt to break the impasse and to exercise their rights respecting lease ADL 34623, Miklautsch and Burglin attempted to sell their interests to Gulf Oil Company (Gulf) in 1975 with the result that litigation was commenced involving Miklautsch and Burglin and Exxon, Arco and Gulf. 13. The litigation involving Gulf, Exxon and Arco and Miklauts'ch and Burglin was eventually settled through the parties entering into two separate settlement agreements, the Gulf- MBH Settlement Agreement dated April 11, 1977 which explicitly recognised that the interests of Miklautsch and Burglin were held in trust by Gulf, and the Exxon Settlement Agreement dated April 29, 1977 the provisions of which were made subject to the Gulf-MBH Settlement Agreement. 14. Section 2(a) of the Gulf-MBH settlement agreement explicitly recognises the interests of Burglin which were held in trust by Gulf and which at the time were described after payout as; "The 40% working interest referred to ...in the Exxon Settlement Agreement is beneficially owned 80% by Gulf, 14.4% by Miklautsch, 3.6% by Burqlin and 2% by Hamel..." (emphasis added). Attached and marked as exhibit $-A is a copy of the Gulf MBH Settlement Agreement. 15. The PNG interests in lease ADL 34623 could be substantial as it has been estimated by Peter Huddleston, an independent consultant, that up to 28% of the Point Mclntyre oil field lies under leases ADL 34622 and ADL 34623 and it is projected that reserves held by the lease total a portion of 8,400,000 barrels of oil and natural gas with a potential' net profit value in the range of $84,000,000.00 and as of February, 202, the field had produced 337,000,000 million barrels of oil. 16. Meetings were commenced by the Alaska Oil and Gas Conservation Commission in October, 1993 in order to determine the leases and rights to be included in the Point Mclntyre Participating Area of the Prudhoe Bay Unit and I attended a scheduled meeting of the Commission on behalf of Burglin on October 13, 1993 17. The meeting of October 13, 1993 was to commence at 9:00 a.m. but was cancelled after various parties casually met and conferred with the Commission members around the water cooler in an interior hallway without an invitation for the interested parties to participate and which action prevented me from presenting evidence to the Commission respecting the ownership interests of Burglin et al in lease ADL 34623 and the Commission's consideration for the inclusion of lease ADL 34623 in the Point Mclntyre Participation Area of the Prudhoe Bay Unit. 18. After being treated so unfairly by the Alaska Oil and Gas Conservation Commission in being denied any right to be heard, it became my opinion, and it appeared to me, that the Commission had already decided to exclude lease 34623 from the Point Mclntyre Participation Area of the Prudhoe Bay Unit. 19. The Alaska Oil and Gas Conservation Commission decided to exclude lease ADL 34623 from the operation of the Point Mclntyre Participation Area of the Prudhoe Bay Unit without giving the interested parties the opportunity to make any reasonable representation to the Commission, presumably because of the dispute as to the title ir~terests in the lease with the result that no oil and gas exploration activities were carried out with respect to lease ADL 34623 and to the substantial detriment of Burglin and eventually myself. 20. Problems with the title to lease ADL 34623 and the failure of the State of Alaska to recognise the interests of Miklautsch and Burglin have frustrated attempts made by Burglin and myself to enter into agreements with parties so that exploration activities on the lease could commence and with the goal to produce oil on the lease with the result that the lease would not be terminated and would be held by production. 21. On November 1, 2002 I forwarded a letter addressed to William H. Colbert, Assistant General Counsel of BP Exploration (Alaska) Inc. in which I requested the voluntary unitization of lease ADL 34623 in an effort to pursue exploration and production potential on lease ADL 34623. Attached and marked as exhibit 6-A is a copy of the letter received from William Colbert dated November 1, 2002. 22. In his response, William Colbert stated 'BP Exploration (Alaska) Inc. would not support the efforts of myself or Burglin to unitize .lease 34623 based on his assertion that we did not have an ownership interest and therefore could not petition for unit expansion. 23. There were numerous instances of breaches of contract which operated to the detriment of the interests of Burglin which breaches will be outlined and proven at the trial of the principal action and which breaches involved a refusal to return legal and beneficial interests to Burglin and a failure to meet the obligations of a fiduciary by GAOC, Humble, Gulf and Exxon. 24. It.is my belief that the GAOC/Burglin/Miklautsch joint venture agreement entered into in 1968 created a trust in favor of Burglin and Miklautsch and their respective 10% and 40% interests which interests were eventually transferred to Gulf and which were explicitly recognised in the Gulf-MBH Settlement Agreement. 25. When the joint venture was terminated Humble, which had later acquired the interests of GAOC, failed to transfer their 50% interests back to Miklautsch and Burglin to their extreme prejudice as they were not thereafter recognized with the State of Alaska as holders of any interest in lease 34623 and which frustrated attempts by Burglin to commence exploration and production activities on the said lease. 26. It is my belief that if lease ADL 34623 is. terminated by the State of Alaska, or is permitted to lapse, any attempts to have the rights of Burglin or myself to be recognized would be frustrated and if new parties are eventually permitted to purchase the lease, that further attempts to recognise the interests of Burglin and myself could be frustrated. 27. That I make this affidavit in support of a motion for a temporary injunction to be ordered barring the State of Alaska, Division of Oil and Gas and or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or in the alternative, suspending the term of the lease until the hearing of the principal action. Sworn before me on thisbe, ) day of December, 2002. ) ~/~dK O. HAKILLA ,-E^.,, ,,o. A,,. _34-625 EI:FECTIV£ DAT~- F ~z,,,- A~z,'. i] :. 1967 J~ssignmonl A/feeling Hecord Title to Oil and {gas Lease The undersigaed assignors as o~ner of the record £1tle interest specified fn item 3 below in the oil and gas lease designated above, for a good ami valuable consideration, does .hereby assign to 0'o Bll. r{~liT1- ~,,ose ,,,~d~-c.. i-~o:: 131~ Pair'b'..m%ks~ Alaska 9970]- the right, title and interest specified in item & below in and to said ieaae insofar as it covers the lands described in item I or such portion thereof aa cite lessor my apl)tO'Se and describe tn item 2 belov, ·giving and. granting to assignee the rights and privileges of a lessee in said lands~ to the extent tndicated~ subject ,to the reservations of Ovezridlng royalties noted in items 5 and 6 below! 1. LANDS REqUESTZD .q. raa t; 01P,-2' Section 5: All 64.0 acres Sect:ton 6: A:kl 577 " " Section '7: A].I~ exclo PLO 1571 .,430 acres Section 8: All~ eXClo PLO 1571 580 " 2. LANDS AI['PROVgp .i. (.os to b. filled in)~~ toiJ~ the ~fidavit of .. . -Sworn beipre mg'this~ -:. - , Kerid~n, ~ 12 N'°, .. 1 4 .E,', II. mia~-~ .... ... c~.t.i.t,,s 2., 227? acre., .~re or les.. · · containing 3. Interest of aqslgnp[.,l~..{,fiid'l~aSe: 100¢ · . ·.·t~, ,'1_. ! &. £xtenC of .uch interest asa~gned'to assignee~ ~0¢ "' · 5. Overriding [o~alty reserved herein to assignor:, none - acr~s.l~more, o~ ~ . .. .( ·- 6. Overriding roya. ity *'previously reaerved:IlOIlO % 3'~ '- -. 5 :si} :'' September ~'"" 1968 ,,, ,, ?oRign.d this aat~"16th-, ~..;tt ' ' t,.~ ,.~:,.-,, ...../.~'..'.--~' ............ ' ' ' ~ . :.}" . .: . . " - . ,,"" ~,'~-"% l,-,-.,(~,nr~4 r~ ~ , - · . ~.. '....'"~ .... '...- ',,i)~,,; - rt ED -" :~ .. ..... ....,.:...:.. ~',,.~u,,,,._u- --.-.~. .. ,~.. _ · .:. ;.'/v,O~p. ~ ,-' '~-; '~, ~ ............ .o ~ L.'" . (A,~,,o,', st~..,.,.) . ' - ~; .' _%. ' .,/ c'~' .-z ~ 'fI,N'5 ...... :¢.-..~ ~ ..... ~ ..... _ ; .... ~ .. ----%U_. · ,* a __ f ~) '.' t ~i-qu~lt,'~ ~¥ .~ ' · ~ · ~' · '..,,;.,,.~ ',: ..:,..--." ) .,,.,. ...... ./¢,% z %., ¢~ I ,,.,,,,,0,,,.~ ~,...~, .... ~ .......... ) ;,..' ....... 7.2Zd./. ....... ~' .,ss .... ~~ .... ~_~ .,,,...,,.,o.,,. /r ..... .... peruse descrlb.e}[~tn and who executed tho foregoing assigneeS, who t~en executed said aas/g~enC tn my presence and, " after~n.g~¢91~; ~o~n'~c~ording to ln~, acknowledged ~o mo onder oath Chat lm executed sams freely ~nd vol~tl[ily tho u$o8 and purposes therein mentioned, r, 0 ,,~',: :,,,', ,, ,~ ,,~ Ny Collnission exp/resl /-~ 9/- ¢~ ,' f · Application for Apl)royal of Alzsignment- Tile utidersiGqed assignee hereby request;, ni,provnl of tile above assignment as to al{ of the lentil described . tn item ~ of the above assignment or such portion thereof as my be appgoved under applicab~ law' and regulations, . Euclosed with this application are{ . (a) Check or money order payable to the Department of Revenue of the State of Alaska covering fee of $20.00; '"' ~, "t (b) Information and doc~nen~s, or references ~bere~o, evidencing ~he qualifications of the undersigned to hold a lease, in compliance with Section ~10.31(c) of the Oil and Gas Leasin~ Regulations[ and . ~ f · (c) Any bond or reference ~het'eto required by said Regulations. '-... ~- .-. Any no,ice irs connection with th~s application or the undersi$ned~s tn~eres~ in.~he lease' deslgn~ed'in the foregoing assignmen~ may be sen~ ~o ~he undersfgnedSs address set forth, in satd'nsslg~e~. '.' .~. The undersigned agrees ~o be bound by ~he prov~onn of said leases .~ ~he above ~s~tg~en~ Is approved , i, ~ . ~.. ' tn whole or In part. : '. , , ~ ~ · . This application discloses and Is signed by or on behalf of all .pargies who will or ~y, if the ~bove . _ ~ - i ' ~ ' .assls~ent Is approved in whole or in par% receive any tn~e~es~ ~n the lease designated above by v~ue o~ a~y agr~emen~ or und~rstand~nB, oral or w~t~en and constitutes certification that each such par~y ts qunll~ to ~old ~lan~ State Oil ~nd Gas Leases pursuant to Section ~03.1 of ~lte O~ and ~s L~asin$ . . . . - . .. , ~~... - ~ .... -.. ' "" .-. -, . · . (Asslsnee'8 Signature) ~ . Approval The above assignment is approved as to the lands described in item 2 thereofe effective as of the date . . . set forth below, ' - · · · STATE OF ALASKA Effective date of assignment By. (;{t,t,,,~tt In triplicate, Must ha filed witless 90 days &fist final execution by tbs assignee. All copies must be signed in ink,)' ' .o . , -- -, ,, · ;. f .' i. i 681203-A. 13 "'..~'~".. ~<.'~.~"-"":'.O~'tAL~ THIS IS EXHIBIT'S,' ( ~,.~!~:.~( ~ refitted to in the Affidavit of -- Sworn bepre rne trois '~.~:) J 0 I N T V E N T U R E A G R E E U E N THIS AGREEMENT made and entered into by G~I:~T., A~TCA_~ OT~ COlV~N¥ OF ~;..X~$, a. Dela~a. re corpo~*-a.t£o~ (hereinafter called "General ~merican"),, T. ~. M*r~%U~SCH of Fairbanks, Alaska (hereinafter called "Miklautsch" ) and C. BURGLIN of Fairbanks, Alaska (hereinafter called "Burglin) ); WITNESSETH: WHEREAS, the parties hereto are the owners (in the proportions of 50% by General American, 40% by Miklautsch and 10% by Burglin) of the oil and gas leases covering lands situated in the state of Alaska that are described in Exhibit A attached hereto and made a part hereof (hereinafter called the "leases"), and such parties desire to create this joint venture (hereinafter called the "Venture") for the ownership, development and operation of the leases; NOW THEREFORE, in consideration of the mutual covenants and agreements herein contained, the parties hereto agree as follows: 1. The members of the Venture shall be general American, Miklautsch and Burglin and their interests therein shall be as hereinafter set forth. Each of such members hereby assigns to the parties hereto as members of the Venture its or his respective interest in the leases as above set forth; provided, however, there is excepted from the assignments hereby made by' Miklautsch and Burglin and reserved unto each of them, as separate production payments (hereinafter called the "Production Payments"), an undivided 50% of all oil, gas and other hydrocarbons in'and that may be produced, saved and sold from the lands covered by the leases that accrue to the respective undivided interests in the leases hereby assigned to the Venture by Miklautsch and Burglin, until, from the proceeds of the sale of the °il, gas and other hydrocarbons accruing to such unreserved interests, Miklautsch shall have received the sum of $3,200,000.00 and Burglin shall have received the sum of $800,000.00, each free and clear of all cost and expense of whatsoever nature '(except costs of transporting the oil, gas and other hydrocarbons accruing to the Production Payments from the wells to such sale delivery point as is reasonably required in the marketing thereof, and except production, severance, occupation and other similar taxes charged against or measured by the production .accruing to the Production Payments). Miklautsch and Burglin shall look solely to the oil, gas and other hydrocarbons accruing to the interests herein respectively reserved by them for the ('_atisfaction and dischargt of the Production Payments. For convenience, record title to the entire working interest in the leases, subject to the Production Payments, shall be transferred to and held in the name of General American without disclosure of the existence of the Venture. Subject to the further provisions of this agreement, the parties hereto shall own and hold the following interests in the Venture: General American 75% Miklautsch 20 % Burglin 5% 2. For purposes of this agreement, "net venture income" shall be all income received by the Venture from any source whatsoever, less any portion thereof attributable to royalties reserved in the leases and to the Production Payments, and the "payout" shall be the point in time at which net venture income equals the aggregate of (a) the sum of Two Million Dollars, (b) all sums accruing to the Production Payments, (c) all costs, charges and expenses of whatsoever nature incurred by the Venture prior to the payout in connection with the ownership, development, operation and maintenance of the leases, determined in accordance with the Accounting Procedure attached hereto as Exhibit B and (d) interest at the rate of 6% per annum on the unliquidated balances of items (a) through (c) above, computed monthly and compounded annually. In determining the payout, net venture income shall first be applied to interest as above provided'and then to the unliquidated balances of items (a) through (c) above. 3. Until payout, all costs, charges and expenses incurred by' the Venture in connection with the ownership, development, operation and maintenance of the leases shall be borne and contributed to the Venture by General'American. After payout, all such costs, charges and expenses shall be borne and contributed by the parties hereto in the proportions of 75% by General American, 20% by Miklautsch and 5% by Burglin. 4. Until payout General American shall be credited with and be entitled to receive all net venture income and after payout, the parties hereto shall be credited with and entitled to receive net venture income in the proportions of 75% by General American, 20% by Miklautsch and '5% by Burglin. 5. For( -~11 income tax purposes, iI~luding the federal income tax, all income and all income tax deductions and credits are allocated to General American until payout and after payout all income and all income tax deductions and credits are allocated 75% to General American, 20% to Miklautsch and 5% to Burglin. 6. General American shall be operator of the Venture and shall have full power and authority to direct, supervise, manage, control and operate the business of the Venture, and the scope of such power and authority shall extend to all things which would be done by a reasonably prudent operator in respect to the exploration, development, operation, maintenance and management of its own properties. The judgment of General American exercised in good faith shall be the limit of its liability to the other parties hereto and General American shall never be liable for any act done or omitted to be done in good faith in the performance of any of the provisions of this agreement. 7. General American shall maintain accurate books and records relating to the Venture which shall at all times reflect the ownership and affairs in connection therewith pursuant to the terms of this agreement. Such books and records shall be maintained upon the accrual basis of accounting and shall be kept at the principal office'of General American in Dallas, Texas. The financial and taxable year of the Venture shall be based upon an accounting year ending on December 31 of each year. The accredited representatives of Miklautsch and Burglin may at all reasonable times inspect, audit and make coPies of the books and records in connection with the Venture, and prior to the payout, General~ American shall furnish to both Miklautsch and Burglin not less often than semi-annually, a detailed statement reflecting the costs incurred by the Venture and the net venture income received during the preceding 6-month period and also reflecting the remaining amount to be 'recovered prior to the payout. 8. The rights and. obligations of the parties hereto shall be several and not joint. No party shall ever be liable for any obligation, or liability arising hereunder which then exceeds its proportionate share as set forth herein, and each party indemnifies the others against all liabilities hereunder which are properly for the' account of the former. For federal income tax purposes, the Venture shall be subject to the .provisions of Subchapter K of Chapter 1 of the Internal Revenue Code of 1954, and General American is hereby instructed for federal income tax purposes only. and for no other purpose to file a proper partnership return, each year under said Subchapter K with the appropriate District Director of Internal Revenue. 9. Gen "~1 American shall initiall pay on behalf of the Venture all costs, expenses and charges incurred by the Venture and, after payout, shall charge Miklautsch and Burglin with their proportionate shares thereof as herein provided. General American shall collect and receive the proceeds of the sale of all oil, gas and other hydrocarbons and other proceeds to which the Venture may be entitled and shall distribute the net venture income monthly in the manner set forth in paragraph 4 hereof. 10. The death of either Miklautsch or Burglin shall not terminate the existence of the Venture. If either Miklautsch or Burglin should die, the legal representative or representatives, heirs or legatees or devisees of such party, whichever is the appropriate one or ones~ shall be substituted as a party to this Venture. 11. Except as herein otherwise provided, no assignment or other transfer by any of the parties hereto of his or its interest in the Venture shall be made without the written consent of all other parties hereto. 12. Any party hereto may at any time terminate the Venture upon thirty (30) days prior written notice to the other parties. Unless so terminated, the Venture shall continue for a period of one year from the date hereof and so long thereafter as either of the leases remains in force and effect. Upon the termination of the Venture, General American shall assign to Miklautsch and Burglin their respective interests in the Venture as set forth in paragraph 1 hereof; provided, however, if the payout has not occurred at the time of such termination, such assignment shall be made subject to the provisions of paragraphs 3 and 4 .hereof which shall continue to be applicable to the interests of the parties in the leases regardless of such termination. Upon the termination of the Venture, the parties hereto shall enter into a mutually agreeable operating agreement with respect to the leases which shall (a) designate General American as operator, (b) employ the Accounting Procedure attached hereto as Exhibit B, and (c) be effective as of the payout. In the event of a dispute between the parties in regard to the terms of such operating agreement, the disputed'matter shall be determined by arbitration in the City of Dallas, Texas in. accordance with the rules of the American Arbitration Association. 13. The provisions hereof shall be binding upon and shall inure to the benefit of the parties hereto and to their respective heirs, successors and legal representatives, and, to the extent that any assignment is permitted under the provisions of this agreement, to their respective assigns. ATTEST: E X E C U T E D this 3rd day of December, 1968: GENERAL AMERICAN OIL COMPANY OF TEXAS Donald C. Apeland Assistant Secretary By R.M. Swesnik R. M. Swesnik, Vice-President T. J. Miklautsch T. J. MIKLAUTSCH C. Burqlin C. BURGLIN EXHIBIT Ai' Attached to and made a part of Joint Venture Agreement dated as of January 2, 1969 by and between GENERAL AMERICAN OIL COMPANY OF TEXAS, T. J. MIKLAUTSCH AND C. BURGLIN Oil and gas lease bearing Serial No. ADL 34622 made by the State of Alaska to T. Miklautsch, dated April 1, 1967, covering Tract C18-1, being the following described lands situated in Alaska: Township 12 North, Ranqe 14 East, U. M. Section 3: Ail Section 4: All Section 9: All Section 10: All Oil and gas lease bearing Serial No. ADL 34623 made by the State of Alaska to T. Miklautsch, dated April 1, 1967, covering Tract C18-2, being the following described lands situated in Alaska: Township 12 North, Range 14 East, U. M. Section 5: Ail Section 6: All Section 7: All, except PLO 1571 Section 8: All, except PLO 1571 EXHIBIT B(' Accounting Procedure attached to and made a part of Joint Venture Agreement dated as of January 2, 1969 by and between GENERAL AMERICAN OIL COMPANY OF TEXAS ("GENERAL AMERICAN"), T. J. MIKLAUTSCH and C. BURGLIN. The costs, charges and expenses to be taken into consideration in connection with the ownership, development, operation and maintenance of the leases referred to in the agreement to which this exhibit is attached are as follows: (a) The costs of all direct labor (including fringe benefits), transportation and other services incurred in developing, operating and maintaining the leases, and of all material, equipment and supplies purchased for use on such leases; (b) Damages or losses suffered with respect to any of the leases which are incurred by any cause not controllable by General American through the exercise of reasonable diligence; (c) Expenses of litigation, liens, judgments and liquidated liabilities and claims incurred and paid by General american involving any of the leases or incident to the development, exploration, operation or maintenance thereof; (d) Ail expenses incurred and paid by General American in appearing before administrative agencies in connection with the leases and the production therefrom, including all amounts paid to outside attorneys and third parties and compensation or salaries paid to officers and employees of General American whose time is not directly allocable to such administrative proceedings, provided, however, that these charges shall not duplicate the 'charges made under subparagraph (g) below; (e) All taxes (except income taxes) paid by General American for the benefit of the parties hereto, including, but not by way of limitation, ad valorem, property, production, occupation and any other taxes assessed against the leases, the production therefrom or allocable thereto, the personal property located thereon or the operations conducted thereon, to the extent not included in subparagraph (a) above; (f) Insurance premiums paid by General American for insurance carried with respect to the leases or with respect to any personal property or equipment situated thereon or used in 'connection therewith, together with all expenditures incurred and paid in settlement of any and all losses, claims, damages, judgments and other expenses, including legal services, relating to such properties; (g)~' A reasonable charge for o( £head to cover the proportion properly allocable to the leases of compensation or salaries paid to managing officers and employees of General American whose time is not directly allocated to the leases, the office expense of General American, and of any district and camp expenses not allocated directly to the leases, such overhead charge to be in addition to any amounts chargeable under subparagraph (a) above; and (h) Ail other expenditures reasonably incurred by General American for the necessary or proper development, operation, maintenance and utilization of the leases, including all legal fees and expenses and engineering fees and expenses not included in any other item above, but excluding any interest paid by General American on any funds borrowed in connection with the development, operation, maintenance and utilization of the leases. '..'ii.,,' Form D~-8 (0~) ' '-' 'i .:i "'. APrtl,J1967 . · ' -*' ' ?' ':" i' . ~.. · i: ;,.)' ... · ',..', ... ,j t'-, ~ '. ,' ~ ' , ..... :~.. -.. · · -. . . .'~, o.' . . ,. . ,.*! ,. -- ! ·., ) . :., . ].1. t . .. · .'. . .. . · . . ; ,o '.~ ....... P. mi.., .:-,. LntsE ,o. ,~,L 34623 "'""""'"";--:. ; ~"'' ~" f*w¢..bdr,~l ~t.:¢,':'.;'diw_~ '.'-'~:/",f:t '- ' EFFECTIVE DATE'OF -"---.'"'- .', "' ' t"as'-a- ."T., , ap,-a , '. ,,.. : . , -. .- . '.- ': Departinent of Natural Resources ' . .. . ! I · '?' " '° '"" ' :..' '-''' - · "Division of Lands , .. .. , : ...:. . '-.- ii.-. , ..- ' -' ;, · ~ .. - .'- ,. -,-- .,.i~ ' .; · : AsstsnmenC A~fectins Record Title to Oil and Gas L~.aso , -. ; ..,.: .'r ,.'- · . · . The undersisned asstsnor, as ovner of the record title interest specified tn item 3 betsy .-" in the oil and sas lease destSnaced above, for a seed and valuable consideration, does hereby assisn , 'i:; to General h__m._ertcan_.OILl Company_of Te..:,;a~; a Delaware corporai;10n ~_ .. '-: · . i,.'.= ,,~,oos addre.s ~s _ Meadows Bulldlmz.. Dallas.-Texas 75206 .... : the rtsht, title a~d interest Spectfied"{n item ~ belo~ in and t° Said lease insofar aa it:covers- -', ."~ ~. the lands described in ices I or much portion thereof as the lessor may approve and 'descEibe in ! : - .. · ,: . item 2 below, sirens and stearinS to easlsnee the rishts and privtleses of a lessee in said 1andes ~. . · ' .,' ' Co the extent indicated, subJec.l:' to the reservations of overridins royalties noted tn item t end ~,.'- · .. · · . betov~ . : .'- - .... · '"' ' ': L' - .j::..., . ..... ' .... '... :. -.. t,'k: .-." ' :~ '..' i.:i' i:./ .... -:., ,. · ' .... --...'-.:,:.':.?. '.~ , l. LAHI~ REQUESTED " ' -' .. ' ' 2. ' ~AHDS AFPROVED .,t-..i.. ,"' " · TRACT C18'2 . .' (Hot to be'fitted in)'*, ," ~ ""'"1";' :' :. · ' _ ~- _- ..... * . , , · , · ~ . ,. .. Section 5:. .. AIl {40 .¢rei ;~ ''~'" ' ~'' :'~:'" """ ' "':'"" ., ...-- ..'..."S;: ..... ,.-. ...-.(:.~..., ,..- . _'... , ! · · : : . ";' all 577.tree ..--...,. · -'- '. . ~¢¢tton 6: .. .... .., .- ' .;'~ ,..·. · ... ! . , . Section 7:' AIl, e.¢l. PLO 1571 430 acres' .,..~:SA}{~./ts'irl~lu.~z .-,..;-.' '"' $¢c~ton 8:'"'/i" '~11, excl..PLD 1571..580 errs." .:.....,, ; ... v' - . . ,. ": ... ". .. ~J,,.: '. -.,;,'",' '' ' . }'i-' ' .':r', · . -' .. ,. .. :' ' i' ' · .- .. . . ;.'.. '.......' - ... . · ~ ... T _. _., it . _, , _ _ -. I~ctdt. tin,'";'"' r~'''. - . concetnin$ _ _ access, more or lass:. .. . _ . ,. - 3, Inter'sc of essiSnor in said lease.* 9-0~ percent ' ' ' ' '""' ' ' (State tn percent of total tease interea, C,) ' : . TP*~;;,/,.-, IS EXHI~IY" '.~."" ' ..::. &. Interest' asstsned"to esstsnee~ . lO~)~ ' percent -, -,~, , ed to in i~e Affid,it~t ',/ / L~-. ., ,. (Scats tn percent of total tease tnterest:; th~s ti assignor - r~'~'~-2. ~)-' · , o~ned 50 percent interest in the tease end ~ished Co trane- Sworn b~i~',e='" ~e thi~'~.~. ~-. fe~ one-half of his Interest, th-is lies would be 25 percent.) . da~' ~fA/~ :A.D.. ~_~f~" &. OverridtnS royalty prevtouI!y reserved; NOlle .... ./.~o~,~ · 7. 8tsnad thC, dat.[ Dt~com~er 3, .19~8 '~.~ ~---:.. ' ' , ..: · - · .......... ' _~"~'-~":~X%~,L~" -'. i " · -. ., . :- · . -'~xm~.-.~.~.~.~.~,,~,T. ' ' -' · ~.;- ., ,.' .i:, ...."'~ ' · i 6: ' .... .,! · ' '. ,:.'~, ":" "' ?'T" Umlat ~eridiau, -,.":...12-N, .-14-E, : I f ,';: · .. ti....1" -. conCatntns -2. 227 ,~r,., more or tess. _ THE t~lTgD STATE OF '."' · · - ' · ;" -- '- i'. ~ . .,..:'.':'.,"~'/~.,.p?~t~ i. ,nd for th. State of _ Texas . d,~y .o.,l..to.e~ ,,d .,0,,. p--.oo.n~ ~' :: .'~' >': :~ ~:: ~ ¢"-"~ 5":'z:~/· % .... "' ' :. '{ '.:'. · , . ~: j .' ,~/'k;g"'e ~ .. mppei~.. . .~~~; .~. D~r~l~ ~' ~.' _ ~o ~ kn~n nnd. kn~. ~o ~ to ba the parson deecribed, ts, 'i.' ~ ~, ';"'.. .'"" :,':..7 ,'.. [~Ad~ho".exe~uCed the for, goln~ assi~nt~ vho then aff~nr belnB duly s,orn accordln~ to la,,' i' ',-' .. ~'." ~ :~;".L~' :"'- ' '; · ' "" ~ ~ ~.. 'ackn~la4Se8 ~o ~ und, r oath thn~ h~ ex~cut,d ~ freely nnd voluntarily got fha uses nnd .: ;".l ':,.. ~ I ~ ~ , - . ,, .i · k. ' i 1' =~: ~,. uurpoaeo:.therein mn!toned. · · ' ' , ' :, _ ~ -- '- '-r- '- ~q~ ", [ ~.--, ;.,,~:. : - . ., . ,'. , ~ / .: · : · ~9~ ", ." ~ .:/".: .... "";."... ,": , j. ' ,. · -~ ;-'&. ~ ..'r..~l~gSS ~ hand and official seat the day and year in this cerC/ftcate ~irlC abwl .... ', .''. '. - , /% I .' ~ ~ - ' ~ · · ' : %~/'~;-~O~enO~ ' .. 'i ' ". ' .- / -_ · ..; .. ~:"./'.':',-.-:-,'.:. : ' "~',,,,,.:/,,,'"", '. i "'": '," : .' // -~ ~.~//.._ :- ....', .... 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',. 5',,:,- ',-.,'F.:, ;:,: .... ' .. . :.,, ... .: ,% .! . ,.~l · '(' ' ~'"- ',%. -~'--- ' :::-',/t-il '~, · ,, ~.,. ,'%. ..}.-',.;x.'.*-... ~i':;- · ~* '(# I ,, · ' · .. · ',I(-~','* '~' ..'~'~' "-:" ': '' :', ' ' ....." ' '' -', I{''-.;" ' ' *'"-" "-'-:'1 .- ' ~' '-' ' : · '']- .'-", ~ '/ , ,: : ,''t - .,~ . -~ . [ '.. t %' - ,; :. ,. '1 ' ~ ;- I ',~' '' '"' ~,-' -' ~" · · :' ." ,'.-/.. ' ' ,,' i -, ' ' · - :~-".' ' ,. · ~ :'~J ' ' ;'. - · :. . · .'., '. '. ' - · ',' - · s · .-r ~ ' -('"' ' $'*'~'," ~: ' . ' ; i · .¢o. ,-, ', . ~' '. ,'' '. '" ·:: . ! " -, . - '' . ' . 7'-, J , '- " -. . · . '' .'; :r,i' ', ,' · . '1 '-' ,~ I'~ ", -, ','. '' · ~/a; ~'..' ''~'{' ' · :. I . ;.:°.' . · '%' . . ~d '; r il ' .', - . : , ' t'..':' .~'~,'[ "-'~" · -' ' m all,' %; -.' I~. · ,-t~,, :,, .., ' 'f,..', '' ' . ,' : · . - ' - ','' ' ~"' "',~ ,~:· · '- ', ' .' ~: ·f~ I."z ~Pq¢-"d" .... ( ' ~/::~f. ' ' --:' .I ~ : :' · · ...... - - -;.'~:([ ..... .. ' i: ,i. , .... ; ?'' I!-' "-'' "' '=-'%: : · .; ' :, : · -"4 .; .,.. :.,t' ' ,{' ,.-' *' ' . ' "..-,' : ' : .. -q' ,q' ' ' , '';-v' · I '" '6-,:~,:',~-,~'} ~" ';",'..~{ '' "'¢:-.". ."' '" '" .''t ' -. ~ "~,".- '-'- .' ''-'. "":' '"~; .;-:' '-:- '". -:' - ;" '' ':'" '~/,; '.':-"~'% ;., - ,. . - ·· · ,*~ ~ .... : ',:~- - '., - : .'1-'. .~, · . .' ¢ ,-- , I : · t' '. q~ ~. - - ~' · - ~..-' t , - ,,, . ., .- ·. , · . , · : . · · ,· , r .... td ;:t~' '' '; ' ' ' "~ .... ' ' ' ' ' ' ' ': " '"' ' ' ':" 'I , ':; "!;' .... ', :-I . .' ' ' : .... ' .... :~ ,. : '_ , x~ - -'-,-;,, j : ,,.-;'._...:t':.'-'.''¢...'¢ ." , . '' ' (' ;' ' ' ' I . ,. ; .... t .. · , . . . . · . , , fq -,- . -. . . · ~, f.. ' ' , .... i , . , . , -., ~ ~ . .. : s! · · . "-.-, -~.. · · ~, ~ . · .' .~c. . ~ · ~. · : . ' ' , ,'. · · ' .- · ? .... '., · ., · '. - ' .~-,:-:" · · , .. ': .'. t ' .': : · ;} r.~.' ~ :. .. · ~,, '- ... 4 .. . ' ' . ..... .'.': ' :.' :, , ' 't,;' -'-; · "-'";'?:';i': ..:,- .:,, ;':.:4, 't..'~S:'~: · -' ". : -' ~'¢'... ' . ' , L : ' ' "'' ' ' :- ' ' ' " '%' '~""q:' 'i''' ~' "' .,:r.~.... ... · ., , ! .'. -. . ,. ,.. . .- ,.-,.. , . , . :'"' :'' ' } ' ' 'i ' ' · - ' ' ' ''~ ' ' ' ... % :. ~":~-' ~ i , '' · · 4 - . .... .% ' ' ' - - tt'~'..: ~-;. , i-, - i .· ..... · . :~ .. -,~.' The understSned aaiLsnee hereby requests approval of the above a0stsnmenc as to all or. " ': ~ : "'the Lands doscrtbed in item I of the above asstsnmenc oF such p.orcl:on thereof as may be approved., ' / . . · ' under appltcab~e'hv and resutaCtona, .':'~" " '" ": : "' · ':': ~ " · , , ', . .. -, 0...~ . .. 'wLth ' "" ' ' · · ' i~ncloeed ch~a app~'~cac$on a~e; ....... "- ~. ;. . " · .4'~ (- ~ ( · . -, ,. · (a) Gaeh~ check or none~ order pa2able Co the ~FiF~MnC o~ Revenue o~ 'the Scats of . ' · ' ', : o :; '~ ' ~ ' ' .J'"~ ~ ' -. 'Alaska cover~nS fL~tnS fee of ~20,001 ,, .,..- '-', .-, i (b)' ~y bond oF re~erence there~o tequtFed by nard resutactons, ' '"~' .' -'"'.' . '.-' . ~ " ~ ~* ..~-. r. ,. : ' ""'.. "::", ~y not,ce Ln connection w~ch this appItcaC~on or the undere~gned~s ~Cere.et Ln the leaae : '' ~ -' -f . . . ~ .'"i .: .... daotdnm~ed tn the foFesoLns eoa~ent ma~ be sent to ~he underatsnedfl addFeoo sM~ forth t~ i~d..' ' - .' . . ' ' ' ~ .i '. . .. · . - ~" i~ ~'~ ~' '" ' ' ";" ' " " '~'~ 't " '' ,l"q~ '' "'.- - :' ~.s ~ '- · . ~ : ~ ~ · - .... . · ,.~ '.. ~ · . . f . ; , : : ,: ..'' ~e undersigned isrees Co be bound by' ~he prov~stons of ontd [ease,.L~ ~he above iosLS~-' .... · ., . :... . . . .. , :~4J:. ... ~ ' : .... '.' ,. . . ,%. v' : men~ Lo approved L. ~o~e o~ Ln p8r~ .., ~ .:.:. : . . ....,: ~.:: ~ ' - . .. - . . . , · ' s · . ~ . · . -...] ::"' ' ":" "' " · · :epplLca~ion' alL'closes ~d ts stgned by or on behal~ o~ 41~, par~ies ~o v~11 or mayo ::: ,t i~" ; :'.X ~.; ', ' - :-., ' -- . J ,' . . ::.. .... · . ~...,::"'.': Lf the above al~t~enC ts approved. . tn ~ole or In part, receive any lnCezeeC Ln the lease deals-. "".: ' . .'-, , f. ': . . -, . · :'....~:':: '"' maced ~bove by v~rCue of any asreemenC or underscmdLns0 oral or ~iccen and cono~i~u~ cercL~i- ~':"..~... /';"'. ' .. ] ~:....:, - ~..~- .,. ' s '' ~ "' ~ ' - ~- i · ;..'' cation chac each· such party is qual~fLed cO hold Alaska Scats '0~1 a~d Gas Le~s~a pursuant Co-- ~j': ~ ..... · I' ' ":~': i ' ' - , .,. ). , : , _ , .'~',."t. ~ ;' .'.~ ' :"" '::~' SettLes ~03,1 of the OLI ~d Oas LeasLnS ResulaCions, " -'-:"· ' ..,~:.'-~,h; . . : , .. . ' ,:.,- · .~- : 'i 'l.· '' : ~ ' ~.,. ~ .~ ,~ .. ' '., · ' t ,~ , '' - : :- ,, . .. ~...,- -~ ' , ,-. ;;: .... .. - .,- · , ... -, .-.-.-... ',~. ~..:]..: ~ .' i. ..r. ~ ~ ~. ,~,~.. ......... . . ... ', ex 8 , -: ~' : ... : ,-Gene~n~ ~e ~ O~ o~2~ .. · ": ':" "' -. ,.¢ ., 2 ;..(. '~'~ r.m,.J:,. '..~'-.'~ ~/ . ~ ' -' .... -.. . , i ',' ~ '~, - -, ~,', ",.t · ~,' ""~ .~' . . ~ i"', · "- , · · , ., I . ,.' ,, ~.~ . ",.' ~ ., "~1 ~ ., :~. · , : . -.~"; · ' - "' 't , . . ~1 * ' ~ ' ~ :" i I .. '. I , i · ...-~ , ~..' ,. - , ... '( tj..l ' . . I i.~'.. ' ~ I '.'~ ..,... ?., ~)I ~.'.~'~,~ - ~:l., ~ui~U~) .... · ::.t'l ::" , ' · ;~ ...... " ',~ · .;. ,~ ', ~ ,f , ~.( :.-.:: ;'.',:.. ~.~,..... -_ ,.-t.~, ,.. . - . . ,: ".. ,'-'. H. ~. '.~E~NIK -~lc~-,.~sl.~.r . -.::;.- .,.... :.~ :':. ., ...... _ ,j-' -. . . - : ~'" ~' "' '~ ~ ' ' ~oVn~ :": ....... ~ ..... i' ' : " '...~ ' "$~'."(,- ~ ': ~"'- '-i. AD ' ' '.: - , -'. .~:~., - ,.. . . . . I,, ~ ' I' .,f~I * '1 " i ' '' :' t' ' .,:-: .,. }. ".' .- - ~e foreseen8 isstd~enC 'Lo npproved aa Co the lends described tn t~ 2 thereof,- .'. '. " : . i e · . ~ '- . , - -. , ~ . : . .". ,'~' -" ., .( .'effective as o~ the date eec fo~ch below, . :" -: F,-:' : - ' ''' ' '"~ ' ' .... ~ I- ,j~;:.~. - .' _ .- , -. ~ :.: ~.~t · :'l. ~' ' '?:' , " :" "' ::'. .: . .. . · - .... ~ ' j"" ~ ' ~'-' ' '' '' ' '" ' . ~ i - , :; ~. ,.- '.' :. ~ .. :~.' "'..'... :. ' .'".~,.'STATK OF ~AS~ , ' "' -"-~..L" ~ -,:' ,.~ ~ .-~ : .' , - "... · . .. ~. . .' . : .. . · ... -'; : .' -. . :": · · ,tAN'_ 1 .:. .-.: . : . . _ ....... ' ~, -.. , ,. ' ' ' ~cf, M~cr~ Sec~. ,-'.':'; .... : : ,~,t.. ' .:.; ' ~' ' ' .,: · · , "-... - . ~ . , .~ · ~' . ., , . . _ ,"~'~~(Su~$C Ln Cz~pILcaCe~ HuaC be l[~ed v[~h[n ~0 daye afl,er fi[nmi -'. ''' ".'- .'"/"..~"'"':":- ' ~' ~'' . ,x '-.,- ' .,,,.." -.'". - -' -:' ~ ~.~' ,':,%~-"'~ ' ,- . ' · ., : -,'.'.~ .... ': ' :~'", ' -"-' , i", ~%," ~-.-'.,,[ll ~'~. ' .- - ' .... ' ' : '""' ' '' ' ' '~ I" , ""' . _ ........ · .~, ~-~'~".~", -. . .... -' '. 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'r. : '~.i:' i~.. :, '~.,'.? :~ ' · : v:"~.'~" ~: '~.' ' '..:.. ~.ii~.'. ~! . · '"' ..:' :'t~. "~..- .... ": 'i .. -;. :,~:: ~.~ .... · ;~..?~ i'!~i.~ ...... :.,:~ .:;~,..:,. . ; .,~ · ..~.~.~. .. .':::';i .:.'.?',~ '. ' ';'!i' . -4)~ '..~..'-. . ' ~,.'~ .' ;.:: . · :;,' .. :.,'-. :i ,~ .'- .,. · · . '... · . .... ..!. . ~..-,:. · - "-'~i.' : · . .....~ ..~: ';; ...-..-} . ~.~i~ · ~. '.':,"i~:;:.' g · t- · '/% .,;: .... Unitod States of Amoric, a ) St~e of A;aska ) ~ '[HIS IS TO CERTIFY that the foregoing ia a full. Irue and oorreol copy of the original as the same appeam in the reco~ ~KI filee of I,,..-~. WITNESS WHEREOE. i ha~/e ~ = ray INand_~d have eo~,xeo mvry o:~ial s~i~lo~ficial s at Faifbankl~ ~ mi~ .l ~L. o~. o-~ _~ . -, ~g.~f ! . ! referred to in the Aff~lavit of -, . -~.~..~... :?'~.:~..'.- ~"; , - ..... 2:,:.*7 .... ... o~. ... , .'*,;,:..o g;....: ........*.....%..~ · .;__.... -... . ...., .:;~.~:.:~:...- :' ' .-.' '"-"?-!~m-': ..'/' ~"~' :-'~"~ ~ . ':-..~.~..,<~,:..~:.;.. .- .-: ................................. · . .. ... ~ ..... C--".~ '. "' ,,~ .. .... . .~. · ·., ..,,, :: ........... · .~. .... "' "-' ..... '~!' · ·2.' .' · .. .... ?: .... . -...'.~.,~::.., ,. ...~-'. :;,i.... 'or..,...2....~, ................ "mi June 11, 1975 Exxon Company U,S.A; Box 2180 Houston, Texas 7~001 t~ns! OIIIce Bo]( ! 4S~-5503 · 45~-5571 - 45,~-5.q74 Re: State of Alaska Oil and Gas Leases AgL 34522, 34623 Dear Sirs: ~e'have recently concluded a trade ~ith'Gulf Oi~ Corporation to sell to Gulf our undivided one-half interest in Sta~e of Alaska Oi! and Gas Leases, Numbers ADL 3~22 and ADL 34623. As you ~o~, these interests are presently sub, ccc to the · Join~ venture a2ree~ent of December ~, 1968. between us and '.General American 0i~ Company of Texas, whose interest was .. subsequently assigned to you through your predecessor in title, Ilumble Oil and Refining Company, by instrument dated as of September 21, 1969. In accordance with paragraph 12 of the Joint Venture Agreement, you are notified that such agreement is cancelled on the 30th day following your receipt of this writ:eh no:ice; and request is made, Under. such paragraph, that you,.as successor in interest to General AmerEcan, assign to us our $0% interest in the venture as set forth therein. -. gul~ is avare o£ your posit~on under these leasea and o~ our intention to terminate the present Joint Venture Agreement a~ herein provided. You may be hearing from them shortly;in view of their future Joint participation with you'in these properties-. Very t'ruly yours, l~mas J. Hiklaucsch, TJM: CB: il .. Gulf 011 Co. Atlantic Richfield Ge. eral American 011 Co. '. · , . · .. EXI{I B I T II B ASSIGNMENT WHEREAS, under date of December 3, 1968, ueneraz ~merican Oil Company of Texas entered into an agreement in writing entitled "Joint Venture Agreement" with T. J. Miklautsch and C. Burglin of Fairbanks, Alaska, a copy of which agreement is attached hereto; and WHEREAS, said Joint Venture Agreement pertains to the following two State of Alaska oil and gas leases: Lease ADL-34622 which covers the following described tract Of 'land in Alaska: T. 12 N., R. 14 E., U.M. Sections: 3, 4, 9, 10; and Lease ADL-34623 which covers the following de~L~ribed tract of land in Alaska: T. 12 N., R. 14 E., U.M. Sec. 5: Ail 640 ac. Sec. 6: Ail 577 ac. Sec. 7: Ail, excl. PLO 1571 430 ac. Sec. 8: Ail, excl. PLO 1571 580 ac.; WHEREAS, Exxon Corporation succeeded to the interests of General American Oil Company of Texas; and WHEREAS, by instrument dated March 13, 1970, Exxon Corporation assigned to Atlantic Richfield Company (hereinafter sometimes callbd "Atlantic") one-half of Exxon Corporation's interest in and to State of Alaska Lease ADL-34623, subject to the terms and provisions of said Joint Venture Agreement; and WHEREAS, by letter dated June 11, 1975 (but received by Atlantic at a later date), T. J. Miklautsch and C. Burglin gave written notice of the termination of said Joint Venture Agreement in accordance with paragraph 12 thereof; NOW, THEREFORE, to the extent,, and only to the extent, that ,.- Atlantic may be obligated to do so by virtue of Atlantic's'aforesaid interest in ADL-34623 and in accordance with said paragraph 12 of said Joint Venture Agreement, Atlantic Richfield Company hereby assigns to T. J. Miklautsch and C. Burglin their respective interests in the Venture as set forth in paragraph 1 of the Joint Venture Agreement; subject, however, to the provisions of paragraphs 3 and 4 thereof which shall continue to be applicable to the interests of the parties in the leases regardless of the termin- ation of the Joint Venture Agreement. IN WITNESS WHEREOF, this agreement has been duly executed this ~ day of July, 1975. ATLANTIC RICHFIELD COMPANY - Attorne~ in Fact STATE OF ALASKA ) ) THIRD JUDICIAL DISTRICT ) · The ~-~egoing instrument was acknowledged before me this ~jz~ day of k~,~~O , 1975, by O. G. Simpson, Attorney in Fact for Atlantic~fiel~C mpany. J ---~-No at ry l~l-ij~ in and for Alaska. .. My Co n expires: 8/3/78 ~enotes ~ey Passages THIS iS EXHIBIT".,~" (' referred to in the Affi/iavit of ,' Settleme: ~wor'r, 'be~or"~--~e this ~ n DEC 1 9 2002 This Agreement, Conveyance and Acknowledgment is executed as of the ll~h day of April 1977, by and between GULF OIL CORPORATION,. a Pennsylvania corporation (' 'Gulf' ') as Buyer, and T. J. MIKLAUTSCH of Fairbanks, Alaska ("Miklautsch") , CLIFF BURGLIN of Fairbanks, Alaska ("Burglin"), and CHARLES HAMEL of Watertown, Connecticut ("Hamel") as Sellers, with Miklautsch, Burglin and Hamel being for convenience herein sometimes referred to as "MBH." WHEREAS, immediately Prior to May 16, 1975, MBH jointly with Exxon Corporation ("Exxon") were members of a Joint Venture (the ''Venture'') which owned interests in Alaskan Competitive oil and Gas Leases Nos. ADL 34622 and ADL 34623 (the ,,Leases''); WHEREAS, in addition to such Venture interest MBH owned a $4,000,000 production payment payable out of a portion of the gross proceeds from the Leases (the "$4 MPP") and asserted certain claims against Exxon, et al. in respect of the Leases; WHEREAS, by Letter Agreement dated May 16, 1975 ("May Agreement"), MBH agreed to sell their entire interest in the Leases to Gulf on certain terms and conditions; WHEREAS, because of disputes with Exxon, et al. which resulted in the filing of multiple lawsuits and other problems, the transaction contemplated by the May Agreement was not consummated, although Gulf did pay $7-1/2 million as part performance of Gulf's obligations thereunder, and MBH, after attempting to terminate the Venture Pursuant to its terms, Purported to assign to Gulf an undivided one-half' interest in the Leases by instrument dated July 14,1975 (the "1975 Assignment''). WHEREAS, Gulf and MBH have now reached a settlement with Exxon, et al. (the ,'Exxon Settlement Agreement", a copy of which is attached hereto as Exhibit A) and, desire to consummate their agreement with each other on the fgllowing basis: , Gulf agrees that MBH may keep the Seven Million Five Hundred Thousand Dollars ($7,500,000) paid to them in 1975 and concurrently herewith, shall additional sum of Seven Million Five Hundred Thousand pay to MBH,.~n Dollars ($~00,OOO). 2 , ~H hereby conveys to Gulf all of F~H's right, title and interest in and to the Venture, the Leases and all claims against Exxon, et al. relating to the Leases, in trust, however, for Gulf and M~H as their interest appear below: (a) The 40% working interest referred to in Subsection (4)(c) of Section Z of the Exxon Settlement Agreement is beneficially owned 80% by Gulf, 14.4%, by Miklautsch, 3.6% by Burglin and 2% by Hamelt and each of them agrees to contribute all of his or its interest in said working interest to a limited partnership (the ''Partnership") to be organized under a form of agreement attached hereto as Exhibit B (the "Partnership Agreement"), and executed concurrently herewith. (b) The $7-1/2 million production payment referred to in Subsection (4)(a) of Section I of the Settlement Agreement is beneficially owned 50% by Gulf, 36% by Miklautsch, 9% by Burglin and 5% by Hamel. Immediately u~on receipt of an assignment of the legal title to the Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 301. 770411-A.26 Gulf-MBH Settlement Agreement (c) $7-1/2 million production payment, Gulf shall reassign an undivided 50% interest in and to such legal title to MBH in the proportions shown above in full remittance of its trust obligation to do so. Ail rights and pr. ivileges in connect/on with the drilling of a s~ecial exploratory well (the "S~ecial Well ") which may be drilled under Subsection 7 of Section Z of the Exxon Settlement Agreement are (including all rights of information in connection therewith) owned by Gulf. However, at such t/me as Gulf has recovered the 500% of its costs out of production from said well as provided for in the Exxon Settlement Agreement, the Partnership shall have the same interest in such well as it has in said working interest in the remainder of the properties covered by, the Partnership Agreement. (d) The oil and gas operating rights surrounding the "Hamilton 'Well" are owned and shall be operated as partnership property the same .as though said rights were never segregated from said Lease ADL 34623. The mHamilton Well~ referred to herein covers a farmout of oil and gas operating rights dated March 12, 1969, a Quitclaim and reassignment of which is being made to Exxon, et al. under Section II of the Exxon .Settlement Agreement, the same well to be subsequently included in an assignment to Gulf under Subsection 8 of Section I Of the Exxon Settl.ement Agreement. (e) The Partnership shall assume and bear the full burdens attached to the GAO net profits interest referred to in Section II of the Exxon Settlement Agreement. (f) MBH, to the exclusion of Gulf or the Partnership, shall be the owners of the 'net.profits interest in State of A/aska Leases ADL 47464, 47645, 47646 and 474'6'7 which is 'to be assigned to them. pursuant to Subsection 3 of Section IV of the Exxon Settlement Agreement. When assigned, the .said net profits interest shall be owned 72% by Miklautsch, 18% by Burglin and 10% by Hamel. When, if and as Gulf acquires any interest in Block 1. T-12-N, R-4-E., U.M. or Blocks 7, 8 or 9, T-13-N, R-14-E., U.M., State of Alaska (the "Subject Lands"), Gulf agrees to convey to MBH an overriding royalty equal to two and one-half per cent. (2-1/2%) of the Market Value of the Petroleum Products attributable to the interest so acquired by Gulf (exclusive of lessor's royalty) which are produced from, and sold or used off, any.of the leases covering such lands. For purposes hereof, the terms "Market Value" and "Petroleum Products" have the meanings assigned to them in the. Partnership Agreement. If Gulf acquires an interest in any of the Subject Lands and within 180 days thereafter conveys a undivided fractional interest in a lease to a third party solely for Gulf's costs of acquisition, the interest so acquired by the third party shall not be considered to'have been acquired by Gulf. If Gulf acquires an interest in any of the Subject Lands and within 180 days thereafter conveys an undivided fractional interest in a lease in exchange for an interest in a lease covering other lands (regardless of whether any adjustment is paid or received in cash to reflect the difference in cost of acquisition of each such interest), the interest so conveyed by Gulf shall not be subject to the above overriding royalty, but the interest so acquired by Gulf shall be subject to a like overriding royalty. If Gulf's interest is pooled or unitized with other interests, said overriding royalty shall be calculated on the basis of Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 3 02 770411-A.26 Gulf-MBH Settlement Agreement Gulf's share of the combined interests. In all other cases, any transfer of an interest in which MBH has an overriding royalty shall be made subject to such overriding royalty. If Gulf acquires or contracts to acquire an interest in a lease from a co-owner other than by purchase, no overriding royalty shall' be granted with respect'to such interest. 4 o All other agreements heretofore entered into between the parties to this MBH Settlement Agreement or other claims asserted by one party against the other are hereby terminated. EXECUTED on the dates set forth below, but to be effective as of the day and year first set forth above. Date: 4-29-77 By GULF OIL CORPORATION Joseph O. Carter Attorney in Fact Date: 4/11/77 T. J. Miklautsch T. J. Miklautsch Date: 4/11/77 C. Burglin Cliff Burglin Date: 4-1~-7~ Charles Charles Hamel THE STATE OF Texas ) COUNTY OF Harris ) BEFORE ME, the undersigned authority, on this day personally appeared T. J. Miklautsch, known to me to be the person whose name is subscribed to the foregoing instrument', and acknowledged to me that he executed the same for the purposes and consideration therein expressed. 1977. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llth day of A~ . Barbara P. Browne Notary Public in and for Barbara P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 THE STATE OF Texas ) COUNTY OF Harris ) Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 303 770411-A.'26 Gulf-MBH Settlement Agreement. BEFORE ME, the undersigned authority, on this day personally appeared Cliff Burglin, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed. 1977. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llth day of A~ B~rbar~ P. Browne Notary Public in and for Barbara P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 THE STATE OF Texas · COUNTY OF Harris ) BEFORE ME, the undersigned authority, on this day personally appeared Charles Hamel, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llth day of April ~ 1977. Barbara P. Browne Notary Public in and for Barbara P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 304 ].1,'1!.."~002 10:$$ FA.~ 907 $64 4031 bp William H. Colbert BP II)0 t. lie.eon 81vd. P.O. Bo~ ~96612 Anchortge. AK ~51g-6612 Switchboard: ;907l 561-6111 Factlmile: (907) $6&-1i)31 Via..F. acsimile (907). 452-520_3 November 1,2002 Mr. Jack O. Hakkila C/o C. Burglin P.O. Box 131 Fairbanks, AK 99707 Reference: ADL 34623 Dear Mr. Hakkila' t have received the letter dated October 29, 2002, that you addressed To R.L. Skillern concerning unitization of ADL 34623. Ail future correspondence and contact with BP should be directed to me at the address above, and not to Ms. Crandall, Mr. Skillern or other BP employees. You have not provided any information that establishes your atleged ownership interest in ADL 34623. Without an ownership interest, you have no standing to petition for uni.t expansion. BP will not support your efforts to unitize a lease in which you have no ownership interest. ., Regards, cc: Brian T. McLaughlin, counsel to O. Hakkila Kerr & Ward, L.L.P. P.O. Box 2858 Midland, TX 79702 Krissell Crandall, BP R.L. Skillern, BP Jim Ruud, ConocoPhillips John Gallogl¥, ExxonMobil Camille Oeschli Taylor, AOGCC Commissioner 0 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter off Jack O. Hakkila and Arctic Basin Industries ,,',~ Plaintiffs ) '! Oil Company) ) i, General American !i of Texas et al ) Defendants ORDER Case No.: RECEIVED DEC 1 2002 0il & Gas Cons. C0mmissf0r, 3 AN-99-9114 CI After consideration it is hereby Ordered: 1. That the term of lease ADL 34623 be suspended effective December _, 2002 and not be permitted to lapse except by Order of this Court; and 2. That the State of Alaska, Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission are from enjoined terminating lease number ADL 34623 on or after December 8, 2002. AND THE GROUNDS FOR THIS ORDER ARE THAT: 1. Permitting the lease to lapse will prejudice the proper determination of the interests' of the Plaintiffs in lease ADL 34623 and prevent any possibility of pursuing exploration and'production activities if additional third by interests are introduced by re-selling the interests in lease 34623. 2. That it is necessary to preserve the status quo of the parties pending the hearing of the principal action. Dated this __ of December, 2002. Superior Court Judge d ~ tHE SUPERIOR COURT FOR TH[ STATE OF ALASKA THIRD JUDICIAL DISTRICT AT ANCHORAGE IN THE MATTER OF: JACK O. HAKKILA and ARCTIC BASIN INDUSTRIES Plaintiff, vs. GENERAL AMERICAN OIL CO, OF TEXAS et,al. Defendants. RECEIVED DEC 1 9 2002 A;aska 0ii & Gas Cons. Commission, Case No. 3AN-99-9114 CI. ~ERTIFICATE OF SERVICE I, Tina M. Harris, being employed with the law office of STEPOVICH, KEN-NELLY & STEPOVICH, P.C., hereby certify that a true and exact copy of MOTION FOR TEMPORARY RESTRAINING AND FOR PRELIMINARY INJUNCTION, MEMO WITH EXHIBITS has been sent via Courier to: State Of Alaska Alaska Oil And Gas Conservation Commission 333 West 7tn Ave, Suite 100 Anchorage, Alaska 99501 State of Alaska Oil And Gas Division 550 W 7tn Ave Directors Office, Suite 800 Anchorage, Alaska 995401 DATED this 3rd day of December, 2002. STEPOVICH, KENNELLY & STEPOVICH, P.C. 626 K Street Anchorage, Alaska 99501 Ph: (907) 279-9352 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of: Jack O. H~l~l, ila and Arctic Basin Industries Plaintiffs ) ) General American Oil Company) of Texas et al, ) ) Defendants ) Case No.: RECEIVED DEC 1 ~ 2002 Alaska Oil & Gas Cons. Commission .Anchorage 3 AN-99-9114 CI ENTRY OF APPEARANCE.. The Law Offices of Stepovich Kennelly & Stepovich, P.C. enters its appearance on behalf of the plaimiffs in the above captioned matter. Ali future motions, papers and pleadings may be served on pla~n~ffs by mailing the same to the address listed below. j ' t-~ 002 DATED this day of ~ day of December 2 . STEPOVICH KENNELLY & STEPOVICH P.C. 626 K Street Anchorage, Alaska 99501 (907) 279-9352 /, /,../4a,/' ....... T~ed Stei~ovich¥ ABANo. 8711113 Jack O. H,~ddla P. O. Box 1900S3 Anchorage, Alaska 99519~00S3 (907) 522-5940 In the District Court For the State of Alaska In Anchorage, Maska Jack O. Hakkila and Arctic Basin Industries, Vs. GENERAL AMERICAN OIL COMPANY of TEXAS HUMBLE OIL AND REFINING COMPANY GULF OIL COMPANY PHILLIPS PETROLEUM, INC. EXXON COMPANY, U. SA, INC. EXXON CORPORATION ARCO Al,ASK,k, INC. GULF OIL TI~UST, GULF OIL COMPANY, TRUSTEE CHEVRON, U. SJL CHEVRON, U.S~. TRUST, CHEVRON, U. SA., TRUSTEE RECEIVED DEC 1 ~ 2002 Oil & Gas Cons. Commission Anchorage ~ON CORPORATION TRUST, E~ON CORPORATION, TRUSTEE BP EXPLORATION, (AIASKA), INC. STATE OF AlAsKA, DMSION OF OIL AND GAS, ALASKA 'OIL AND GAS CONSERVATION'COMMISSION, CHARLES E. C'OLE, MICKAEL KOTOWSKI, DAVID JOHNSTONE, Defendants Two. J~trisdiefion. COMPLAINT COME NOW the plaintiffs by and through Jaek O. Hakkfla, pro ~ of Box 190083, Anehorage Masl~t 90519-0083 and for the eauses ofaetion against Defend,xuts, eomplain and allege as follows. JURISDICTION PlaintiffJaek O. Hakkila has been a resident ofthe State ofAlaska sinee June, 1969. Aretie Basin Industries has been domieiled in Maska since 1981. 10. 12. 13. · 1. Jack O. Haldkila agreed to represent C. Burglin via a' sales agreement rega~ling his interests in Pt Mclntyre leases ADL 34622 and ADL 34623 in An~st, 1990. 2. H~dckila fiu~heranore assigned a portion of his interests in the sales a~ement to Mark'Alexander of Houston, Texas. 3. The remaining interest was assigned to Aretie Basin Industries ofAnehortzge, Alaskm 4. Through .association with M~xander, Hakkila pursned a rigorous investi~o~tion oftitle on the leases in order to eonsmmnate a sale to a major oil eomlmny in Houston, Texas. 5. The title investigation was doeumented by Hakkila and Aretie Basin Industries. 6. A title etzrative was prodneed by Aretie Basin Industries for C. Burglin for his use in litigation against Exxon U.S~., Inc. and Areo Maska, Ine. in the period 1993-97. 7. This title eurative was forwarded to B~wglin's attorney, Charles E. Cole. S. Bueglin settled with Exxon Company, U. SJL, Ine. and Areo Maska, Ine. on August 14, 1997' in an out ofeourt settlement. 9. Burglin's title was not entel as eontemplated by AB I in forwa~ling this title information to Bm~lin and his attorney Charles E. Cole. Burglin has subsequently oflbrc~l sLxty-five l~reent ofhis interests in ADL 34622 and ADL 34623 to Jaek O. llakkila as they may be definc~l through litigation of his interests originating from the Deeember 3, 1968 joint venture agreement with Gener~d Ameriean Oil Company of Texas. 11. Jaek O. Ha~a has a.~ec~i to eonvey his interests in Bur~in's leases as they may be definc~! through litigation to inelude dam,~es to Aretie Basin Industries. Mark Mex~mder has been intbrme~l ofeontemplated litigation and has deelined to partieipate in this litigation. Venue is proper in Dista. ic~c Co, mt tbr the State ofMasl, t at Anehorage sinee reeord title for the leases has been held in the offices ofthe Division of Oil aml Gas, whose offiees have been loeated in various offiees in . · pa~oe Tlu-ee. Jm-i~lietion. 14. Anchorage throughout the l~riod 1968-1999. Likewise the offiees of the Maska Oil and Gas Conservation Commission have been loeated in Anehorage through the period of 1968-99. Key a,oz~ements affeeting the title em~ttive proee~s have been fbrwarded to the offices ofthe Division of Oil and Gas. The most reeent settlement between B~trglin, Exxon Company U.S.A., Ine. and Arco Maska, In~ was in a ease brought forth in the Third Judieial Distriet in Anehorage, Mas 'ka. COMPLAINT 15. The Alaska Oil and Gas Conservation Commission is eharged with looking after the Correlative Rights of working interest owners in oil and ~,~$ leases, royalty owners, lienholders, dehtors or any other lmrties with an interest arising out ofthe le~ses. The offiees ofthe AOGCC are loeated at ~001 Poreupine in North Mo~mtain View, Anehorage. This offiee is supervised by three Commissioners who serve on appointment by the Governor ofthe State of Alaska. 16. The Division of Oil anti Gas in the State of Maska Delmrtmeut of Natxtral Resourees is charged with the responsibility to traek rifle, so that the Maska Oil and Gas Conservation Commission etm properly alloeate a tHvision of interests in the leases to the proper owners of interest as the unit is prodneed. The Division of Oil and Gas is loeated at Suite S06 in the Robert Atwood Building in downtown Anehorage. The ~ease El~tbreement Supervisor is Carol (Wilkinson) Lee. Jmnes Eason is an employee of the Division or,Oil and Gas. Miehael Kotowski is an employee ofthe Division of Oil and Gas. W. The origin~ party to Leases ADL 34622 and ADL 34623 was Thomas J. Miklautsch. He was awarded these ... leases in a lease sale whieh took place on April 1,1967. 18. Mikhmtsch assigned a twenty percent interest in the leases to his lease broker, Clifford C. Burglin in 1968. 19. On December 3, 1969 Miklm~tseh and B~w~in entered into a joint venture agrce~nent with Genemd American Oil' 'Company of Texas, a eomlmny based in Dallas, Texas at that rime. Phillips Petrolemn sx!bsequenfly acquired this company. 20.Bu~in has remained as the only original joint venture partner throughout the period December 3, 1968 through August 14,199~ when he most recenfly settled with Exxon U.S~L, Inc. and Arco Maska, Inc. 21. In forming the December 3, 1968 joint venture, Miklautseh anti Bur~in assigned fifty percent of their interests, to the joint'venture in exchange tbr stock and a production pa~nent Title to the remaining fifty percent was to be held in the name of Gene~d American Oil Company ofTexas '~br convenience sake.' Page l%ur. Complaint 22.0n September 21, 1969 General Ameri~n Oil Company sold its fifty percent interest in ADL 34622 anti ADL 34623 to Hmnble Oil Comlmny. 23. Robert IL Riddle, Lands Manager for Humble Oil Comp~my, recorded 100% ownership in these two le~xses for E~xon. No new joint rent,we w;~s formed between Humble Oil and Refining and Miklautseh and Burglin. 24.Areo Maska, Inc. received a twelve an assigmnent of interest of one-half of the interest of Hmnble Oil and Refining Comlmny in ADL 34623 on March 13, 1970. 25. lVrom the time that Hmnble Oil Company recorded a one hundred percent ownership interes~ in ADL 34622 and ADL 34623. The State of Alaska Division of Oil and Gas has refi~sed to acknowledge the interests of Burglin, despite the faet that there was an attempt by Arco Alaska, Inc. to enter an assigmnent into the Division of Oil and Gas files on behalf of B~w~in. Throughout the period Septelnber 23, 1969 to A~x~st 12, 1999, the State of Alaska has maintained that ownership of these leases was vested one hundred percent in Hmnbl~ (now Exxon, U.S.A., Inc.) and its assignee Arco Alaska, Inc. and Arco Alaska, Inc.'s assignee British Petroleum, U.S~L 26.Burglin et al attempted to sell their interests in ADL 34622 anti ADL 34623 to Gulf Oil Comlmny in 1975. The Division of Oil anti Gas never accepted these assigmnents. Exxon Company U.S~k. and Arco Alaska, Ine~ sued Miklautseh, Burglin, and Hamel.. 2~. Settlement of the liti~o~tion resulted in two settlement agreements, the April 29, 197~ Exxon Settlement A~o~eement and a simultaneous Gulf-MBH Settlement Agreement~ ,.. 2S. Tbe E~xon Settlement Agreement and the Gulf-MBH Settlement a,o~-eement were to work as follows. The Exxon Settlement ~Agreement provided that Miklautseh, Burglin, and Hamel could keep the payment of $~.5 million reeeived from Gulf Oil Company. G~df Oil Company would .hold the interests of Miklautseh, ]~ur~in, and Halnel in trust while they drilled .for oil. These interests of MBH eonsisted of the lease interests of Miklautsell and .B~glin, their rights title and interest in the ventx~re(s), and all elaims against Exxon Comlmny, U.S~k. At the time that Gulf produeed oil a limited partnership would be formed in whieh Gulf would serve as general partner, and MBH would be limited partners. 29.The Exxon Settlement Agreement e~trved out an ext~ ten l~reent for Exxon on ADL 34622 and .an extra 10 l~reent tbr Arco anti Exxon on ADL 34623. The State of Alaska has had a copy of the first 30 pages of this agreement since it was forwa~l~ to them in i992. The copy is in the Division of Oil and Gas. (note that the sLxteen exhibits to this agreement whieh were also forwarded by Mr. Burglinto the Division of Oil and Gas can not be located in the DOG files). Mr. Mike Kotowski achninisters the unit files in the Division of Oil and Gas. He maintains that documentation of the Exxon Settlement A.o~ement is of no interest to the State of Alaska and is .an internal matter between Exxon anti B~tr~in. Pa~oe Five. Complaint 30. Gulf Oil Company driHc~l two dry holes on ADL 34622 ,,md plug~oed ,-md abandoned the wells. Consequenriy no limited partnership was tbrmed. The interests of MBH remained in the Gulf Oil Trust with Gulf oil as trustee for MBH. GulfOii Company never prmluced a trust agxeement for MBH. 31. Gulf Oil Company sold their interests to Chevron U.$~k. Conseqnenriy Chevron beemne trx~stee for MBH's interests, as they wo~dd have appeared in the Gulf Oil Trx~st 32. Chevron sohl their interests to E~xon Company, U.S~ Exxon Comlmny would now hec0me trustee for MBH's fifty pereent interests in addition to owning ri~eir fifty pereent interest in ADL 84622 and the joint fii~y pe~eent interest in ADL 84623 whieh riley owned with Areo Maska, Ine. 33. In 19SS, Exxon and Arco deeided to produee the Pt. MeIntyre Field along with their partner in mljoining leases, British Petrole~un. E~xon represented to Miklautseh, Btw~in and Hmnel that they were general pm~ners in a limited partnership and p~wported to buy ont the limited partnership interests of MBH in a partnership whieh had not been fo~qned. 34.This lmrehase resulted in litigation to deter~nine the vahmtion of these 'pm~nership interests.' 35. MBH lost their lawsuit in Judge Blaek's jtmisdietlon in Houston, Texas. They appeaied to the Fifth Circuit Court of AppeMs in New Orleans ami lost. Case No. 92-2415 was heard before Circuit Judges Gavwood, Davis, and Smith with Circuit Conrt .~¢lge Smith rxding in favor ofthe Plaintiffs. 36.A ~awsuit was filed in the Thirxl Judieiai Court in Anchorage, Alask~ in 1990. ~l~nis e~ase was continued once the appeai was completed in the Ivitth Circuit in New Orleans. ABI produced a title curative for review by Bm~glin whieh he forw.arxled to Charles E. Cole. Mr. Bm~lin settled with Exxon Comlmny, U.S~L out ofeourt~ Tlds settlement was sealed by Judge Holhtnd. .~ 3~r...~t the time that MBH shed E~cxon Company, U.S~k. in the early 1.990's an independent consultant verified that 28% ofthe Pt~ McIntyre Field lies on ADL 34622 aml ADL 34623. 88. Reeent lmblieation of field prmluetion by the Maslm Oil and Gas Consewation Commission shows that Pt MeIntyve has now p~lneed 2~'5,000,000 ba~els of oil. This field has a substantiai life of pr~iuetion inelmling the flowing of oil from ADL 84628 whieh has not been produced at this thne and whieh appears to be on a high lmint ofthe structure. · .' 89.A proper title cm-ative which reverses each assignment of interest as it affects Burglin's original ten percent interest in the December 8, 1968 Joint Ventxtre Agreement, would minimaily show a ten percent interest in twenty eight percent of 600,000,000 Imf-reis ofoil. The value ofthis oil could be minim~ assessed at ten Pa~ Six. Complaint 40.Minion U.S. dollars l~r barrel at the wellhead. The value of this 8.4 million barrels c~dd therefore be imputed at eighty fo~w million doli~. 41. This title curative was prodneed tbr review by Charles E. Cole, attorney for C. Bm~in. Mr. Cole produced an unknow~ settlement tbr Burglin whieh has been sealc~l by Jmlge HollamL 42. G~df Oil Company as trustee at no time prodneed a trust doeument for MBH, nor did they aetivate the G~dt: MBH Limited Partnership through the required produetion ofhydroearbons.. 48. Chevron, U. S. A. hmi a trust responsibility to MBH. At no time did they produce a trust doezunent for review by MBH. Defendant Exxon Company, U. SJL hml a responsihflity as trustee for the trust reslmnsibilities inherited from Chevron U.S~A~ At no time ~Hd Exxon Comlmny U. SJk. produee a trust doemnent for review by MBH. 45. Despite the entry ofthe Exxon Settlement Aganze~nent and the GulfMBH Settlement Agreement in the files of the State of Alaska, the important sixteen exhibits to the Exxon Settlement Agreement are not available in the lease files for ADL 34622 and ADL 34623. 46. On October 13, 1993 a meeting was cndlcnl at the eonferenee room of the Maska Oil and Gas Conservation Commission at ~001 Poreaq~ine in Anehorage Maska. MI parties with interests in the respeetive leases Under eonsideration to be ineluded in the Point MeIntyre P~eipating Area ofthe Prudhoe Bay Unit were invited to attend. The meeting was ealled for 9:00 ~m. Mr. Hakkila attendcnl as a l~rsonal representative of Cliflbrd Burglin and on his own behalf. Other partieipants eonvened around the water eooler until 9:20 a.m. at whieh time Mr. Johnstone on behalf of the commissioners related that this meeting was mljourned as there were no matters for eonsideration to present~ This aetion prevented Hakkila on behalf of his own ami Burglin's intere~ from appearing before a meeting to diseuss ownership interests in the Pt. MeIntyre leases being eonsidered for unitization into the Pr~dhoe Bay UniL 47. At the time of the Exxon Settlement Agreement, Phillips Petroleum, sueeessor in interest to General Americ~m oil Company received interests arising from a well drille~! by Hamilton Brothers on ADL 34623 whieh were assigned to Burglin. These interests have not been assigned to Burglin at this time. 48. A breach of contract has occurred tlwough the wiilfid, fraud~dent, intentional, reckless and/or negligent aets and representations of those defendants who were assignees of the rights derived from General American Oil Comlmny of Texas as those rights were assigned to Hmnble Oil and Refining Company and its successors and heirs. These defendants ~Hd not continue in ~od faith the ori~nal Deeember ~, 196S joint ventx~re with Mikhmtseh ami Burglin. They deliberately concealed the existence of the December ~, 196S joint vent/rte agreement t~om the files of the Division of Oil and Gas. At the time ofthe Exxon Settlement Agreement, Exxon carved an mlditiomd ten l~reent for itself from ADL 34622 and F~xon ami Arco earved five percent apiece t~om Miklantsch, Hamel ami Burglin. This agreement demonstrates a sLxty percent interest in ADI~ 34622 for Exxon and a thirty percent ownership tbr Exxon in ADL 34623. Arco is shown to own .thirty l~reent in ADL 34623. A further breach of contract occurred through the failure to create The Gulf Oil Trust by Gulf Oil Company and to serve as trustee for the interests of MBH as spelled out in the Exxon Settlement Agreement and the Gulf-MBH Settlement Agreement. This breach of contract continued as Chevron, U.S.A. and Exxon Corporation succeeded Gulf Oil Company as trustees for MBH. Page Seven. Punitive Dama~oes. 49. A willfid, tYamlulent, intentional, anti reckless act oceurrexl when E.~xon Corlmration and Exxon Company, U.S~ attempted to acquire interests from MBH in a nonexistent general partnership for which they were trnstee in 1989. 50. In acquiring interests of the nonexistent general lmrtnership, Exxon breached its tn~st reSlmnsibilities by creating a nonexistent limitexl partnership. Previons alle~ttions have been that l~xon violated fidneiary responsibilities as a general, lmrtner. The fraud~dent representation that these assets hml been ereated through the produetion of oil by Gulf Oil Company amd the fidim-e for E~cxon to reeognize that as trustee they held -all elaims ,~,~ain~ Exxon in tru~ are a deliberate breaeh ofeontraet and breach oftrnst responsibilities. 51. As a direct result of the franchdent, intentional, reckless and/or ne~igent ~ and representations by Defendants, the breach of Defendants' obligations held in trnst by Plaintiffs, and other breaches set forth in this complaint, plaintiffs 'have been dmnaged and hereby claim a sLxty-five percent interest in ten percent of ADI~'s 34622 and 34623 throngh an ~ag~eement with C. Bm~lin dated Augx~st 11, 1999 an amo~mt in excess of sixty-five percent of $84,000,000, this amount to be proven at trial. This claim is .~,o~ainst successors in interest to General Ameri~m Oil Company in the December 6, 1968 Joint Venture, nmnely Phillips Petroleum, Hmnble Oil Company, Exxon Corporation, Exxon Company, U.$~L, Arco Alaska, In~, Gulf Oil Company, Chevron U.S. A~,, and British Petrolemn Exploration (Alaska), Inc. 5~.Alternatively, Defendants as legal owners to the rights' of Burglin, whose rights were in trust to Gulf Oil Cmnpany, Chevron, U. SJL, and Exxon Corporation, ehdm a breach in integrity in the hantHing of this trx~st relationship. Plaintiffs have been d~unaged by this breaeh in violation oft~st responsibilities and are entitled to damages in aeeord with applieable Alask~ Statutes and proofat trial, but in excess of $54,600,000. 58. The State of Maska Division of Oil and Gas breaehed its responsibilities by deliberately eoneealing intbrmation it has that showed Bnrglin to have a working interest in leases ADL 34622 and ADL 3462~. T lo PUNITIVE DAMAGES A pattern of fraud and misrepresentation presents itself throughont the handling of title on behalf of Bur~in tlxronghout the many transfers of interest arising out of the Deeember ~, 1968 Joint Ventnre with General Ameriean Oil Company of Texas and therefore entitle Plaintiffs to pmdtive ¢ .lmn~,oes in an mnount in accord with proofat trial, but in excess orS10,000,000. Page Eight. P~yer for Relief. PRAYER FOR RELIEF WHEREFORE, Plaintiff.s, and each of them, request that the Court enter jud.o~nent in their favor ms follows: 1. For compensatory dam~es in excess of $54,600,000, for Plaintiffs at triM, but in aceordance with proof at time of trial; 2. Punitive damages in an amonnt in excess of $2~,000,000 in aec~rxlance with proof at time of trial for Plaintiffs. 3. Costs and Attorneys fees in lmrsuing this action; and 4. For such and fi~rther relief as the Co,mt may deem just and equitable. Dated at Anehor~ge, Alaska, this thirteenth day of Angx~st, 1999. Hakkila P. O. Box 190083 Anchorage, Maska 99519-0083 IN ~ DISTRICT/SUPEIHOR COURT FOR ~ STATE OF ALASKA AT Anchorane Jack O. Hakkila, and Arctic Basin Industries, vs, Haintiffs Exxon Corporation, et al , state upon oath or ~tion that the following facts are 1. an aad aed the corn on 7,1999, ~ compi~ aim is being filed in Superior Court as opposed to Dis~et Court for the State of Alaska. 2. The naming of defondants will include Exxon Mobil Corporation, successor to Erxon Company, U~.A. and Exxon Corporation. 3. Hamilton Brothers Oil Company of Calgary, Alberta wm be added to the complaint. They are now owned by Bm' Petrole_m: Canada,/nc. Bm' Petroleum, Canada, Inc. has recommc~nded serving the legal department at Bm' Pemdeum in Houston, Texa~ These cmnpanies ~ both be served SurmnOl~. 4. Iron Number 24 should rote, "Arco Alaska, Inc. received an assignment ofintere~ of one-half of the interest of Hmnble Oil and Refinin~o Company in ADL 34623 on March 13,1970. 5. ~ 40 which ~s a ~on ofitem 39 should read as follows regarding the sentence which hegira on page five under item 39, "The value of this oil could be mlnlm~ily assesSed at ten U~. dollars per barrel at wenhea&" .- 6. The plaintiffs request that the complaint be brought forward without Prejudice under Article I, Section 207 of the Uniform Commercial Code. The plaintiffs would llke this case to be tried under P. O. Box 1900~, Anchorage, Ak. 99519-0083 Subsedbed and sworn to or affnxned before me at/~ ~. ~,o fc~ ~_. , Alaska authorized to administer oaths. My commission expires: C~/ ALASKA OIL GAS CONSERVATION FAX 907-276-7542 PHONE 907-279-1433 COMMISSION FACSIMILE TRANSMITTAL SHEET / TO: //,~, FAX NUMBER: PHONE NUMBER:, RE: SENDER'S REFERENCE NUMBER: YOUR REFERENCE NUMBER:. [] URGENT [] 'FOR REVIEW [] PLEASE' COMMENT [] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: , , ,. AOG'CC 33'3 WEST 7TM AVENUE, SUITE 100 ANCHORAGE, AK 99501-3935 ALASKA OIL GAS CONSERVATION FAX 907-276-7542 PHONE 907-279-1433 ( COMMISSION FACSIMILE TRANSMITTAL SHEET TO: COMPANY: FAX NUMBER: PHONE NUMBER; SENDER'S REFERENCE NUMBER:. RE: [] URGENT [] FOR REVIEW [] PLEASE' COMMENT . ,[] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: AOGCC 33'3 WEST ?TI-I AVENUE, SUITE 100 ANCHORAGE, AK 99501-3935 DEC-17-2002 TUE 03:49 PH ~K Ir"rOT SYSTEH F'~X NO. 1~840720 ' ~ . , ' . ~,' I~ IH~ S~P[~IOR ~0~1 FOR TH~ ~lfi Off ,, ,: ', , · T~IRD ]UDIC~L DI~RI~ AT ANCHO~GE J~CK O. I-I~KKi~, and , ' "AR~C BASIN INDU~RI~, ' ' ' , Plaintiff, . ' ,, EXXON CORPO~ON, ~. ai,t ., , uemnoan¢. ' ' . ..... '..--'-.~ ........ , .... Case No. 3AN-99-9114 CI ,~ , ~, h~arin~ ~n plaintiff's morton' for lempora~ Re~ainin~ sche~dled f6r December 20t 2002 at 16:00 a,m. in ~ou~room ~3 of'the Nesbe~ ' , , C~u~ho~i~e~ Plaintiffs shall im'~ately pr~vid~ notice of this hearing ~ all . defen~n~ and shall, be p~pared, at ~e hearing, to provide proof that .such ' noUce was made. .' DATED 'at Anchorage, Naska,'this ~',?~ day of December 2003. , , , ', ~ ' .. . . SuperiorCoud3udge , ] ~,rti~ t/tat on'~mber lg 2002 ' ' , A ~py W~ mail~/~x~ ~: , ' T, .¢tO~vlch , ,, -,..,,, , , ,'RECEIVED, . .,.' , DEC 17 2002 ', ' " ' '" ~Oil&G~Cons. P, 01/01 Jack Hakkila Letter dated October 29, 2002 The letter concerns two points; 1) Mr. Hakkila is preparing his claim for ownership in lease ADL 34623. 2) Mr. Hakkila believes ADL 34623 is being drained by production at Point McIntyre and should be included in the participating area. Some inferences about the nature of the first point can be drawn from the DNR case file abstract for ADL 34623. The lease was purchased in 1967 by Thomas Miklautsch (100% WI, 87.5% RI). In 1968 Miklautsch assigned 20% WI and 17.5% RI to Clifford Burglin. In 1969 Miklautsch and Burglin together assigned 100% WI and 87.5% RI to General American Oil (GAO). All future claims to ownership in the lease evolve from this transaction. Apparently .all working and royalty, interests were assigned to GAO at this time. An .overriding royalty assigmnent is the only way I can think of that any interest was retained in the property. The case file abstract doesn't mention any of this because interests of this kind' are not approved by. the state. Some record of the transaction may have been filed in the appropriate reeorder's office. In 1969 GAO assigned 100% WI and. 87.5% RI to Humble Oil. The lease ownership was divided through the years until it now stands at 50% BP, 25% ExxonMobi125% ConocoPhillips., .. In 1975 Miklautsch and Burglin applied to assign interest in the lease to .Gulf Oil Corp.. Several weeks later the application was withdrawn. In 1977 a settlement agreement with Gulf Oil Corp. caused a limited partnership 'named "GulfMBH-Alaska" to be formed. The limited · parmership owned some sort of interest in ADL 34623. ,' Krissell Crandall.' s letter to Mr. Hakkila dated September 3, 2002 indicates "GulfMBH-Alaska" owned "working interest" in ADL 34623.' She also states that Mr. Burglin sold his interest in ADL 34623 to Exxon in 1989. c Mr. Hakkila claims he is the successor to Burglin's ADL 34623 interest from the 1977 settlement and that he still owns some interest in the lease. The second point is based on the fact that ADL 34623 is high to the Kupamk Fm. oil/water contact at Pt. Mclntyre. The attached map shows the lease in the NW comer. The second attachment comes from the field roles, and describes stratigraphic trapping along the west side of the field. I suppose Mr. Hakkila doesn't think the evidence is very good. The evidence comes from a dry hole and poor producers along the west side of the field. This matter could Snowball into a major issue, but I think the basis for the decision has been borne out by the field's production history. Hakkila letter Subject: Hakkila letter Date: Fri, 01 Nov 2002 07:29:53 -0900 From: Cammy Oechsli Taylor <Cammy_Taylor~_~admin. state.ak.us> Organization: DOA-AOGCC To: Bob Crandall <bob_crandall~admin. state.ak.us> CC: Dan Seamount <dan_seamount~admin. state.ak.us>, Mike Bill <mike_bill~,admin. state.ak.us> Bob, Jack Hakkila provided the commission with a copy of a letter he sent to BP, Phillips and Exxon asking them to join him "in a voluntary petition to enjoin ADL 34623 within the Prudhoe Bay Unit as part of the Pt. McIntyre Field." Although the letter does not ask the Commission to take any action, we should have an understanding of the situation in order to be prepared to address' potential conservation issues. You indicated you knew all about this issue. Would you please prepare a written summary to educate us on the subject of this lease and identify what you believe the conservation issues to be? Is it possible t.o provide that to us by the end of the day on Tuesday, November 5, 2002? Thanks, Cammy Cammy Oeehsli Taylor <cammy_taylor~admin. state.ak.us> Commissioner Alaska Oil and Gas Conservation Commisison Department of Administration 1 ofl 11/1/2002 7:30 AM ALASKA OIL GAS CONSERVATION FAX 907-276-7542 PHONE 907-279-1433 COMMISSION FACSIMILE TRANSMITTAL SHEET COMPANY: FAX NUMBER: PHONE NUMBER: TOTAL NO. OF PAGES INCLUDING COVER: SENDER'S REFERENCE NUMBER: RE: YOUR REFERENCE NUMBER: [] URGENT, [].FOR REVIEW [] PLEASE COMMENT [] PLEASE REPLY [] PLEASE RECYCLE NOTES/COMMENTS: AOGCC .333 WEST 7TM AVENUE, SUITE 100 ANCHO,RAGE, AK 99501-$935 Jack O. Hakkila C/o C. Burglin P. O. Box'131 Fairbanks, Alaska 99707 Fax: (907) 452-5203 Calgary, Alberta October 29, 2002 Mr. R. L. Skillern (907) 564-$200 lip Exploration (Alaska), Inc. Mr. Jim Ruud (907) 263-4933 Phillips Alaska, Inc. Mr. John Galiogly (713) 656-0280 Exxon/Mobil Production Company . Gentlemen: Re: Unitization of ADL 34623 By the accompanying letter dated September 3, 2002, Krissell Crandali, Sr. Landman, BP CExplorat~on) Alaska, Inc. states intentions of allowing ADL 34623 to expire for re-bidding in the October 2003 areawide lease sale. We are in the process of preparing our claim' for ownership in the lease for presentation to Mr. Colbert as she has suggested. We believe that this lease is being drained by production from ADL 34622 according to AOGCC maps of the Kuparuk Formation as it extends to ADL 34623. We also have other reasons to believe that this lease is already being produced and that Sadlerochit production from this lease i.s also being drained from ADL 34622, Consequently, I would lik~ to ask that you join us in a voluntary petition to enjoin ADL 34623 within the Prudhoe Bay Unit as part of the Pt. Mclntyre Field. Because of the short time limits prior to the December 8, 2002 expiration date, we need a response to this request within five days. Please note that I am traveling and' may best be reached by fax at the above address. Sincerely, · hck O. Hakkila Copy to: Alaska Oil and Gas Conservation Commission (907) 276-754'2 Witness: C. Burglin RECEIVED OCT ZOOZ FII.E No,734 09~10 '02 0~:Szl ,,~...'. bp Krissell Crandail ~C~ 2/ 3 Mr..Jm3k O. Hekkila P.O. Box I KX)a3 Anchorage, AK g9619-0083 Relezen~,e: ADL ~ Dear Mr. Hal~kila: Thank you for your lettem of March 30 and June 1. 2002 expressing your interest in farming-in to ^DL 34823. BP Exploration (Alaska) Inc. operates ADL 34823 on behalf of itself, ExxonMobil Production Company ("Exxon"} and Phillips Alaska, Inc. ["Phillips"i; BP, Exxon and Phillips are the working interesx owners in the lease, with 50%, 25% and 25% ownership, respectively. BP, Exxon and Phillips are continuing to evaluate Options for our jointly held acreage located' to the North of Prudhoe' Bay Unit, and are not interested in' pursuing a sale or farmout of ADL 34623 at this time. If we do not progress ~tiviW on the lease; it will expire and the acreage will be available for bidding et the October 2003 areawide lease sale. : In your lettem and in various telephone oonversalions with representatives of Exxon, Phillips and BP,. you assert 'that you have some ~ort of {merest in ADL 34623 as a sug~'essor Io Cliff Burglin pursuant to an agreement between. the two of you dated August 13, 1999. . '. As of Augus[ 13, 1999, Mr. Burglin did not own any interest 'of record in ADL 34623 'that he could ha~ transferrecl to you.. Mr. Burglin was a former limited partner in Gulf MBH-Alaska, which wes a former working interest owner in ADL 34623. Mr; Burglin solcl his limited partnership interest 1o Exxon) in 1989. Mr. Burglin ~anno! transfer a partnership interest 1o you in 19gg that he already sold to Exxon in 1989. You .seem to claim that you have succeeded to Mr. Burglin's "rigl-~" under the 1977 Settlemen~ Agreement wlth Gulf. Oil Company that led to the formation of RECEIVED OCT FILE No.734 Og/lO '(~ og;Ex5 ., FP.X ;g15 L September 3, 2002 Mr, Jack O. Hal~kila Page 2 Gulf MBH-Alaska. We do not see' any basis for your c~aim that ~e 197? Agreement granted Mr. Burglin any rights with respect to ADL 34623 that survived his sale of the limited partnership interest to Exxon. Mr, Burglin and other limil;ed partners that sold their limited partnership interests later sued Exxon. alleging fraud, misrepresentation and breach of fiduoia~/duty arising out 'of the sale. The federal Fifth Circuit Court of Appeals ruled in Exxon Coraoratiort v.. Bur. cilia, 4 F.3d 1294 {19931, that Mr. Burglin and the other limited Partneis had no valid claims against Exxon, (Copy of decision · enclosed.I Beoause Mr. Burglin°s claims against Exxon under the partnersl~ip agreemen~ were ruled invalid by the ~ourt~, the claims are still invalid regardless of any purported transfer of those claims lo you. BP, Exxon and Phillips are willing to review any additional dOCuments you can provide that you believe establi$1~ e chain of title that creates an owiqership 'interest in your favor. However, all future contacts with BP should be directed to our Assistant General Counsei, William H. Colbert, at the letterhead address above, Reoards, Ena: Ex_,<_~_n Cor.aorafion_v..Buralin cc: Brian T. McLaughlin, counsel to J. Hakkila Kerr &.Ward, L.L,P, P,O. Box 28F~ Midland, TX 78?02 William Colbert, BP David Frazier, Exxon Paul Wharton,' Phillips ;3! STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 333 W. 7th Ave, Suite 100 ANCHORAGE, ALASKA 99501-3192 REQUEST FOR EXAMINATION OF AOGCC RECORDS I, the undersigned, request that I be authorized to examine the AOGCC records listed below, I agree not to remove or alter the contents of records and I agree not to remove the records from the room designated for examination. I certify that I am neither a party, nor representing or acting on behalf of a party, involved in litigation in a judicial or administrative forum with the State of Alaska or a public agency to which these recor& are relevant. Signature:_ ~.~.c~ L(3.: .... /~c'--~~c~ AOGCC RECORDS REQUESTED: Printed Name: Company/Firm: Address: FOR AOGCC USE ONLY: Date and Time Records Requested (6 AAC 96.320): Date Notice of Receipt of Request Sent (6 AAC 96.310): Date Additional Information Requested (6 AAC 96.315): Date and Time Records Provided for Review: Date and Time Records Returned: Name of AOGCC Employee Handling Request: AoGcc will respond to this request as .soon a practicable, but no later than.the 10th working day after the request is received (6 AAC 96.325) This request is a public record.. (6 AAC 96.320) m:wccpic/chcckout.doc d IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of: Jack O. Hakkila and Arctic Basin Industries VS. Plaintiffs General American Oil Company Of Texas et al.;. Defendants MOTION FOR TEMPORARY RESTRAINING AND FOR PRELIMINARY INJUNCTION Case Number: 3 AN-99-9114Cl Plaintiffs, by and through counsel, hereby move the court for immediate entry of a Temporary Restraining Order and for a hearing to determine whether the TRO should be converted to a preliminary injunction which enjoins the State of Alaska Division of Oil and Gas and all other defendants, their agents and their successors from terminating lease ADL 34623 or in the alternative, suspending the term of the lease until the principal action in Jack O. Hakkila and Arctic Basin Industries v. General American Oil Company et al, Case Number 3 AN-99-9144Cl can be heard. This motion is filed pursuant to Rule 65 of the Alaska Rules of Civil Procedure, is supported by the Complaint filed by the plaintiffs, the affidavits filed herewith, and the memorandum of points anc~uthorities filed herewith. DATED, thisbe_ day of December, 2002. Ted Stepovich Stepovich, Kennelly & Stepovich, P.C. 626 K Street A n ch o ra, ge~"~"k~'9~501' (907,)/270- 9,..~ ~,~?. ~_ .,, Ted Step0vicn ' ' ABA No. 8711113 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of.' Jack O. Hakkila and Arctic Basin Industries Plaintiffs ) General American Oil Company] of Texas et al ) ) Defendants .) MEMORANDUM IN SUPPORT OF TEMPORARY RESTRAINING AND PRELIMINARY INJUNCTION Case No.: 3 AN-99-9114 CI When the court is considering a request for a Temporary Restraining Order and Preliminary Injunction, four factors are considered. /LO. Smith Corp. v. F.T.C., 530 F.2d 515 {3rd Cir. 1976). Those are: 1) whether the moving party has shown that it is likely to prevail on the merits, 2) whether the movant has demonstrated that he would be irreparably harmed if the preliminary injunction is denied, 3) whether the grant of the injunction would harm other interested parties to a greater extent than it would benefit movant, and 4) whether the public interest would be served. When irreparable injury is apparent the need to show probable success on the merits becomes a less stringent standard and the Court applies a balancing approach. Amalgamated Tran. U., v. Sunline Tram Aac¥., 663 F.Supp. 1560, 1564 {D.C. Cal. 1987); See also Brenda v. Grand Lodae, 584 F.2d 308 (gth Cir. 1978); cert dismissed, 441 U.S. 937, 99 S.Ct. 2065, 60 L.Ed.2d 667 (1979); and William inglis & Sons Baking Co. v. ITT Continental Baking Co., 556 F.2d 86, 88 {9th Cir. 1975). If balancing the hardships shows the scales tip heavily toward plaintiffs, in that plaintiffs will be irreparably harmed,' a showing of likelihood of success on the merits is less important a burden for the potentially injured party. Brenda, at 315 See also Oakland Tribune, Inc. v. Chronicle Publishing Co., 752 F. 2d 1374 (gth C~r. 19S$). Plaintiffs seek a restraining order and preliminary injunction with respect to the above captioned litigation. The State of Alaska Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission are named as defendants in this action and the purpose of this motion is to prevent the termination or the lapse of lease ADL 34623 on December 8, 2002. It is submitted that a temporary injunction is required to preserve the rights of the plaintiffs prior to the hearing of the principal action, to prevent prejudice to the proper determination of the interests of the plaintiffs, to prevent any further acts which will deter any possibility of pursuing exploration and production activities with a view to extending the term of the lease and to prevent any other activities which will unduly complicate matters by introducing additional third party interests in the event that the lease is sold to a third party. As the court is aware the 'legal elements for both restraining orders and preliminary injunctions are a probable right to recovery, imminent irreparable harm and no adequate remedy at law. Fasken v. Darb¥, 134 O & GR 302; See State v. Norene, 457 P.2d 926, 930-931 (Alaska 1969). It is submitted that the elements of a temporary injunction are met in the particulars of this motion. The rights of Cliff Burglin and Thomas Miklautsch are clearly established prima facie in the documentary evidence and by the conduct of the parties in addition to the numerous breaches of fiduciary obligation owed to these parties with the result that there is a probable right to recovery. Imminent' irreparable harm will occur if the leases are permitted to terminate and are subsequently leased to another party as any potential right to exploration and recovery will be lost and there is no adequate remedy at law to prevent the loss of rights upon termination of the lease described as ADL 34623. Where there is a bona fide dispute regarding title to an oil and gas lease and any rights arising under it, issuance of a temporary injunction to maintain the status quo pending trial of the principal case is proper. Litfleiohn v. Finder, 15 O & GR 72 (Texas Ct. App., 1961); and Morse v. Earnest, Inc.., 54 O & GR 323 (Okla. Sup. Ct., 1976). A temporary injunction is required in the case at bar to prevent the termination or lapse of lease ADL 34623 and to preserve the status quo and the rights of the plaintiffs, which rights will be prejudiced by the termination or lapse of the lease and by any possible re-sale of the lease interests to a new third party lessee. The term of a lease may be suspended from the time that the lease's validity is brought into question by a landowner until the date when thc trial court rules on the principal action. Where the primary term of an oil and gas lease is due to expire prior to the court's final decision, the term of the lease may be suspended until the final decision is rendered and then thereafter extended for a period equal to the period during which the lease term was suspended. Pennington v. Colonial Pioeline Company, 32 0 & GR 1 {U.S. Ct. App, Fifth Circuit 1968) {emphasis added). It is further submitted that reasonable time should be permitted to comply with such lease terms and what is reasonable time depends upon the circumstances. Jones et al v. Moore et al., 10 0 & GR 963 (Okla. Sup. Ct. 1959). The title to lease ADL 34623 has been brought into question in the present case and it can be presumed that without the benefit of a temporary injunction being ordered to restrain the State of Alaska Division of Oil and Gas and the Alaska o 0 !i Off and Gas Conservation Commission from terminating lease ADL 34623 or an '. i order be issued to suspend the term to prevent it's lapse, lease ADL 34623 will be ii suspended prior to the hearing of the principal action. Where, as here, there is a probable right to recover either all or at least part of the title in question, plus substantial damages through lapse of the lease term, then a temporary injunction may be issued. Garcia v. Sun Oil Company., 70 & GR 19.56 (Texas Ct. of Civ. App., 1957). The present litigation has been commenced respecting proper title to lease ADL 34523. The present case was filed in 1999 and has further cast the proper ownership and title to lease ADL 34623 into doubt. The litigation has been f'~led as plaintiffs have been frustrated in their attempts to pursue exploration and production of off and gas on lease ADL 34623. In turn the litigation frustrates their attempt to explore and produce. If a lessee is prevented by litigation from commencing operations within the time stipulated in thc. lease, he is'entitled to an extension for the time of such hindrance if he is successful in the suit, Greet v. Carter Oil Co., 25 N.E. 2d 80S (Illinois Sup. Ct. 1940). It is further submitted that the wrongful decisio~:~ .in October, 1993 by the Alaska Oil and Gas Conservation Commission to exclude lease ADL 34623 from the Point Mclntyre Participation Area of the Prudhoe Bay Unit prevented the plaintiffs from pursuing their interest in exploring and producing off and natural gas on lease ADL 34623. Where a lessee's failure to produce or to commence or continue drilling operations during the primary term is due to the wrongful interference by the lessor, the lessee's failure may be excused and the lease time period extended. Jones et al v. Moore et al., 100 & GR 963 (Okla. Sup. Ct. 1959). It is the plaintiffs' position that the wrongful decision by the Alaska Oil and Gas Conservation 0 Commission to exclude lease ADL 34623 from the operation of the Point McIntyre Participation Area in the Prudhoe Bay Unit constitutes such interference. Reasonable time should be permitted for a lessee to comply with such lease terms and what is reasonable time depends upon the circumstances. Id. Because of it's exclusion from of the Point McIntyre Participation Area in the Prudhoe Bay Unit wells on adjacent lands which are part of the unit are draining any potential reserves which may be recovered from lease ADL 34623. A temporary injunction is necessary in order to preserve the status quo until the hearing of the principal action and to ensure that the rights of the plaintiffs' are not further prejudiced. A temporary injunction may be issued to prevent irreparable harm such as where other wells on adjoining lands are draining the lands in question. Simkins v. Maras, 9 07GR 182 (Illin. App. Ct., 3rd Dist., 1958). It has also been held that a temporary injunction is an appropriate remedy for a lessee out of possession. Petroleum Engineers Producing Corp. v. White, 12 0 & GR 100 (Okla. Sup. St., 1960). In the principal case, the interests of the plaintiffs have been denied and as such, they are in effect, lessee's out of possession of t'heir interests. Based on the foregoing it is respectfully requested that his court issue a temporary restraining order barring the State of Alaska, Divisio:~ of Oil and Gas and/or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002. Additionally, plaintiffs are requesting that a hearing be held and that a preliminary injunction be issued barring the State of Alaska, Division of Oil and Gas and/or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or, in the alternative, an order suspending the term of the lease until resolution of the principal action on the grounds that the said termination will prejudice the proper determination of the interests of Jack O. Hakkila and Clifford Burglin in lease ADL 34523 and will prevent any possibility of pursuing exploration and production activities with a view to extending the term of the lease and unduly complicate matters by introducing additional third party interests in the event that the lease is so~cl to another third party. Dated this ~ 'day of December, 2002 Ted Stepovich Stepovich, Kennelly & Stepovich, P.C. 626 K Street Anchorage, Alaska 99501 (oo7) ..................... Yeti/itepo ch TM ABA No. 8711113 O. IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter off .Tack O. Hakkfla and Arctic Basin Industries Plaintiffs General American Off Company of Texas et al Defendants Case No.: 3 AN-99-9114 CI KFFZDAVZT STATE OF ALASKA THIRD JUDICIAL DISTRICT TED STEPOVICH, being duly sworn upon his oath, deposes and states as follows: 1. I have just entered appearance as counsel for plaint/frs in the above- entitled matter. 2. I make this affidavit is support of plaintiffs' Motion for Temporary Restra/ning Order and Preliminary Injunction. 3. The matter having been filed pro se and the court having granted pro se plaintiffs' leave to obtain counsel, it is counsel's understand/nE that the complaint in this matter has not been served on the defendants. 4. Notwithstanding the lack of service as to the complaint, plaintiffs" i'de for a Temporary Restraining Order and Prel/minary Injunction. Counsel has had no communication w/th those parties, as to the present motion, due to the fact that there -1- has been no service on those defendants. A copy of the motion is to be served forthwith on the State of Alaska, Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission. 5. Notice is not necessary ha the present situation based upon the case law and legal precedent as set forth ha the underlying memorandum ha support of the Motion for Temporary Restraining Order and Prelim/nary Injunction. The sole purpose of the underlyhag motion ha the present case is to preserve the status quo until the present case is heard on its merits. DATED this g' of December, 2002~~' ........... /~ ~ Ted Ste~ovic~ ABA No. 8711113 SUBSCRIBED AND SWORN to before me this ~-41ay of , .oo2'. · ~t~ ~bhc for ~e State of ~a~a My Commission e~kes: '~{ ~ ~ o ~ -2- GENERAL AFFIDAVIT FORM # US-00407 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE In the Matter of: Jack O. Hakkila and Arctic Basin Industries Plaintiffs Vs. General American Oil Company Of Texas et al Defendants Case Number: 3 AN-99-9114CI GENERAL AFFIDAVIT Comes now, Jack O. Hakkila, resident of Fairbanks, Alaska, United States of America who' makes his statement and General Affidavit upon oath and affirmation of belief and personal knowledge that the following matters, facts and things set forth are true and correct to the best of his knowledge: . I represent the joint owners of 65 percent of the interest held by Clifford Burglin (Burglin) in Alaska Oil and Gas leases ADL 36422 and ADL 34623 and have commenced litigation respecting these said leases in: Jack O. Hakkila and Arctic Basin Industries v. General American Oil Company et al, Case Number 3 AN-99-9144CI (principal action) with the State of Alaska Division of Oil and Gas and the Alaska Oil and Gas Conservation Commission inter alia being named as defendants in that action. , I file this affidavit in support of a motion for a temporary injunction to be ordered barring the State of Alaska, Division of Oil and Gas and or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or in the alternative, suspending the term of the lease until the hearing of the principal action on the grounds that permitting the lease to lapse will prejudice the proper determination of the interests of myself and Burglin in lease ADL 34623, will prevent any possibility of pursuing exploration and production activities with a view to extending the term of the lease, will unduly complicate matters by introducing additional third party interests in the event that the lease is sold to a third party, and is necessary to preserve the status quo of the parties pending the hearing of the principal action. , Burglin is a life long resident and land owner in Fairbanks, Alaska and I have resided and am a landowner in Alaska on a continual basis since 1969, during which time we have both shared an ongoing involvement in the development of oil and gas in Alaska as well as an interest in the rights of individual Alaskans to particiPate and become directly involved in the development of oil and gas in our State. , Lease ADL 34623 is a ten year oil and gas lease which term commenced after the lands subject to the lease were patented in 1992 and which is scheduled to lapse by expiration of it's primary term on December 8, 2002. , Lease ADL 34623 was originally purchased in a lease sale held in Alaska on January 24, 1967, becoming effective April 1, 1967 and the original lessee was Thomas J. Miklautsch(hereinafter referred to as Miklautsch) who later transferred a 20% interest in ADL 34623 to Burglin on September 27, 1968. A copy of the assignment from Miklautsch to Burglin is attached and is marked as exhibit 1-A to my affidavit. , On December 3, 1968, Miklautsch and Burglin entered into a Joint Venture Agreement with General American Oil .Company of Texas (GAOC.) whereby 50% of the interests of Miklautsch and Burglin in leases ADL 34622 and ADL 34623 were assigned to the joint venture in exchange for shares of stock in GAOC and a production payment with Miklautsch to retain a 40% interest and Burglin to retain a 10% interest. . Pursuant to the terms of the Joint Venture Agreement, the interests of Miklautsch and Burglin' were to be held by GAOC which was permitted to register a 100% interest in lease ADL 34623 and hold the interests of Burglin and Miklautsch in trust with their interests to be re-assigned to Burglin and Miklautsch upon termination of the joint venture agreement. Attached and marked as exhibits 2-A and 2-B to my affidavit are copies of the joint venture agreement and subsequent transfers to GAOC. , On September 21, 1969 GAOC assigned its entire interest, including the portion held in trust for Burglin and Miklausch in ADL 34623 to Humble Oil and Refining Company (Humble) which subsequently assigned 50% of its interest equivalent to Arco Alaska Inc. (Arco). . The joint venture was eventually terminated on June 11, 1975 by letter from Burglin and Miklautsch to Exxon Company U.S.A. (Exxon), the successor company to Humble and which termination was made in accordance with 'the terms of the Joint Venture Agreement that permitted the termination of the Agreement by either party on thirty days notice. Attached and marked as exhibits ;~-A to my affidavit is a copy of the termination letter sent to Exxon. 10. Subsequent to the termination of the Joint Venture Agreement, Exxon failed to re- transfer the interests of Miklautsch, which was a 40% working interest and Burglin, which was a 10% working interest, back to them. 11. After the termination of the Joint Venture Agreement, the State of Alaska Division of Oil and Gas refused to register or acknowledge the interests of Miklautsch and Burglin, the original lessees, despite their efforts to do so and despite having received documented proof of their interests and disregarding the fact that Arco previously recognised that Burglin and Miklautsch had an interest and filed an assignment on behalf of Burglin which was rejected by the State of Alaska Division of Oil and. Gas. Attached and marked as exhibits 4-A to my affidavit is a copy of the assignment submitted by Arco. 12. Later in an attempt to break the impasse and to exercise their rights respecting lease ADL 34623, Miklautsch and Burglin attempted to sell their interests to Gulf Oil Company (Gulf) in 1975 with the result that litigation was commenced involving Miklautsch and Burglin and Exxon, Arco and Gulf. 13. The litigation involving Gulf, Exxon and Arco and Miklautsch and Burglin was eventually settled through the parties entering into two separate settlement agreements, the Gulf- MBH Settlement Agreement dated April 11, 1977 which explicitly recognised that the interests of Miklautsch and Burglin were held in trust by Gulf, and the Exxon Settlement Agreement dated April 29, 1977 the provisions of which were made subject to the Gulf-MBH Settlement Agreement. 14. Section 2(a) of the Gulf-MBH settlement agreement, explicitly recognises the interests of Burglin which were held in trust by .Gulf and which at the time were described after payout as; "The 40% working interest referred to ...in the Exxon Settlement Agreement is beneficially owned 80% by Gulf, 14.4% by Miklautsch, 3.6% by Bur~lin and 2% by Hamel..." (emphasis added). Attached and marked as exhibit 5-A is a copy of the Gulf MBH Settlement Agreement. 15. The PNG interests in lease ADL 34623 could be substantial as it has been estimated by Peter Huddleston, an independent consultant, that up to 28% of the Point Mclntyre oil field lies under leases ADL 34622 and ADL 34623 and it is projected that reserves held by the lease total a portion of 8,400,000 barrels of oil and natural gas with a potential net profit value in the range of $84,000,000.00 and as of February, 202, the field had produced 337,000,000 million barrels of oil. 16. Meetings were commenced by the Alaska Oil and Gas Conservation Commission in October, 1993 in order to determine the leases and rights to be included in the Point Mclntyre Participating Area of the Prudhoe Bay Unit and I attended a scheduled meeting of the Commission on behalf of Burglin on October 13, 1993 17. The meeting of October 13, 1993 was to commence at 9:00 a.m. but was cancelled after various parties casually met and conferred with the Commission members around the water cooler in an interior hallway without an invitation for the interested parties to participate and which action prevented me from presenting evidence to the Commission respecting the ownership interests of Burglin et al in lease ADL 34623 and the Commission's consideration for the inclusion of lease ADL 34623 in the Point Mclntyre Participation Area of the Prudhoe Bay Unit. 18. After being treated so unfairly by the Alaska Oil and Gas Conservation Commission in being denied any right to be heard, it became my opinion, and it appeared to me, that the Commission had already decided to exclude lease 34623 from the Point Mclntyre Participation Area of the Prudhoe Bay Unit. 19. The Alaska Oil and Gas Conservation Commission decided to exclude lease ADL 34623 from the operation of the Point Mclntyre Participation Area of the Prudhoe Bay Unit without giving the interested parties the opportunity to make any reasonable representation to the Commission, presumably because of the dispute as to the title ir~terests in the lease with the result that no oil and gas exploration activities were carried out With respect to lease ADL 34623 and to the substantial detriment of Burglin and eventually myself. 20. Problems with the title to lease ADL 34623 and the failure of the State of Alaska to recognise the interests of Miklautsch and Burglin have frustrated attempts made by Burglin and myself to enter into agreements with parties so that exploration activities on the lease could commence and with the goal to produce oil on the lease with the result that the lease would not be terminated and would be held by production. 21. On November 1, 2002 I forwarded a letter addressed to William H. Colbert, Assistant General Counsel of BP Exploration (Alaska) Inc. in which I requested the voluntary unitization of lease ADL 34623 in an effort to pursue exploration and production potential on lease ADL 34623. Attached and marked as exhibit 6-A is a copy of the letter received from William Colbert dated November 1, 2002. 22. In his response, William Colbert stated BP Exploration (Alaska) Inc. would not support the efforts of myself or Burglin to unitize lease 34623 based on his assertion that we did not have an ownership interest and therefore could not petition for unit expansion. 23. There were numerous instances of breaches of contract which operated to the detriment of the interests of Burglin which breaches will be outlined and proven at the trial of the principal action and which breaches involved a refusal to return legal and beneficial interests to Burglin and a failure to meet the obligations of a fiduciary by GAOC, Humble, Gulf and Exxon. 24. It is my belief that the GAOC/Burglin/Miklautsch joint venture agreement entered into in 196.8 created a trust in favor of Burglin and Miklautsch and their respective 10% and 40% interests which interests were eventually transferred to Gulf and which were explicitly recognised in the Gulf-MBH Settlement Agreement. 25. When the joint venture was terminated Humble, which had later acquired the interests of GAOC, failed to transfer their 50% interests back to Miklautsch and Burglin to their extreme prejudice as they were not thereafter recognized with the State of Alaska as holders of any interest in lease 34623 and which frustrated attempts by Burglin to commence exploration and production activities on the said lease. 26. It is my belief that if lease ADL 34623 is terminated by the State of Alaska, or is permitted to lapse, any attempts to have the rights of Burglin or myself to be recognized would be frustrated and if new parties are eventually permitted to purchase the lease, that further attempts to recognise the interests of Burglin and myself could be frustrated. 27. That I make this affidavit in support of a motion for a temporary injunction to be ordered barring the State of Alaska, Division of Oil and Gas and or the Alaska Oil and Gas Conservation Commission from terminating lease number ADL 34623 on or after December 8, 2002 or in the alternative, suspending the term of the lease until the hearing of the principal action. Sworn I~fore me on this~ ) day of December, 2002.' ) (JACK O. HAKILI~a, i' / ,,. ,, - .-'.-. ;;..; b .:.-': ~,~ :. g ~: ~, ...~ ;.-.', ~'.,- ,~ ~ E .-: ~ cz ..,,%; :: ~ = ~ : ----: ' ,-..-.'~ -c ,~ - ,,, . .q .-. .. ,. .','. .... 0, ,,, _., ,.., I.-' : .~-~. ct- ,-,° ~" ,," ,',l,.. t.--'i ~'"~ ~' ,,r~ ~.': .... ,"-. ,.,,:.;'~: .... oo o o , ~.....I = ~'~';'-: ° " : '""'" ......... "' t- ~, -~- a ,-- -.. ~ ~.'.-,'q .., :; -.-----.~,. -.-..- ... .... ..- ,-.~,~,-'- ..,,ol ~, 0 '~ t~ 1~ '','~ - ' ~ '" ~ tl° -'J' P' '~ 0 ] -.~ · ..-: ,.:: ~.1 n 0 ._-' m ';'~,'*.~..,, .: ..:"' ,'" ~ < X ~ I'" I ~ ;.~ ¢ n :~ I ~...~.~ .......... c,:) ~ · ,, ,., I-..11-.-~ -- , ',', ~: g ~ .l,,,,~ ....... .l..,____-. ....... ,-. "- ~ ," ,', ,,, : ' :-- ' I'-'1 · ' -'-~ .',- ~ > .-,- :-? --. ,,, ,-- ,--o . /1~ ' ,-'- o ,,~1 c-:- ,. -, 'J~J ' ' ; ~3" ' [' '~- ~ ~ ~-4 'L~ ~' = 4 ~' ' ~ , "0~ 'L'' '1-" ['-' 1--- l--" ....... .{:3. .0"1°1. .' , ~.~, "- g" g ~. ~> '.' z : .,- ,-..'...,.--x: ,, ~ '~' .=' '"' '"' " " o ,, . g \ _ g ! tx, '-'- ~. L\X !~;.. ;.-'~X.g '~.. · -,, ,., t o 0 D '-'--':": ;~. .-,,~ ...,, / :,.~;~ .w-. ~:' i~x-' ':1~ ~"'" '"' "'- · . 5~ · ..~ ,~ - , : '- .-- ~ -,, ~ o '~ ~ ~'1 PI' . Id.. ' " '~ " ' ' "-' .~ . I~ - -.a--..~ ,.,° ~.i ~. o.= ~ = ~' "" i iP- -.c : '3 o ,, · I0 ,... n =. ~" ~ ' ........... · ~ '~ .. x ~ .. ' F-. o , g .. ~ ~ · ,,I : ° "' ,'- '= . ~, ~.. -... ,-- - = oo ,.. r,:l '"" ~ - - · ~ ra .~ '' ' :' ' ' .~ ~'." ".{ "' "-"" a .... "":' - -i :" :."~-" ~, .... ' '.:. ' , ('3,.,.' ., ,.. }-,~ ~ t ~,~.. ~L'%, I, . ""' '" ' ''o " ,-'~,' - ~ ,,, li~~' c:~ ' '! ," ~ I~ .m_ ~ I .- -.' .' '-,' <--I ¢- ~ : .... .o , ~t :-,tx _x .' o --,.,. !~ ~f'F~ '" o . ~o~ ~'t~ O ~ I ~ %1'~ ~ ~ .2.. ~'L~,'I_% = · I i...... I .' '.% Applienrt()n Esr Apl)rov,&l sE Assignment · The undersigned esslllnee hereby request, nl,provfll sE the above assignment an tO all of the land~ described in item 1 of the obeys assistant or ouch portion thereof ns my be approved under aPp!tcab~a'- ' ~a~' and regulations.. Enclosed ~tch this appl~cattou are: . (a) Check or money order payable to ti~e Departmen~ o~ Revenue sE the State of Alaska cove~lng ~tl~n~ fee of ~20.00; ':' ~ 't.' (b) Information nnd doc~nenCs, or reEerencen thereto~ evidencing the quali~cattonn o~ the undersigned to hold n leases tn eomp~lnnen w~th Section 510.3~(e) o~ ~he O~1 nnd Onn Lenn~n8 Regula~ona~ and . (e) Any bond or reEe~enee thereto requtred by "... ~- ... Any no~ce tn connection ~tth th~n npplte~ton or the undern~gnnd~a the forego~n~ assig~ent may be sent ~o the undersLgnedSs add,ess se~ forth tn oald~a0n~s~e~." - '.' _ The undersigned agrees to be bound by the prov~onn of said lease~ .~ the above assistant lo approved La ~hole or In part. : '. , . This applica~ton d~scloaen and in s~8ned by or on behalf sE all .par~ien who viii or ~y~ ~f the above .. ~ . ~ .'~ .assistant lo approved In whole or In part, receive any tnCe~eot tn ~he lease designated aboveby v~ue of a~y a~reement or understanding, oral or ~r~C~en and constitutes certification that each such pa~ty ta quall~ to ~old ~laoh Sta~e O~l and Gn~ Leases pursuant to Section 503.~ of the OIL and ~s L~'~s~n8 ResulsLtons. . · % x .. .. Approval set forth below. Effective date of aeslsnment '. The above assigmnant is approved aa to the lands described in item 2 thereof) effective as of the dace -. . · . · . STATI~ OF ALASKA -. · .. · ny. (:h,t,Mtt in CriplicaCa. Nus~ I)o flied within 90 days after final execution by Cite assignee. All copies must be signed in ink,)' · o , o, " i · .. · .' -j .- .. . ',.%. ..' .~ .' :. ,, -~. .~ · .~ · , ..-,.: ,.~ .! '-;. '.. ~'. · : ':; ~'<.-:., ~:' ~: - .. · . '3 t. ,. , ~J~s Js To cllmfy ~ lbo JofEgeb~ # o ~dl, uw o6d Eomm ~ TH)j~ IS EXHJBIT"Z/~" 6 812 0 3-A. 13 (' ~i...,,~ .~¢,.:..:r;r:'.C.,:',,~,~,L~ reft.rred to in the AfSdavit · : ,i4 o, Sworn before me this. J o z N · N · W I T N E S S E T H: WHEREAS, the parties hereto are the owners (in the proportions of 50% by General American, 40% by Miklautsch and 10% by Burglin) of the oil and gas leases covering lands situated in the state of Alaska that are described in Exhibit A attached hereto and made a part hereof (hereinafter called the "leases"), and such parties desire to create this joint venture (hereinafter called the "Venture") for the ownership, development and operation of the leases; NOW THEREFORE, in consideration of the mutual covenants and agreements herein contained, the parties hereto agree as follows: 1. The members of the Venture shall be general American, Miklautsch and Burglin and their interests therein shall be as hereinafter set forth. Each of suchmembers hereby assigns to the parties hereto as members of the Venture its or his respective interest in the leases as above set forth; provided, however, there is excepted from the assignments hereby made by Miklautsch and Burglin and reserved Unto each of them, as separate production payments (hereinafter called the "Production Payments"), an undivided 50% of all oil, gas and other hydrocarbons in and that may be produced, saved and sold from the lands covered by the leases that accrue to the respective undivided interests in the leases hereby assigned to the Venture by Miklautsch and Burglin, until, from the proceeds of the sale of the oil, gas and other hydrocarbons accruing to such unreserved interests, Miklautsch shall have received the sum of $3,200,000.00 and Burglin shall have received the sum of $800,000.00, each free and clear of all cost · and expense of whatsoever nature (except costs of transporting the oil, gas and other hydrocarbons accruing to the Production Payments from the wells to such sale delivery point as is reasonably required in the marketing thereof, and except production, severance, occupation.and other similar taxes charged against or measured by the production accruing to the Production Payments). Miklautsch and Burglin shall look solely to the oil, gas and other hydrocarbons accruing to the interests herein respectively reserved by them for the s~ ~sfaction and discharge ( the Production Payments. For convenience, record title to the entire working interest in the leases, subject to the Production Payments, shall be transferred to and held in the name of General American without disclosure of the existence of the Venture. Subject to the further provisions of this agreement, the parties hereto shall own and hold the following interests in the Venture: General American 75% Miklautsch 20 % Burglin 5% 2. For purposes of this agreement, "net venture income" shall be all income received by the Venture from any source whatsoever, less any portion thereof attributable to royalties reserved in the leases and to the Production Payments, and the "payout" shall be the point in time at which net venture income equals the aggregate of (a) the sum of Two Million Dollars, (b) all sums accruing to the Production Payments, (c) all costs, charges and expenses of whatsoever nature incurred by the Venture prior to the payout in connection with the ownership, development, operation and maintenance of the leases, determined in accordance with the Accounting Procedure attached hereto as Exhibit B and (d) interest at the rate of 6% per annum on the unliquidated balances of items (a) through (c) above, computed monthly and compounded annually. In determining the payout, net venture income shall first be applied to interest as above provided and then to the unliquidated balances of items (a) through (c) above. 3. Until payout, .all costs, charges and expenses incurred by the Venture in connection with the ownership, development, operation and. maintenance of the leases shall be borne and contributed to the Venture by General American. After payout, all such costs, charges and expenses shall be borne and contributed by the parties hereto in the proportions of 75% by General American, 20% by Miklautsch and 5% by Burglin. 4. Until payout General American shalI be credited with and be entitled to receive all net venture income and after payout, the parties hereto shall be' credited with and entitled to receive net venture income in the proportions of 75% by General American, 20% by Miklautsch and 5% by Burglin. 5. For a~' income tax purposes, inc{' ding the federal income tax, all income and all income tax deductions and credits are allocated to General American until payout and after payout all income and all income tax deductions and credits are allocated 75% to General American, 20% to Miklautsch and 5% to Burglin. 6. General American shall be operator of the Venture and shall have full power and authority to direct, supervise, manage, control and operate the business of the Venture, and the scope of such power and authority shall extend to all things which would be done by a reasonably prudent operator in respect to the exploration, development, operation, maintenance and management of its own properties. The judgment of General American exercised in good faith shall be the limit of its liability to the other parties hereto and General American shall never be liable for any act done or omitted to be done in good faith in the performance of any of the provisions of this agreement. 7. General American shall maintain accurate books and records relating to the Venture which shall at all times reflect the ownership and affairs in connection therewith pursuant to the terms of this agreement. Such books and records shall be maintained upon the accrual basis of accounting and shall be kept at the principal office of General American in Dallas, Texas. The financial and taxable year of the Venture shall be based upon an accounting year ending on December 31 of each year. The accredited representatives of Miklautsch and Burglin may at all reasonable times inspect, audit and make copies of the books and records in connection with the Venture, and prior to the payout, General American shall furnish to 'both Miklautsch and Burglin not less often than semi-annually, a detailed statement reflecting the costs incurred by the Venture and the net venture income received during the preceding 6-month period and also reflecting the remaining amount to be recovered prior to the payout. 8. The rights and obligations of the parties hereto shall be several and not joint. No party shall ever be liable for any obligation or liability arising hereunder which then exceeds its proportionate share as set forth herein, and each party. indemnifies the others against all liabilities hereunder which are properly for the account of the former. For federal income tax purposes, the Venture shall be subject to the provisions of Subchapter K of Chapter i of the Internal Revenue Code of 1954, and General American is hereby instructed for federal income tax purposes only and for'no other purpose to file a proper partnership return each year under said Subchapter K with the appropriate District Director of Internal Revenue. 9. Genera ~merican shall initially p ~ on behalf of the Venture all costs, expenses and charges incurred by the Venture and, after payout, shall charge Miklautsch and Burglin with their proportionate shares thereof as herein provided. General American shall collect and receive the proceeds of the sale of all oil, gas and other hydrocarbons and other proceeds to which the Venture may be entitled and shall distribute the net venture income monthly in the manner set forth in paragraph 4 hereof. 10. The death of either Miklautsch or Burglin shall not terminate the existence of the Venture. If either Miklautsch or Burglin should die, the legal representative or representatives, heirs or legatees or devisees of such party, whichever is the appropriate one or ones, shall be substituted as a party to this Venture. 11. Except as herein otherwise provided, no assignment or other transfer by any of the parties hereto of his or its interest in the Venture shall be made without the written consent. of all other parties hereto. 12. Any party hereto may at any time terminate the. Venture upon thirty (30) days prior written notice to the other parties. Unless so terminated, the Venture shall continue for a period of one year from the date hereof and so long thereafter as either of the leases remains, in force and effect. Upon the termination of the Venture, General American shall assign to Miklautsch and Burglin their respective interests in the VentUre as set forth 'in paragraph 1 hereof; provided, however, if the payout has not occurred at the time of such termination, such assignment shall be made subject to the provisions of paragraphs 3 and 4 hereof, which shall continue to be applicable to the interests of the parties in the leases regardless of such termination. Upon the termination of the Venture, the parties hereto shall enter into a mutually agreeable operating agreement with respect to the leases which shall (a) designate General American as operator, (b) employ the Accounting Procedure attached hereto as Exhibit B, and (c) be effective as of the payout. In the event of a dispute between the parties in regard to the terms of such operating agreement, the disputed matter shall be determined by arbitration in the City of Dallas, Texas'in accordance with the rules of the American Arbitration Association. 13. The provisions hereof shall be binding upon and shall inure to the benefit .of the parties hereto and to their respective heirs, successors and legal representatives, and, to the extent that any assignment is permitted under the provisions of this agreement, to their respective assigns. E X E C U T E D this 3rd day of December, 1968: ATTEST: GENERAL AMERICAN OIL COMPANY OF TEXAS Donald C. Apeland Assistant Secretary By. R.M. Swesnik R. M. Swesnik, Vice-President T. J. Miklautsch T. J. MIKLAUTSCH C. Burqlin C. BURGLIN EXHIBIT A ~ Attached to and made a part of Joint Venture Agreement dated as of January 2, 1969 by and between GENERAL AMERICAN OIL COMPANY OF TEXAS, T. J. MIKLAUTSCH AND C. BURGLIN Oil and gas lease bearing Serial No. ADL 34622 made by the State of Alaska to T. Miklautsch, dated April 1, 1967, covering Tract C18-1, being the following described lands situated in Alaska: Township 12 North, Range 14 East, U. M. Section 3: Ail Section 4: All Section 9: All Section 10: All Oil and gas lease bearing Serial No. ADL 34623 made by the State of Alaska to T. Miklautsch, dated April 1, 1967, covering Tract C18-2, being the following described lands situated in Alaska: Township 12 North, Range 14 East, U. M. Section 5: Ail Section 6: All Section 7: All, except PLO 1571 Section 8: All, except PLO 1571 EXHIBIT B ( Accounting Procedure attached to and made a part of Joint Venture Agreement dated as of January 2, 1969 by and between GENERAL AMERICAN OIL COMPANY OF TEXAS ("GENERAL AMERICAN"), T. J. MIKLAUTSCH and C. BURGLIN. The costs, charges and expenses to be taken into consideration in connection with the ownership, development, operation and maintenance of the leases referred to in the agreement to which this exhibit is attached are as follows: (a) The costs of all direct labor (including fringe benefits) , transportation and other services incurred in developing, operating and maintaining the leases, and of all material, equipment and supplies purchased for use on such leases; (b) Damages or losses suffered with respect to any of the leases which are incurred by any cause not controllable by General American through the exercise of reasonabl.e diligence; (c) Expenses of litigation, liens, judgments and liquidated liabilities and claims incurred and paid by General american involving any of the leases or incident to the development, exploration, operation or maintenance thereof; (d) Ail expenses incurred and paid by General American in appearing before administrative agencies in connection with the leases and the production therefrom, including all amounts paid to outside attorneys and third parties and compensation or salaries paid to officers and. employees of General American whose time is not directly allocable to such administrative proceedings, provided, however, that these charges shall not duplicate the charges made under subparagraph (g) below; (e) All taxes (except income taxes) paid by General American for the benefit, of the parties hereto, including, but not by way of limitation, ad valorem, property, production, occupation and any other taxes assessed against the leases, the production therefrom or allocable thereto, the personal property located thereon or the operations conducted thereon,. to the extent not included in subparagraph (a) above; (f) Insurance premiums paid. by General American for insurance carried with respect to the leases or with respect to any personal property or equipment situated thereon or used in 'connection therewith, together with all expenditures incurred and paid in settlement of any and all losses, claims, damages, judgments and other expenses, including, legal services, relating to such properties; (g) ~ ~°easonable charge for ove~' .ad to cover the proportion properly allocable to the leases of compensation or salaries paid to managing officers and employees of General American whose time is not directly allocated to the leases, the office expense of General American, and of any district and camp expenses not allocated directly to the leases, such overhead charge to be in addition to any amounts chargeable under subparagraph (a) above; and (h) Ail other expenditures reasonably incurred by General American for the necessary or proper development, operation, maintenance and utilization of the leases, including all legal fees and expenses and engineering fees and expenses not included in any other item above, but excluding any interest paid by General American on any funds borrowed in connection with the development, operation, maintenance and utilization of the leases. '"'<'' ' .... ll~,,G --' I, EA~-HOo&DL34623:". ".'--,- '..':~-,~or~ D~-8 (0~)':' >J ~.~ ....~. . . ,~.. ,:,. ~'~ ~ . . ~. . : ~.:~ ...April,Jig67. ~ ~' ~Y '-' ~u~,~ ~t.:~,?~-d~ ~;~f.f" :' ~' g~lVg DAT~ 0[~' --~'. '~'-~'i"~ ,. DcJ]flrtlHCnJ.,.. of Natural Resources ' ' J J . J , . j l '" ': Division of Lands '.~' '[ '. · , ~ . . . ' ' ' I.'' The understsned sssisnor, as mmer of the record title intarelt specified Ln item 3 beim~ -': - · . ; in the oil ~nd Sas lease designated able, for a Bood and valuable consideration, d~s hereby Il '.: :.p . co _General American Olll Cotupany of Te}:as, e Delaware cor~rajl0a , ' J · . . '::.. ,boa. address i. ~dows Bulldlne..Dallas.-Texas 75206 ' . , ' "'., ~ :tha r~8ht, title and tntara~ Spac~fiad~{n ltam ~ bal~ tn and to .aid leaae ~n$ofar aa re.' c~ar~-- , ' ' .. · ~ ; the lands da$cribed in lgam I or such poreion tharaof a$ tha le.aor ~y appr~e and 'da~cE~ba ~n '- · .,: :. ~tem 2 bel~, glving and ~rantin$ to ~$.~gnae the rgght~ and privilaga$ of ~ la.~ee In eaid land~; ,"': . . : : :l I ~ O the exteng indicatedo oubJec.g ~o the rescissions of ~arridtns royalties nosed In item S and 6~ ' ;'-' ' '.':, bz~ · -~ ". · " ' ' ' .... ' i.' - ,. '~:." . ~ . ~.A- " " ". ', · ' · ' ' ....... ' "· ' ~ .... . .'.'.. ~/J*;~'" ':', ' " <' . .... ~, .'. ~..'~- ' ,,'-"-~ '~ ~.',' i~.. .... -:., · .. · . . · · , * . ' · _ ~ ' · ~ ~ . '.: · '~ ' TRAGT GIB'2 .. ' (~ ~ ~*'~x~*~ ~-) ~' , i.'"',?',-:- ' ' ..i ""..l~ec~lon ~:-.' ...... .l. All 6~0 Gc~e8 :~ "" :" '"" -`~': ...,.,:l, l.'l'l'* l. '4'..- .... · ' ~ .: '-. ."" 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'. i ~ ~-:' i ' , .. .. .. .. .... ~ ." , '.."'-'.-'= .... , · .{.~. . . ., < , J- .. ='~ ~'~.. (a) qash~ check o~ monmy otde~ payable Co Che ~pa~C~nC o! Rewnue ot 'the Scats . . .. s .- . . . · ~. - . '"i · ' ~ destSnaCed in the Ioresotns easiest may be sent Co the underwisnedte address s~C forth in said. · .'. . ., ,- ~, ~ ~, , .. .... ... . . ., .. . · .... - ,.....,.~., .. ~e underaLsned asreeo co be bo~d by the provtsions of satd leaseo-i~"'the above aaatS~-'." '' . . ~ .. . ' , . .. ~ - · . ~ ...... ;¥ ,,' , · ~ .., .. , , - -.. : ~ · '~ ''"~ ~f the above aeo'~s~nC La approved In ~ole or Ln receive' ~ '~":'.' '~ ~'.'. . ,.,.%~..: .. :sated above by v~rCue of ~y asreemenC or underscnd~ns, stax or ~CCen and cona~u~ ce~c~f~,.~.~'~'''//' · ., , ,..., ?i..:..''.~ ..... cac~on ChaC each such p~rCy ~s qualified tO hold Alaska State OLd. a~d Gas Led~a pursuant Co- . .., : .' ..~ ). - , , _ . ' :' '/],:~ Section 503, L of ~he OL~ ~d Oas Leao~n8 Resu~aCLono, ' ' :-' .:-~.~.,,~:~.'. h.'. ' ' ., ' ' '= ' .... ' ':"':-"' " ~ ....... ..: . ..:.. · ..._ ; ~ I .. · ... · . t '-. . ., , . t- . · .; t · . , .. · .:. '.~ , ,~ * .,,. , · -' ' · . . .: . · : . ~.. . .. -.. Sna~ure) '- · .... ~,~.; ~ ',. · - i - .- ::.. ;-. : ~e foreso!nS aanll~en~ 'to approved an co the lands deocFibed In t~ I chereof,- · ,'.~, '.' effective as of the dsce sec fo~ch . .. i. ' " .. , . · . ',.. " ~.~ ,.. ' , . ,' . · ; . , ..... ~ -.~: ' : '".' ' ':r t . L . ' · . · :;' ' -.,. t , ' ' ' ' .. , . - ..... , :;:~ ' '. . .... ~11~ //. . ~. ___ ~ ~ ~ ~"~ /.' '.... ' '..-'~. .: '.'. , .. ":~ ', . · . · ' ~ ' ' - t ' "~... ' '~". .; '' - ]' . '.'-4/6~ · , ~'~ ~ ~~_ · · .. '- '-'- ' , :i. : .' ', · : . · - ".,~ .'..-.. '' ' .: ' ~ ;.i .'..- ~.~:' -.' .-i .... . .~.,' · , . - . , - . ~, , :. '..., ... .' . - . .. . . : - . : ~ . . · . , . . · . . .: .,.'~, s · ,....,, ~ , . · .~. .t-'.' .. , .. u , .. · .: ,..-..=~.-. :.:~ . · ~-..,.. .. ./~,-~-., ~.'~,.::;., -~ - .-~ .' I,,.." · .' 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' ... ~;. :,,..,.::-.. :. '.' .o . United States of America ) State of Alaska ) aw · . .... '['HIS IS TO CERTIFY that the foregoing Iii a full. true and oorrelx copy of the original as the aaree appeam in lite record, and filee et ~,~ ,'.~l~'~CO. I~' "~. WITNESS WHEREOF,, Ih ave ~ eat r41y Italy, ~ have ~,~e~ ~-~. ~ia~ ~ ~~ ~ ~ I ~ ..... .THIS IS EXHIBIT"..,~" r_efll.rred to in the AJfitlavit of - Sworn be~re me this ~ _~. //~~ -, . ~~AS, u~de~ da:e o~ Decembe~ 3, 1968, Ge~e~aZ ~erica~ .. _ . _ -. OiZ Company o~ Texas e~:e~ed i~o "Joint Venture Agreement" with T. J. Miklautsch and C. Burglin of Fairbanks, Alaska, a copy of which agreement is attached hereto; and WHEREAS, said Joint Venture Agreement pertains to the following two State of Alaska oil and gas leases: Lease ADL-34622 which covers the following described tract of land in Alaska: T. 12 N., R. 14 E., U.M. Sections: 3, 4, 9, 10; and Lease ADL-34623 which covers the following described tract of land in Alaska: T. 12 N., R. 14 E., U.M. Sec. 5: Ail 640 ac. Sec. 6: Ail 577 ac. Sec. 7: Ail, excl. PLO 1571 430 ac. Sec. 8: Ail, excl. PLO 1571 580 ac.; WHEREAS, Exxon Corporation succeeded to the interests of General American Oil Company of Texas; and WHEREAS, by instrument dated March 13, 1970, Exxon Corporation assigned to Atlantic Richfield Company (hereinafter sometimes called "Atlantic") one-half of Exxon Corporation's interest in and to State of Alaska Lease ADL-34623, subject to the terms and provisions of said Joint Venture Agreement; and WHEREAS, by letter dated June 11, 1975 (but received by Atlantic at a later date), T. J. Miklautsch and C. Burglin gave written notice of the termination of said Joint Venture Agreement in accordance with paragraph 12 thereof; NOW, THEREFORE, to the extent,, and only to the extent, that ., · Atlantic may be obligated to do so by virtue of Atlantic's aforesaid interest in ADL-34623 and in accordance with said paragraph 12 of June 11, 1975 ........... .......... Exxon Company U.S.A~ Box 2180 Houston, Texas PoSl O/rice [tox 1 Falfbank% /~laska 99707 · ~rea Code 007 452.5503 - 452-5511 - 452-55?4 · Re: State of Alaska Oil and Gas Leases ADL 34022, 34623 Dear Sirs: We have recently concluded a trade with'Gulf Oil Corporation to sell to Gulf our undivided one-half interest in State of Alaska Oil and Gas Leases, Numbers ADL 3~622 aud ADL 31623. As you know, these interests are presently subject to klte Join~ venture agreement of December 3, 1968, between us and 'General American Oi~ Company of Texas, whose interest was .. subsequently assign.ed to you. through your piedecessor in title, llumble Oil and Refining Co~pany, by instrument dated as of September 21, 1969. In accordance with paragraph 12 of the Joint Venture Agreement, you are notified that such agreement is cancelled on the 30th day following your receipt of this written notice; and request is made, ~nder. such paragraph, that you, as successor in interest to General American, assign to us our 50% ~n~erest in the venture as set forth therein. -. . Gulf is aware of your position under these Iease~ and of our ~ntention to terminate the present JOint Venture Agreement as herein provided. You may be hearing from them shortly~in view of their future Joint participation with you'in these. properties-. Very t'~uly yours, l~mas J. Hiklautsch, and TJM:CB:iI cc: Gulf O11 Co. -' Atln.tic Richr. teld Ge. eral American Oil Co. '. · , · · · EXl{I I~ I T "l~" said Joint Venture Agreement, Atlantic Richfield Company hereby assigns to T. J. Miklautsch and C. Burglin their respective interests in the Venture as set forth in paragraph 1 of the Joint Venture Agreement; subject, however, to the provisions of paragraphs 3 and 4 thereof which shall continue to be applicable to the interests of the parties in the leases regardless of the termin- ation of the Joint Venture Agreement. IN WITNESS WHEREOF, this agreement has been duly executed this ~ day of July, 1975. ATLANTIC RICHFIELD COMPANY By ~act STATE OF ALASKA ) ) THIRD JUDICIAL DISTRICT ) The f~egoing instrument was acknowledged before me this ~jz~ day of ~ , 1975, by O. G. Simpson, Attorney in Fact for Atlantic ~fiel~/Company. ... My Co~ssion expires: 8/3/78 ~enotes ~e~ Passages ( Ii' 770411-A. 26 Gulf-MBH Settlement Agreement This Agreement, Conveyance and Acknowledgment is executed as of the 11th day of April 1977, by and between GULF OIL CORPORATION, a Pennsylvania corporation (''Gulf'') as Buyer, and T. J. MIKLAUTSCH of Fairbanks, Alaska ("Miklautsch"), CLIFF BURGLIN of Fairbanks, Alaska ("Burglin"), and CHARLES HAMEL of Watertown, Connecticut ("Hamel") as Sellers, with Miklautsch, Burglin and Hamel being for convenience herein sometimes referred to as "MBH." WHEREAS, immediately prior to May 16, 1975, MBH jointly with Exxon Corporation. ("Exxon") were members of a Joint Venture (the ''Venture'') which owned interests in Alaskan Competitive oil and Gas Leases Nos. ADL 34622 and ADL 34623 (the ''Leases''); WHEREAS, in addition to such Venture interest'MBH owned a $4,000,000 production payment payable out of a portion of the gross proceeds from the Leases (the "$4 MPP") and asserted certain claims against Exxon, et al. in respect of the Leases; WHEREAS, by Letter Agreement dated May 16, 1975 ("May Agreement"), MBH agreed to sell their entire interest in.the Leases to Gulf on certain terms and conditions; WHEREAS, because of disputes with Exxon, et al. which resulted in the filing of multiple lawsuits and other problems, the transaction contemplated by the May Agreement was not consummated, although Gulf did pay $7-1/2 million as part performance of Gulf's obligations thereunder, and MBH, after attempting to terminate the Venture Pursuant to its terms, Purported to assign to Gulf an undivided one-half' interest in the Leases by instrument dated July 14,1975 (the "1975 Assignment''). WHEREAS, Gulf and MBH have now reached a settlement with Exxon, et al. (the ''Exxon Settlement Agreement", a copy of which is attached hereto as Exhibit A) and,desire to consummate their agreement with each other on the fgllowing basis: 1. Gulf agrees that MBH may keep the Seven Million Five Hundred Thousand Dollars ($7,500,000) paid to them in 1975 and concurrently herewith, shall' pay to MBH, Lan additional sum of Seven Million Five Hundred Thousand Dollars (~?~00,000). , M~H hereby conveys to Gulf all of ~H's right, title and interest in aJ~d to the Venture, the Leases and all claims against Exxon, et al. relating to the Leases, in trust, however, for Gulf and M~H as their interest appear below: (a) (b) The 40% working interest referred to in Subsection (4)(c) of Section Z of the Exxon Settlement Agreement is beneficially owned 80% by Gulf, 14.4%, by Miklautsch, 3.6% by Burglin and 2% by Harnell and each of them agrees to contribute all of his or its interest, in said working interest to a limited partnership (the ' Partnership ) to be organized under a form of agreement attached hereto as Exhibit B ( the "Partnership Agreement ~), and executed concurrently herewith. The $7-1/2 million production payment referred to in Subsection (4)(a) of Section I of the Settlement Agreement is beneficially owned 50% by Gulf, 36% by Miklautsch, 9% by Burglin and 5% by Hamel. Immediately upon receipt of an assignment of the legal title to the Pt. McIntyre Preliminary Legal Package Documents Exhibits Page (~ I' 770411-A. 26 Gulf-MBH Settlement Agreement · $7-1/2 million production payment, Gulf shall reassiFa an undivided 50% interest in and to such legal title to ~BH in the pro/~ortions show~ above in full rem/trance of its trust obligation to do so. (c) Ail rights and privileges in connection with the drilling of a special exploratory .well (the 'Special Well') which may be drilled under Subsection 7 of Section I of the Ex:con Settlement Agreement are (including all rights of information in connection therewith) owned by Gulf. However, at such time as ~ulf has recovered the 500% of its costs out of production from said well as provided for in the Exxon Settlement Agreement, the Partnership shall have the same interest in such well as it has in said working interest in the remainder of the properties covered by, the Partnership Agreement. (d) The oil and gas operating rights surrounding the "Hamilton 'Well' are owned and shall be operated as partnership property the same .as though said rights were never segregated from said Lease ADL 34623. The 'Hamilton Well' referred to herein oovers a farmout of oil and gas operating rights dated March 12, 1969, a Quitclaim and reassignment of which is being made to Exxon, et al. under Section II of the Exxon Settlement Agreement, the same well to be subsequently included in an assignment to Gulf under Subsection 8 of Section I of the Exxon Settlement Agreement. (e) The Partnership shall assume and bear the full burdens attached to the GAO net profits interest referred to in Section II of the Exxon Settlement Agreement. (f) M~H, to .the exclusion of Gulf or the Partnership, shall be the owners of the net.profits interest in State of Alaska Leases ADL 47464, 47645, 47646 and 4746'7 which is to be assigned to them pursuant to Subsection 3 of Section IV of the Exxon Settlement 'Agreement. When assigned, the .said net profits interest shall be owned 72% by Miklautsch, 18% by Burglin and 10% by Hamel. When, if and as Gulf acquires any interest in .Block 1. T-12-N, R-4-E., U.M. or Block's 7, 8 or 9, T-13-N, R-14-E., U.M., State of Alaska (the "Subject Lands"), Gulf agrees to convey to MBH an overriding royalty equal to two and one-half per cent (2-1/2%) of the Market Value of the Petroleum Products attributable to the interest so acquired by Gulf (exclusive of lessor's royalty) which are produced from, and sold or used off, any.of the leases covering such lands. For purposes hereof, the terms "Market Value" and "Petroleum Products" have the meanings assigned to them in the. Partnership Agreement. If Gulf acquires an interest in any of the Subject Lands and within 180 days thereafter conveys 'a undivided fractional interest in a lease to a third party solely for Gulf's costs of acquisition, the interest so acquired by the third party shall not be considered to have been acquired by Gulf. If Gulf acquires an interest in any of the Subject Lands and within 180 days thereafter conveys an undivided fractional interest in a lease in exchange for an interest in a lease covering other lands (regardless of whether any adjustment is paid or received in cash to reflect the difference in cost of acquisition of each such interest), the interest so conveyed by Gulf shall not be subject to the above overriding royalty, but the interest so acquired by Gulf shall be subject to a like overriding royalty. If Gulf's interest is pooled or unitized with other interests, said overriding royalty shall be calculated on the basis of Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 302 ' '(. 770411-A. 26 Gulf-MBH Settlement Agreement Gulf's share of the combined interests. In all other cases, any transfer of an interest in which MBH has an overriding royalty shall be made subject to such overriding royalty. If Gulf acquires or contracts to acquire an interest in a lease from a co-owner other than by purchase, no overriding royalty shall' be granted with respect to such interest. 4 · All other agreements heretofore entered into between the parties to this MBH Settlement Agreement or other claims asserted by one party against the other are hereby terminated. EXECUTED on the dates set forth below, but to be effective as of the day and year first set forth above. Date: 4-29-77 By GULF OIL CORPORATION Joseph O. Carter Attorney in Fact Date: 4/11/77 T. J. Mikla~%sch T. J. Miklautsch Date: 4/11/77 C- Burqlin Cliff Burglin Date: 4-11-77 Charles Mamel Charles Hamel THE STATE OF Texas ) COUNTY OF Harris ) BEFORE ME, the undersigned authority, on this day personally appeared T. J. Miklautsch, known to me to be the person Whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and'consideration therein expressed. 1977. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llSh day of . April . Barbara P. Browne Notary Public in and for , Barbara P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 THE STATE OF Texas ) COUNTY OF Harri. s } Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 303 Gulf-MBH Settlement Agreement. BEFORE ME, the undersigned authority, on this day personally appeared Cliff Burglin, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed. 1977. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llth day of ~ Barbara P. BrQwne Notary Public in and for Barbara P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 THE 'STATE OF Texas ) COUNTY OF Harris ) BEFORE ME, the undersigned authority, on this day personally appeared Charles Hamel, known to me to be the person whose name is subscribed to the foregoing instrument, and acknowledged to me that he executed the same for the purposes and consideration therein expressed. 1977. GIVEN UNDER MY HAND AND SEAL OF OFFICE this the llth day of A~ Barba~ P. Browne Notary Public in and for , Barbara.P. Browne Notary Public in and for Harris County, Texas My Commission Expires March 15, 1978 Pt. McIntyre Preliminary Legal Package Documents Exhibits Page 304 11/11.."2002 10:35 FA~ 907 $$,4 4031 bp William H. Colbert AS$iSl:a~t I~ chsr~l ~P LEGAL-ALASKA 0O2 BP Exploration (Alaska) Inc. SOO E. Babson Blvd. Anchorsls, AK P.O. BoK 195612 Anchorlgl. AK ~519-8512 Switchboard: [g07) 561 -$111 FaCsimile: [907) 58A-4~31 Via Facsimile (907).452-520_3 November 1,2002 Mr. Jack O. Hakkila C/o C. 8urglin P.O. Box 131 Fairbanks, AK 99707 Reference: ADL 34623 Dear Mr. Hakkila: .1 _r~/,~r??.'t°~the Affidavit of -. ~worn b8 , I have received the letter dated October 29, 2002, that you addressed to R.L. Skillern concerning unitization of ADL 34623. Ail future correspondence and contact with BP should' be directed to me at the address above, and not to Ms. Crandall, Mr. Skillern or other BP employees. You have not provided any information that establishes your atleged ownership interest in ADL 34623. Without an ownership interest, you have no standing to petition for unit expansion. BP will not support your efforts to unitize a lease in which you have no ownership interest. Regards, cc: Brian T, McLaughlin, counsel to O. Hakkila Kerr & Ward, L.L.P. P.O. Box 2858 Midland, TX 79702 Krissell Crandal[, BP R.L. Skillern, BP Jim Ruud, ConocoPhillips John Gallogl¥, ExxonMobil Camille Oeschli Taylor, AOGCC Commissioner ii IN THE MATTER OF: THIRD JUDICIAL DISTRICT AT ANCHORAGE JACK O. HAKKILA and ARCTIC BASIN INDUSTRIES Plaintiff, vs. GENERAL AMERICAN OIL CO, OF TEXAS et,al. Defendants. ) ) ) ) ) ) ) ) ) ) ) ) ) Case No. 3AN-99-9114 CI. CERTIFICATE OF SERVICE I, Tina M. Harris, being employed with the law office of STEPOVICH, KENNELLY & STEPOVICH, P.C., hereby certify that a true and exact copy of MOTION FOR TEMPORARY RESTRAINING AND FOR PRELIMINARY INJUNCTION, MEMO WITH EXHIBITS has been sent via Courier to: State Of Alaska Alaska Oil And Gas Conservation Commission 333 West 7tn Ave, Suite 100 Anchorage, Alaska 99501 State of Alaska Oil And Gas Division 550 W 7tn Ave Directors Office, Suite 800 Anchorage, Alaska 995401 DATED this 3rd day of December, 2002. RECEIVED DEC 0 3 2_002' asia Oil.& Gas Cons. Commission Anchorage STEPOVICH, KENNELLY & STEPOVICH, P.C. 626 K Street Anchorage, Alaska 99501 Ph: (907) 279-9352 IN THE SUPERIOR COURT FOR THE STATE OF ALASKA AT ANCHORAGE d In the Matter of: Jack O. H;~l~ila and Arctic Basin Industries Plaintiffs ) ORDER rs, ) ) General American Oil Company) of Texas et al ) ) Defendants ) Case No,: 3 AN-99-9114 cI After consideration it is hereby Ordered: 1. That the term of lease ADL 34623 be suspended effective December_, 2002 and not be permitted to lapse except by Order of this Court; and 2. That the 'State of Alaska, DivisiOn of Oil and Gas and the Alaska Oil and Gas Conservation Commission are from enjoined terminating lease number ADL 34623 on or after December 8, 2002. .AND THE GROUNDS FOR THIS ORDER ARE THAT: 1. Permitting the lease to lapse will prejudice the proper determination of the interests of th'e Plaintiffs in lease ADL 34623 and prevent any possibility of pursuing exploration and production activities if additional third by interests are introduced by m-selling the interests in lease.34623. 2. That it is hecessary to preserve the status quo of the parties pending the hearing of the principal action. Dated this of December, 2002. Superior Court Judge ALASKA OIL AND GAS CONSERVATION COMMISSION September 30, 1992 ARCO Alaska Inc. POBox 100360 Anchorage, AK 99510-0360 Attn.: James R. Winegarner Senior Landman Re: Final Location Clearance, Various Gwyder Bay Unit and Hemi Springs Unit Wells WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Dear Mr Winegarner: In response to your September 24, 1992 letter, we have reviewed the well files which contained recommendations for Final Location Clearance. The wells are: Well Name and No. ADL No. PTD NO. Operator Pt Storkersen #1 34623 69-0033 Gwydyr Bay'State A #1 47465 73-0028 Gwydyr Bay State #1 47467 79-0039 Gwydyr Bay State Unit #1 47444 79-0068 GBU Kup Delta #1 & 47469 87-0001 iA " 87-0016 Rock Flour #1 28250 90-0177 Hamilton Brothers Cities Service Conoco Inc. Mobil Oil Corp. Vaughn Petroleum ARCO Alaska Inc We found field inspection reports in all of the above files recommending final location clearance and in the Gwydyr Bay State #1 file we also found a copy of a 10/26/82 letter to Conoco approving "Final Abandonment location clean-up" of.subject well. Final Location clearance is hereby approved for the above listed wells. S' Chairman bew/df lc-992 ~ printed on recycle, ri p~l~e, b y (7. I}, ARCO Alaska, Inc. / Post Office B(',:,! ~360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 September 24, 1992 Alaska Oil and Gas Conservation Commission 3001 Porcupine Ddve Anchorage, AK 99501 Attn: Blair E. Wondzell, P.E. Senior Petroleum Engineer RE: Request for Wdtten Final Location Clearance Gentlemen: ARCO Alaska, Inc., as operator of the Gwydyr Bay Unit and Hemi Springs Unit, respectfully requests written final location clearance for the following wells, all of which have internal correspondence in the well file indicating the location has been inspected and recommended for approval by the AOGCC. Well Name Permit No. O0erator Pt. Storkersen No. 1 Gwydyr Bay State A No. 1 ~,~.. Gwydyr Bay State No. 1 Gwydyr Bay State Unit No. 1 GBU Kup Delta No. I and lA Rock Flour No. 1 69-33 73-28 79-39 79-68 87-1/16 90-177 Hamilton Brothers Cities Service Conoco Inc. Mobil Oil Corporation Vaughn Petroleum ARCO Alaska, Inc. Also, please plan to inspect the surface location of the following well during the next scheduled North Slope location inspection tour. West Storkersen No. 1 89-14 ARCO Alaska, Inc. If you have any questions, please call me at (907) 265-6914. Sincerely.. '~J, afnes R. V~arner ////Senior ~/a'.,~dman / JRW:jls b/ cc: Mike Kotowski, DNR RECEIVED S E P 2 8 19~2 Alaska 0il .& Gas Cons. CommiSsion ;A~horage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company ,r February 18, ]987 Telecopy No. (907) 276-7542 Exxon Company, U.S.A. P. O. Box 196601 Anchorage, AK 99519-6601 Re: Pt. Storkersen #1 Gentlemen: In compliance with the regulations set forth in Chapter 25 of the Alaska Administrative Code, your company has dutifully submitted to the Commission sepias of the various logs run in the subject well. Primarily due to age and to frequency of use, the sepias of the logs indicated below have deteriorated to the point that satisfactory prints can no longer be made from them. · Accordingly, in the interest of upgrading the quality of the material maintained for permanent reference in the Alaska well log library, the Commission would greatly appreciate 'receiving from you fresh sepias of the following logs: DIL 5" BHC/Sonic - GR 2" Please direct any questions you may have in fulfilling this special request to Bill Van Alen at 279-1433. Thank you .f. or your contribution toward maintaining a good State well log lzbrary. Sincerely, /' It/. W. Barnwell Commissioner jo/L.FJ.0i-02 (REV.08-73) ., ,l .~. MEMORANDUM DEPARTMENT OF NATURAL RESOURCES DMSION OF OIL AND GAS TO: Homer L. Burrell TI{RU:Hoyle H. Hamilton ~ State Or Alaska DATE: FILE NO: October 21, 1974 TELEPHONE NO: FROM: Lonnie C. Smith ... SUBJECT: Location clean-up inspection of Point Storkersen ~1, Sec. 7, T12N, R14E, U.M. Tuesday, October 15, 1974 - I departed Anchorage by commerc%al air' c~er., arrivin~-~a~'De~orse on the North Slope at approxlmatel~ 10:00 AM. I was not expected to arrive on this flight, so. I was not met at the airport. I contacted the ARCO security guard, who was driving a bus from the ARCO camp and made arrangements to ride to the ARCO pro4uction camp. Upon arr'ival at the ARCO production camp, I talked with Chuck Simons, who informed me that the Exxon supervisor, Mr. Travis H..McLain was not available at the time. but that he would be in by lunch. Mr. McLain came in abo~t 12:3~ PM and I had lunch with him. We talked over plans, to visit the Point Storkersen location right after lunch. ...... After 1un=hi accompanied Mr. McLain to his' production office which is located.outside of %he ARCO camp area.· It.is just off' of the road near the Nabor's camp .pad. Exxon has constructed a warehouse and has installed a trailer unit office with. sleeping quarters for a telephone- radio c~am~anica~/ons =enter for expediting the work of their ex- ploratorf activi'%y on the North Slope this winter. Mr. MoLain called' for..a 'helicopter and as soon as it was available it landed at the Exxon site and we boarded at 1:00 PM. ' @ R63072 ,. This well was P &' A by ~amilton Brothers .September 3, 197'0 but Exxon was S.ubseqUently designated as operator' of the lease. We flew north- west d~l:'e~,t~ to the Point S'torkersen 'location. Upon reaching .Point Storkersen location, I had the pilot circle .once and took aerial Photo %1 (attached). Th:is.shows the light snow cover on the pad and ~A'marker on the wellhead. We then lan~ed and I took a brief t~ur of the location and discussed with Mr.. M~ai.n the areas of work that he had performed, There was a slight cover'of snow bat it was not heavy eaough to completel.y Obscure the gravel. The specific 'l°cat~on of debris ha~ be.em established on my previous inspection on September 3, 1974. It was easy for 'me to locate where, additional. 'work had been performed. I circled the 1.ocation and .quick'ly checked 'o~t. the points where I had.previously observed trash, debris, an~ boards. These areas had been cleaned up. The cellar had been well f. illed. I discussed the work with Mr. McLain, who informed me that they had cmt the pipes off deeper under the gravel and had cappe~ the. rathole and mousehole at a depth under the gravel so that · · · should not again protrude. The filled'c~l%ar ~s ~vld~nt in and Photos %3 and 4 show the clean, levele~ gravel pa . ~,, ..,,. ~. . ,',,, : . .:. ~: 7 .- ~:~' :~ On the. return flight we flew over several areas o.f construction and I observed: the 'new Prudhoe Ba~ breakwater, docking and staging p.a~ ~ear ARCO's N~ Prudhoe Bay"State 92.3-12-14; the. new d'rilli~g pad for ARCO's. W. Be~ch State' 9!; the gas'i..compreSsor fa~cility .site and the. .'PUt Rive..r road crossin~".. ..~.. '~% ... ;. . . '. ,,,:]'.. "', , ~ "' ,:'. . ".'~ ....... ' ................ .'. ............. ',,,.: ...... . .... .~: :-., .,~.~ '..":,:: "~,¢' · .~' ~.:~.'.,. " ' "" " , . .. , .,.,. .......:, ',. :,:',,,',:~.., .,,.~¢,, ,;.,' .,., ';,;'~'~'. .- ... ~' Homer L. Burrell -2- October 21, 1974 Upon arriving at Exxon's office I filled out a Field Inspection Report (attached) with approval of a satisfactory final clean-up of this location. Mr. McLain then drove me to the ARCO base camp to get my bag and then to the Deadhorse airstrip %~here I caught the Wein flight, arriving in Anchorage at 6:00 P~. On this field trip I witnessed and approved the final clean-up of Exxon's Point Storkersen #1 well location. LeS:~ha Attachments , " ~ ! " \" ~... Ct' ¡ " . , ' låì:iéîåctory '$fj:.š~,iJ'l.g . 1£:..' ,~. N(), " " """," ,,', ",,", "Ye~ Nb., '" ,', """', ",,',', ""', ,',' ",", """.' ,:I;::')1.<i~'1. ',.~~;.S$. ,', ' "',,',,/ (:' ()11. Man,",ifold"p:'res&ur,e't,es't,' '~"::~;:i;:<:::"",.,j ,~,:,,) (, 'J 2.: : Säfety , V~alve:s...J:.løœl" ,(""J, , .' ,() ,12.,', ~'P:~...:.y.~. T.~~ , , ~:,;~:;:;,:.;t;~~;;;;:~;;~':::,j ( ) ( ) 3. Safety Valves-Kelly, ( W' () 13., 'eserve Pit," " j ( ) (1 4. Safety Valves-Subsurface () () 14. Pit B~rm ' 'j , (0) " () 5 .BOPCløsiag , System () () 15., Location Berm' ,j ( )() 6. Remote Controls ( ) ( )' 16. Fuel Berm, :'1 ',', ,5 ) """ ,J» 7. "BrUling Spool-outlets ,,'.. ",' (, ~.., ,. ,', (.>', " "17.,, .,~e~nionsof{ nt~~~n" " ,;h:'; "j '¡¿>J't!/'¡I,';fj(¡;;¡''i!)f.lA,:f: 11-1($ AAAN ri,, J 1) £ þWb"'Lt. /fÞPp Vj 1/1::1>. ' '~~1. Signed. ';(.. H ~ (L>;., :.:dDate 1,;" ~ / '.,~,' , 'ð/~'~' .';..~ ~." M EM ORAN D( b M,.,.. DEPARTMENT OF NATURAL RE$~O~'RCES DIVISION OF OIL MiD GAS/, TO: Homer L. Burrell ~...~m.'~-'" ~." Di~ctor C~ief Pet~le~ · Lonnie C. Sm, th ~¢ Petrole~ EnCneer IlJRU: FROM: State Alaska DATE: September 17, 1974 ~-' TELEPHONE NO: ...~f SUBJECT: Field Trip Report- Cld'an-up Inspections on the North Slope- for Plactd's Staging. Area and Placid et al Plaghm Beechey Point ~l; ' Exxon's Point Sl~orkerse~ #],:. Mobil's Bell Unit #1, West Kadleroshilik' #1, .... and Mikkelsen Bay State ~l, · ,, .Tuesday.- September 3, 1974 I met Placid Geologist, Mr' Bill Van Allen a.t m the Anchora~g& airport 'and we both boarded a 7:30 a.m. flight for Oeadhorse, l. ' arri.ving af.ter some delays at 10:45 a,m, While we were waiting on our luggage . at the airport I was contacted.by Mobil's Construction. representative,. Mr. ~im . Taylor, who informed me he had.,.three wells ready for a final clean-up inspection and would like for me. to visit them either that evening after' I was., .through... .... . with .the Placid work or' the. 'next day. if I. could, stay. Over, . I assured him. that.'..." ' ! could stay over and would make. arrangements,.later, that afternoon.to visit his' .. locations ........ ~j( .... Mr. Van, Allen· and i were met 'by his contractor; Mr. Murphy Clark, who was in .. charge of the Bechtel construction, crew that performed the clean-up work for .: Placid, Mr., Clark drove us to ,the Gay Ainvays I~eltport where we contracted .. for a helicopter to carry us to.. the location. We then went on to the Nabor's ,', camp·where we had 1.unch..Following lunch we returned, to Gay.AirwaYs and .de.'. .' parted in.a Jet Ranger at 1:38 p..m.. . .... Placid'$ Beeche3,.Point Supply. Staging Area - l~e flew directly to the Beechey Point Staging .area 'On the ocean, just north of the Beechey Point well.,., circled once to take pictures and landed to inspect the location.on the ground.,, i .. took Photo #1, from the air, and Photo. #2 (all. photos attached) from the ground,. Both '~hOtOs' Show the neat stacks Of PiPe, supplies and folded pillow tanks~ .clean smooth gravel:pad and bermed gravel fuel .revetment. The location is still clean' and in a very neat condition.. · . , , The six full tanks of dies.el'.~ueI that had originally been ~tock piled at the I m :m m m :I .. Staging area had been empt3ed .and transferred to anOther operator and the pillow. .. tanks removed '.from the fuel .pit,. rol.led up and stacked on top of the casing that i~ 'still stock' piled on the location. As a matter of interest, Mr, Van Allen .in-.' formed me he had. calculated that a minimum of 13,000 gallons of diesel fuel had been stolen, from the pillow tank storage this past year .... After walking the pertmete~"'°f"i~he pad, it' aPPeared that the location was stil I '. just'as clean as' it had be. eh .last year when .I had flown over (9./19/73)_ and the. " previous year when I had ~nspected the location on the ground (9/13/7~). We.. went back to the 'helicopter. and after, circling the location again, flew one.' .i .: mile south to the. Beechey Point well.' ..... m m mm "" P]acid'$ PlaCid'et a1 'P'lagh~ ~'eechey Point. No: l, section 14, Tl3N, RllE, Uj."'."..'."" (P&A",' ¢a'nuary '12, '1971 )"' This mwel '1 I~aS ' pl'ugged and.abandOned soon afl, er~ 6~.i~' ..... '.. · drilled in l~)~i" but~ .bhe'".rig was stacked on .the locattdn Until. this'past 'al. nfo.r, ...'.. _ )-tomer L, Burrel 1 -2- September 17, 1974 a~:d now that it has been re:~.oved and the location cleaned up, b~e were supposedly .,.~aking a final inspection of the location. We circled the location and I took Photo #3, ~hich shows the majority of the pad ~vith the pit area in Ge background. It shows clearly the erosion that has occurred between two small lakes across t~ .,e filled pit area, and the three ungraded areas on the pad also. show up to some degree, ),~e landed and I took Phot~ #4, which shows the P&A marker, the unfilled cellar,. cellar boards which stick up above the gravel level and also several rows of ' piling which were not cut off deep enough and are so shallowly covered With gravel, that normal weathering will soon expose them again. Photo ~5 is another view of' the P&A marker across a well graded area of the . pad. Photo ~6 is a close-up of the erosion cut betmmen the two small lakes and across the pit fill area. I informed Hr. Van Allen that additional work would be required,.' We discussed the work that had to. be performed' on the locatio~ with the contractor, Mr. Clark. An. ungraded mound o.f dirt on the east edge of the. pad needs leveling.. 'a, area on the northwest, corner of. the pad ' needs grading and sufficient gravel, will have to be. pulled from some areas of the pad to refill the erosion cban.nel that has occurred' between the two lakes. across the pit fill area. I also. asked that. additional gravel be placed over' "' the piltmgs so that normal weathering would .not expose them and that. the cellar' ~ m boards' be removed and the cellar ftl~led with gravel. They both assured me that . there would, be no problem to do thiS~additional work and we headed back for Deadhorse .... .. ., ., . On, the return flight ! requested that rye stop by an Exxon location that.was on "' our way so that I could make a brief inspection. Mr, Van Allen readily agreed to this and we had previously discussed whether or not we would split the cost but since it was such a minor amount of time involved, and not out o.f the ~vay, he saidl that there would be no cost to the state for this stop. and that Placid would take care of the complete chopper ticket, I filled out a Field Inspec- tion Report form {attached) for the Beechey Point Staging area .indicating a satisfactory 'condition and showing' all fuel had been removed and the. pillow. tanks stacked, I also filled out a similar'repor, t form. {attached) for the Placid-Plaghm Beechey Point No. 1 well indicating the unsatisfactory work and the corrective measures required. ,.. ,, Exxon's point Stgrke~smn No. '.)., Sect~ion. 7~ il. 2N, Rl~r_ )).M, (P&A, September. 3, '1970) This Well. was ~i'~u~ged in lg70 by. the preVi6uS'-6'pe~l~6r' HareliP:On. Brothers Oil Company' but before the clean-up, of the lease, could be .accomp- lished, operatorship was changed over to Exxon Corporation on June l, 1973, .. Hy.inspection of the locatton..last year, September 19, 197'3, indicated the .... clean-up of the location was incomplete.. Our letter' to. Exxon and their P-3 notices to us indicated their willingness to complete the clean-up and finally on May 16, 1974 they indicated that they had com. pleted the clean-up require- merits and requested inspection.. This P-3 was' filed without coming to my atten- tion, and the inspection was not made until this' visit. ~(e approached the location from the West and I took an. aerial photo;..Photo ~7., v~hir~ shows the location on which can be seen the P&A marker and the ~i'lled" pit area. We landed' and I walked the location and took Photo #8, which shows. Homer L, Burrell -3- September 17, 1974 the 'flanged ~vellhead with the P&A marker welded on top. The P&A marker cor- rectly identifies the well with the information on it. However; the cellar shown is incomplete because 'it is unfilled; has loose boards on top which should be removed and/or covered; and most of the steam pipes have been cut off or bent over and they are so shallow under the gravel that normal weathering will expose them. Several loose boards are lying around and the rathote case- ment is still sticking up. Photo ~9 is a little fart, qer away from the wellhead but shows the P&~ marker in the background. Several· loose boards are exposed on the gravel, .and a steel band in the foreground. Photo #10 is.to the east side of the wellhead, off of the pad, and it shows a twisted, bent joint of pipe and a portion of a barrel. Photo #11 is off of the south edge. of the pad and shows miscellaneous cups, cans, and trash.. ~ I had previously documented just about every item mentioned in the above photos , in my previous visit a year ago,.with, simil'ar.photos, showing, these same boards, .. metal:, bands, trash, and. pieces of pipe laying on or off of the pad. It is obvious whatever contractor performed the clean-up work'for Exxon 'only did a small ".: ...... amount of work around the wel. lhead. · .. ,. I filled out a Field Trip Inspectio~Report (attached'). indicating the unsatis- factory condition of the clean-up and what needed to be done to correct it. I. only spent 15 minutes on the location and at 3:15 p.m. we took off and departed for Deadhorse, After arriving at Deadhorse, t~'e returned to the Nabor's camp and the Bechtel Bffice, where I provided Mr.....Van Allen with copies of the Field Reports and we again went over the requirements for satisfactory completion of the clean-. up on the Placid location. .. i then contacted Mr, Jim Taylor, contractor for .the Mobil. Oil Corporation, .and made provisions to spend the night at Nabor's camp at Mr, Taylor's request.. At 4:20 p.m, I left withI ~r. Taylor and his pilot in the Mobil chartered helicopter and headed for the West Kadleroshilik location. ,, Mobil"s West Kadleroshtlik No.. 1, Section 1~, TBN', R14E, U.M, (P~, March lB, ~i97k))' 'g This well' is o6e' O¢'seve.ral' l'eas'es "ahd Well~s"~.h'i6h have be'eh" t~rans': -'i ferred from federal authority to state authoritY, Th~'s was. my second visit to this location. I had inspected this location and requested additional, work to be performed before it could be satisfactorily completed, ... .. Photo #l~ was taken near the ice airstrip location and it shows a. pile of.' tundra grass and material that was scooped up when. an area was. cleared of snow.. The snow and ice is just about all melted now,. leaving just a pile of tundra grass. There seems to be no problem, here. since there, appears, to be no tundra damage.. Photo #13 is. a picture of the..reseeded airstrip area, Close inspection .. showed this to be in very good. condition with the new seed growth coming on. ,. . Homer L. Burro1 ] -4- September 17, 1974 Photo #14 shows the wellhead on the left side with the tip of the P&A marker sticking up above the mound of dirt arour~t the wellhead. At the time of my first visit this n~rker was already in place. At t~he request of the U.S.G.S. It was welded to the side of the high wellhead rather than on the too of the top flange so that it would be less noticeable (according to a U.S.G;S. rep.) I allowed it to stay there, even though it is not 'the normal installation. The large area in the foreground was the pit area where the gravel boulders had been stacked and was now leveled and smooth. Photo #15 is a picture of a portion of the. pit area and the camp area'in the background. Photo ~16 is a different view of the pit area and the well- head with the mound of dirt covering the wellhead. Photo ~17 and #18 shows the areas of the campsite where much debris and trash had been cleaned, up. This location was extremely well cleaned up and looks very good. ! complimented Mr. Taylor on the completeness of the work. Since I had no additional Field. Trip Report fores with me I took Mr. Taylor's copy of the previous Field Trip Report form of 7-31-74..and wrote on the bottom. that the unsatisfactory items had been corrected and that the "Final abandon'" merit and location clean-up approved 9-3-74,.". i We had a stroug wind of approximately 45.knots blowing from the east.. The . chopper pilot did not even leave th~ controls,, while. I quickly walked the location with Mr, Taylor and made the previously mentioned photos... We then ... boarded the chopper again and headed for the Bell location, .~b~l's B,e]ij Unit "9- l, Section 8, T4N, R23E, ,.M.. (p&A, June 24,'.1973) e appFoached the B'el'i l'6'catio'n, from 'th6'.S'outhweSJt I took 'P-ho.to '#19 an~d ~20 from the air. Photo #lg shows the location with the .wellhead ma-F~-er in the center; the camp & supply pad area; the short road and the Beaver air- strip that was 'finally constructed when this well was unable to be finished during the winter. Photo #20 is a close-up of the well pad.,, with the P&A marker and a mound of' ~nd the-wellhead shown in. the center, It has rained quite a bit during the work on this location,, and water is still standing, in all the tracks in the filled pit area,. The. foreground of the picture is very wet. and not completely smooth due .to the vehicl.e {cat) tracks. After circling the location we. landed, .With the wind still' very high the chopper pilot stayed in the aircraft,. Mr.. Taylor and I walked the .location,.. I took Photo #'2'1 from the southwest corner of the pad area., looking across. the filled pit"toward the wellhead... As I mentioned in my previous, report, .the ' so called "gravel" used on this location is. really a mixture of conglomerate rocks with dirt and would be a very coarse textured surface even under the most ideal grading conditions. I could tell that considerable work.'had beenl' done. since my previous visit and that the pit' area was iln 1)lu(ch better conditiou. i took Photo #22 standing on the mound of dirt by the P&A marker and. looking. toward' the southwest across the filled pit area. I walked up .tO the short'.. road leading to the airs. trip and took Photo #23 of the supply pad area., I then walked back to the north along the east edge of the pad and took Photo #24, looking west toward the wellhead marker and helicopter.... -- ~ m .: ,Ho~er L. Burrell -5- September 17, 1974 .. All the debris had been ren~oved as I had requested on my previous visit and the dirt work had b~n completed. Again, using Mr. Taylor's copy of the previous Field Inspection Report dated July 31, 1974, I wrote "items corrected, Final abandonment and location clean-up approved, Sept~J~er 3, 1974." ~,Je loaded back into the chopper and headed for the Mikkelsen Bay State loca- tion. Mobil's Mikke!sen Bay State No. 1, Section 13, TgN, ~a~.~,. SeptemJ)er 30, lg7~ ~-~ ~-~e' ~bout ~g from the southwest. I took three photos of this location all from approximately the same angle and all from the air. They each give a progressively closer view of the well cleaned and leveled pad with the dirt mounded around the well- head and the. PaA mrker, in the center. ~ m m ~ The first photo, Photo ~25 allows, one to see the .lakes around the location m m and the road leading Oiff to .the airstrip.. Photo ~26 ts essentially a close up of the pad area lWith the road.leading off'to th'e at~r~trtp i in the' background..... I could see from this view that the large amount of trash., material,, and iron that had been. located on the southwest corner of the pad. area had been picked up and removed,' As we came closer I took Photo. ~27;.'showtng just the pad area w}th the' smooth graded gravel, the. dirt, mounded 'a~ound the.. wellhead, with. the. P&A . . marker., ' ..'~:.~!. ,. Following this photo we circled over the location', so that I could view areas where trash had been removed. I could also .see. thewell filled and graded . area on the northwest corner o~ the pad where I. haddiscovered a sunken area with a puddle of oil on my previous visit,. " We then. headed for Bullen Point, Mobi'l's supply depot, on the Beaufort'Sea coastline, I noted on Mr. Taylor's copy of my previous inspection report, dated July 7, 1974 that all unsatisfactory items, had been "corrected and Final abandonment and location, clean-up was approved Septer~oer 3, 1974." We arrived at Mobil's Bullen Point'supply depot a.t 7:00 p.m. with the high winds still in progress.. 'We could see that alll of the available, crewmen, were out trying, to .contain the pillow tanks.and pit liners which were trying to blow out 'of position.. After landing and anchoring down the helicopter we .all aided in tying down the pillow.tank liners and later had dinner. We ,. returned to. Deadho.rse at 9:15 p.m, . The chopper pilot dropped ne'off'at the ." r~.abor's camp where I spent the. night.. ....... . ...... · .. m m mm m . ' .... .. . Thursday, September 4, lg74.I '-'..')[ made plans' to .depart. D.e.adhorse' on the 9:45. ... -a.m. flight and'aYter Obtai'ntngl transportation to the a~rport, found' the . flight was. delayed. Finally,. the plane arrived and we departed at' 12:15 p.m. I arrived in Anchorage, after stopping in Fairbanks, at approximately 3:00 p.m.. ,O~n_~]_s_ft~ld ~tr.i.p_ I ~de_a p.~l.'tmin~ary i.nspection of Placid's Beenhey Point. ,uu=~mn, ~nere ~ re ulreu a¢clltlonai work , · q' ' to be performed, and Exxon s Point' stor- kersen location, where.! likewise will' require additional work to be performed, .. Homer L. Burre]] '6-- ' September 17, 1974 and Placid's Staging Area which ! conside~d in satisfactory condition. I also visit~d three ~4obil locations where I approved the final abandonn~nt and clean-up of the West Kadleroshilik, the Bell Unit, and the ,~likkelsen Bay State. Attacb~nents HHH:LC$:jh . - Alas~_.? Oil and Gas Conservation Commi~_:ae Field Inspection Report Drilling Permit Inspected by ~~, ~. ~,~perator's Rep..~ ~~-A~ fionCr. HiS ~o. Satisfactory Item Satisfactory Yes No Yes No ( ) ( ) 1. Well Sign ( ) ( ) .( ) ( )- 2. Safety Valves-Floor ( ) ( ) ( ) ( ) 3. Safety Valves-Kelly (~)~ ( ) ( ) ( ) 4. Safety Valves-Subsurface ( ) ( ) ( ) ( ) 5. BOP Closing System ( ) ( ) ( ) 6. Remote Controls ( ) 7.' Drilling Spool-outlets ( ) 8. Flow Lines ,. ( ) 9. Kill Lines ( ) 10. Manifold Chokes Item 11. Manifold Pressure Test 12. BOP Pressure Test 13. Reserve Pit 14. Pit Berm 15. Location Berm (). () () () () ( ) ( ) 16. Fuel Berm ( ) (.~ 17 Operations off "Pad" ( ) (~r 18 ~ "General Housekeeping" (-I~ ( ) 19. Abd. Marker in place ( ) ( ) 20. Water Well covered . J. hole I~ iFe _mc~ s'~ 'be " .! Form 10-403 REV. 1-10-73 "1 ntentions" In Triplicate Submit & "Subsequent Reports" In Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) ~LF-1 GAS I--I {Exxon Corporation - Operator 6/1/73) WELL[---i OTHER(p. 0. BOX 120 Denver, Colo. 802D1) 2. NAME OF OPERATOR Hamilton Brother~ (lil £n. ((l?ratnr tn fi/1/7.~) 3. ADDRESS OF OPERATOR 1600 Broadway - Denver, Colorado 802(32 4. LOCATION OF WELL At su trace 500' ~L & 500' FSL Section 7 T 12N R14E UN 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 14, CheCk Appropriate Box To Indicate Nature of Notice, Re NOTICE OF INTENTION TO: 5. APl NUMERICAL CODE 6. LEASE DESiGNATiON ANOSE ~AL~- ,. ; , ADL 346 2306 7. IF INDIAN, ALLOTTEE OR TRIBE N/A , 8. UNIT, FARM OR LEASE NAME .. Pnint S~nPbp~pn ~ .......... 9. WELL NO. I .... "FILE: ~ lde~ - - .... , TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PL~NS (Other) 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) SW 7 T 12N R 14E UM 12. PERMIT NO. 69-33 )ort, or Other Data SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENTH ALTERING CASING SHOOTING OR ACIDIZlNG ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. On 5/15/74, the existing Christmas tree was removed at the 6" series ,1500 top flange on the upper casing head section. A 6" series 1500, blind Flange with the approved , ,, i den l~i fi ca ti on marker welded to it was installed. All clean up work has been corn- pleted and a final location and marker, inspection is requested. / 16. I hereby certify that the foregoing Is true and correct . (This space for State office use) CONDITIONS OF ~PPR~AL, IF-ANY: T,TLE'Drilling Operations gmJ,nt_ DATE .~/1fi/74. See Instructions On Reverse Side E~.~ON COMPANY, U.S.A. POST OFFICE BOX 120 · DENVER, COLORADO 80201 EXPLORATION DEPARTMENT WESTERN DIVISION DORSEY HAWKINS DIVISION ACCOUNTANT State of Alaska Division of 0il and Gas 3001 Porcupine Drive Anchorage, AK 99504 March 1, 1974 - -~'-~.- ~-~c ~!'~' .... c'¥-~'~'- - -.i-~.....;,:~,-~_~ - -i.-~-..~.~5-:F7~.t ...... -- '--~'~X~--~-- SEC CONFER: FILE: Gentlemen: Exxon Company, U.S.A. became operator of the Point Storkersen No. 1 Well effective June 1, 1973, after taking over from Hamilton Brothers Oil Company. Attached in triplicate is Form P-3 Sundry Notices and Reports on Wells, submitted in request for approval of our stated plan of a'bandonment. Assuming the plan meets with your approval, please return a copy with your' approval. DMV/ch Attachments Yours very truly, MAR ~ 1_ 1974 DIVISION OF OiL AND GAS A DIVISION OF EXXON CORPORATION ~'orm REV. 9-30-67 :i Submit "Intentions" in Triplicate '[ & "Subsequent Reports" in Duplicate STATE O,F AL~KA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or pluli back to a dl£flerent reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) Ami N~CAL CODE 6. L~,ASE DESIGNATION A.ND SEI~LAff~ NO. 4 DL 346 2306 ~'o,L (Exxon Corporation-0perator6/1 WELL ~- GAS wELL []] OTHER(p. 0. BOX 120, Denver,C0,8020l~ 2. N~U~. O~ O~TO~ ~ ~ ~U ~.~,~ Ga Hamilton Brothers Oil Company (0perat~~ ~~3~] [~ [J~int Storkersen 1600 Broadway, Denver, Colorado 80202 ~m · ~ 4. ~CATION. O,F WRI.T. [VIlli , i 1~; T [ 10. F~ a POOL, OR WIDCAT At ,ur~ace - .. '~ .~ildcat 500' F~ & 500 FSL Section 7 T12N R14E ~i~}~{.0N OF 0IL s~7 T12N RI4E 13. ~-EVATIONS (Show whether DF, ET, GE, etc. 14. Check Appropriate Box To I,ndi'cate Nature of N~oti'ce, Re NO~ICE OF INTENTION TO: TEST WATER SHUT-OFF ~--~ PULL OR ALTER CASING WATER SHUT-OFF 12. PEP,/VIIT NO. 69-33 :or~, or 'Other · UBSEQUENT R~POET OF: REPAIRING WELL SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACXDIZING ABANDONMEN, Te REPAIR WELL CHANGE PLANS (Other) (Other~ (NOTE: Report results of multiple completion on Well -' Completion or Reeompletlon Report and Lo~ form.) 15. l~EscaxSEproposed,,aoPOSm~work. Ga COMPLETED OPma~TxONS (Clearly state all pertinen~ details, and ~tve pertinent dates, includin~ estimated dat~ of startl~ an}- Propose to remove well head equipment to 5-1/2" casing hanger spool -' weld 1/2" steel plate Over face of spool, weld 4-1/2" pipe well marker upright on top of steel plate, fill and level cellar. The 5-1/2" casing was set and cemented at 10792': .lst s~age'with 450 sacks, 2nd stage through DV collar at 4000' with 550 sacks, circulated to surface 9-15-69. A Halliburton cast iron bridge plug was set at 10742', 10-28-69. Perforations 10580'-10640' squeezed with 100 sacks cement, 11-3-69. Perforations 10495'-10505' squeezed with 75 sacks cement, 11-6-69. Perforations 10460'-10470' squeezed with' 100 sacks cement, 11-12-69. The 2-7/8" extreme tubing landed at 10558' with Baker Model D packer set at 10555', removed blow out preventers, installed ~as tree, 11-18-69. Well re-entered and plugged in August 1970 due to perforation seepage causing pressure on 5-1/2" csg. and 2-7/8" tubing (approved by State Oil & Gas Co~is'sion). The 2-7/8" tubing was perforated and the annulus cemented from 7420'-8640' with 100 sacks Class G 'cement, 8-21-70. Tubing was perforated at 7350' and cemented tubing and annulus 6182'..7350' with 100 sacks Class G cement. Cut tubing at 6000'. ~lled up 5' and cemented 5-1/2" casing 5660'-5995' with 100 sacks Class G cement. ~lled out of cement. ~id do~ tubing to 820*. Cemented,~5-1/2" casing 820' to surface with 175 sacks Class 'G cement. Pulled tubing out, 8~-70. ' Z/ Laid tubing/~wn out of de. ck. Installed ~as tree, 8-24-70. Reques.ted pe~ission tn close tt~f well & ~1 ~ellar for final P & A after freeze first of Novmmber 197l 16. I her~~~t..th, f~~4 eorr,~ .... . ' ~~,x,n, Division~Orilli~' ri,Tm 3-1-74 *Continu.:~d on attached sheet. Approved Copy . ...: . .. In September, 1973, the remaining boards were stacked and general location leveling was done. The stacked boards were removed in Novem- ber, 1973, and additional cleanup performed. Pursuant to your approval of the _ow ol e t the following additional work will be performed in March or April, ~974, at Pt. Storkersen #1: I. Remove existing Christmas tree at the 6" Series 1500 top flange on the upper casinghead section. II. Install 6" Series 1500 blind flange with.~ long x 4" OD steel well ma. rker welded to it. The ~" OD well marker ~~:;;e%,~will be cap welded-on-th~-~pen end and the following infor- ~'~ mation will be bead welded approximately 2' from the top: Hamilton Brothers 0il Company V Pt. Storkersen #1 500' FWL; 500' FSL; Sec. 7-T12N-R14E U.P.M. III. Fill cellar with gravel,'~level, and make sure location is clear of all debris, trash, boards, etc., prior to leaving. RS/ch 2-28-74- DWI ,OI OF OIL PO"' T STORKEF{SEN WELLBORE SCHEMATIC PLUGGED 5-I/2"CASING FROM SURFACE to 820'W/175 SKS. CASING LEFT W/ll.7 PPG MUD INSIDE PLUGGED 5-1/2" CASING FROM 5660-5995' W/]00 SKS. PERFORATIONS 10~460- 10,470' SQUEEZED W/100 SKS. PERFORATIONS 10,495-]0,505' SQUEEZED W/75 SKS. PERFORATIONS 10,580-10,640' SQUEEZED W/100 SKS. CAST IRON BRIDGE PLUG of 10,742' PLUG No.l' 10,9'12-10,750'W/46 SKS. ]I6"X 24"at 65' CMT TO SURFACE W/;~54 SKS. 11-5/4"0t 275' CMT TO SURFACE W/t~t51 SKS. ~ 8-5/8"0t 20:~1' CMT W/1570 SKS. HALLIBURTON DV TOOL(If 4000' CMT TO SURFACE W/550 SKS. CUT 2-7/8" N-80 TBG. ot 6000' AND PULLED TUBING ond ANNULUS CEMENTED FROM 6182 to 7350' W/I00 SKS. ]00 SK. CMT. PLUG FROM 7420' to 8640' .~~ 5-1/2"ot 10,79:>' CMl. W/450 SKS. TD at 11,473' R.S. 2-20-74 OTIS TYPE "XO" SIDE DOOR SLEEVE ot 10,543' OTIS TYPE "N" NIPPLE ot 10,554' W/PLUG IN PLACE MAR' ! 1974 I)I~I$10N OF OIL E:~()N COMPANY, U.S.A. POST OFFICE BOX 120 · DENVER, COLORADO 80201 EXPLORATION DEPARTMENT WESTERN DIVISION State of Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Homer L. Burrell Gentlemen: In re: I--T-~:~ i .... / -',..L':;' · Lb t ........ ,,..:. ~ 9 ?-'~"K ' -'~ mG I~ 'r' December ---]'-'i' (~EOL --I-'~ GEOL File No. 816815 ---j'--'R~- ..... ADL-346~.3 Stump Island Area 2nd Judicial Division State of Alaska ---i DRAFT I SEt:----- CONFER: A copy of your letter dated December 10, 1973, directed to our Anchorage, Alaska office, has been referred to this office for reply. You have advised that since Exxon has now' become the operator of that part of the captioned lease previously operated by Hamilton Brothers Oil Company, you should be furnished with documentation of such change of operator- ship. We sincerely regret not having previously advised you of this change. Hamilton Brothers Oil Company was the operator of an 80 acre;..' tract carved out of the SW/4 of the captioned lease pursuant to a Joint Venture Agreement dated March 12, 1969, by and between General American Oil Company of Texas and Hamilton Brothers Oil Company. The rights and obligations of General American Oil Company of Texas under said Joint Venture Agreement have been acquired by Exxon and Atlantic Richfield Company. By letter dated February 22, 1973, Hamilton Brothers Oil Company advised Exxon and other joint venture parties of its intention to resign as operatOr. A xerox copy of said letter is attached for your records. Since Exxon was the operator of all of the acreage covered by the lease except the said 80 acre tract, we elected to become operator of the 80 acre tract. Pursuant to the terms of the said Joint Venture Agreement, the companies comprising the "Hamilton Brothers group" voted and determined that it was agreeable for Exxon to assume the A DIVISION OF EXXON CORPORATION State of Alaska Department of Natural Resources Page 2 December 20, 1973 operations under the said Joint Venture Agreement. A xerox copy of Continental OH Company's letter dated June l, 1973 to "Al! Joint Venture Parties", advising of the voting° is also attached for your records. Accordingly, we wish to advise that E~_ _xx_ o~n~ C, orl~_orahion~is~des~iznated~ a_s the ~ ~ooerat.o~r of the lands comprising the captioned lease. Please adviSe-,~ if we may furnish any additional information to you. ¢ l lq Very truly yours, RDL:vl Attachments Ro~ D. Lynam P~.o r m P~7 SUBMIT IN I 'r '! :iTATE OF ALASKA "' .,,. .,,~ 'o~',- OIL AND GAS CONSERVATION COMMITTEE ~,,._,..~,. ,ide, WELL COMPLETION OR RECOMPLETION REPORT AND LOG* b. TYPE OF COMPLETION: NEW %VELL ~'~ WOI1K OVER 2. NAME OF OP[RATOR Es ..t__J BACK [] n£Svs.. ~_~ Other Hamilton_Brothers Oil Com_~_~Ev- 8. ADDRleS-q OF OPERATOR 440 Eagle Street, Anchorage, ALASKA 99501 4. I, OC~TIOS oF W~-Lr- (Repor~~ a~d in accorda~ce~m~ts), At,u~race 500' FWL and 500" FSL of Section 7 it top prod. l.terva, re~,o,'tea below 539' FWL and. 5 70' FSL of Section 7 it total depta 540' FWL'and 59'0' FSL of section 7 __ /..:'~ .......... 4 DL 3462306 .-. ~.. IF INDIA_~, ,6J.J.~-i-/.~,l OR ~BE 9. W~L NO. Point Storkersen ~1 Wildcat [1. S~., T., R., M., (~M HO~ . O~E~VE) 7, T12N, R14E, UM NOTE: T.D. extrapolated from'10,750" btm of survey, i...~,~o. . ~I~D_A, TE ~D' 1~. C~. _H~ID_~MI~. SU~ ,P..(~R ABAArD. ~c~..z~ 1969[November 25', 1969. I 9a ~7, ¢, I ............... !~.~.}~ ~~'0 742/10740] 10,580- 10,640 (meas'.:depth) ~4. TY~E F.I-~CTRIC AND OTHER lES, CFD, TEMP, GRNi, BCS, CB'; CAL, DM., BHS, SNP ....CASING' P~CORD (Report all strings set in w~ll) ' CASING SIZI WEIGHT, SURVEY MADE '.DiYI$1OROFOItAN~',,'".:~; . ' /' ' ~es ueezea w/100 Sx Class G ~. '- 7 0'Sx lass G .. DATE ~RST P~ODUC~ON Flowh~, gas Iii. t, pump~ize and type of p~) ' ~~S (~u~ .or .. Well Suspended :' ] ='~'~' Shut in ~ . '," . . , , . ~ , ~ " . . ..., , . ~ ~ .... sm~ . _ -- . ; ~.~ : . ~ Production Su erintendent ~E ':'~"~ D&TB OP TEST. IHOU'RS TES'~mo ' ICHOI{E S~.~: [PROD'IV FOR OII~BB ' ~EST PI/IPulOD ' · . i-NSTRUCTIONS .. · . General: This form is designed f.0r submitting a Corhl01ete ~ _ and correct well completion, report: and log on all types of lands and leases-in Ala:Ska. : Item: 16: Indicate which elevation is used as refei'ence (where not otherwise shown) for depth measure- : ments given in cther spaces .on this form and in any attachments. Items :20, and 22:: If this well is completed for separate production from more than _.one interval zone (multiple completion), so State in item 20, and in item 22 sh'ow the p'rcducing interval, or intei'vals, top(s), bottom(s) and name (s) (if any) forlonly the interval reported in item 30. Submit .:a separat~ report (page) on this form, adequately identified, for each adc~itional inte~.val to be seperatel, y produced, show- ing the ao~litional data pertinent to such interval. Itom26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location ofl the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). -- 34. SUMMARY OF FORMATION TESTS INCLUDIN(; INTERVAl, TESTED, PRESSURE DATA A_N/) ~,COVERIES OF OIL, GAS. 35. GEOLOGIC' M AR~]gl:t~ WATF-J/ AND MUD __ : . . DST gl (10,580-10,640) 315 BOPD-30% 16,800 cfb FFP-51034 psi'FSIP 5151 Psi N~t,~ ' DST g2 (11,070-11,277) Packer Failed _'-. DST g3 (11,086-11,277) Rec 2000'W.C. and 450 ' gas cut mud. FFPll05psiFSIP Top Upper 6000 psi' Cretaceous 4,750' DST ~4 (10,580-10,6~0) M~srun DSTg5 (10,580-10,640) M!smn '"~' Top lurassic. DST g6 (.:10 ~ 580-10 , 640) 735 BOP/D, 0%,.1550 Cfb FFP-5000 psi FSIP 52~7 psi T~p Tripssi~ ShubHk 1 O, DST ~7 (10,4~5-10,505) Rec 3100' Diesel Cushion, 570" freo oil', 500'off & cut mud, 285~ mud & o~'1 cut ~ormat~on wtr FFP 1647 psiFSIP 5102 psi T~p Tr~asslc DST g8 (10,~60-10,470) Rec 2800' off, ~as and mud cut w,c. and 850.-' ~a~_ and Sadler0~hit 10,577 mud cut wator. No froo oil. -- Top Ponn-Mlss -. · ~.: ..... .. (Carbonate) 11,0 68 ~. co~ ~'~. aa-rac~ ~m~ ~mcm~mo~s or ~uo~v. ~o~osi~. r~ac~am. ~~* ~S Total Depth ~ ~.~.~, ~.o~.s o~ o,~. ~ o~ w~-~. Penn-Miss No cores taken. . . . : . . -. . : ~ -. .. . . _ : . . .~ .: - . . - . : ., , WELL COMPLETION REPORT ORIGINAL DRILLING OPERATOR Hamilton Brothers Oil Compaay · %V]ELL NO. %1 Point Storkersen FIELD Prudhoe -SEC.. 7 , T. 12N, R. 14E UM BIAT~ Alaska~ COUNTY /~OCATIO.N 500' FWL and 500' FSL of Section 7 LEASE NO. ELEVATION S ENGINEER GEOLOGIST DATE. 4DI, 3462306 26.47' (K.B.) (T.'.H.) Don Herron Eric Loughead December 15, 1969 Production Sffperi~te~'ent COMMENCED DRILLING Iune 9, 1969 C'OM.PLETED DRILLING November 25, 1969 TOTAl. DEPTH 11,473 PLUGGED DEPTH 10,7.42 '.]'UAIK~.. _ , . . GEOLOGICAL MARKERS Top U. Cretaceous Top Jurassic Top Triassic Shublik. · Top Triassic Sadlerochit ON PRODUCTION · .. Suso._Flowing/~]~Y~X~. Top Penn-Miss (carbonate) '(.cross out unnecessary words). MEAS. DEPTH 4750' 8409' 10.545' ' ....10577'_. 11068' .~r. od'uction, Clean oi'i Gravity _._..---___ ,Clean Oil In:iiial B/DJ · PRODUCTION DATA Total Cut I'Bean Size % Tubing Pre~s.ure Casing Pressure Gas ~ IMCF Per. Day~.. ., Size .Of. 'J.D'ept.h' ~.s_~q., (ApI)lof Shoe j .fS' 10,792 Top of Casinq.. Surface CASING RECORD (PRESENT HOLE) Weight New or Smls. .Grade Size of' ofCsg.. 2ndHand LW _ofC..s.g. HoleDrld 42% New Surface Smls. Smls. H-40 ]5" J-55 .11" Smls. N-80 7-5/8 No. of Sks Depth Cem. of Cem. ifthmtPerfs. 851 1,370 1,000 _, 36%· New SUrface 1 7% New PERFORATION S Size f_._:C_.!a' S i n___g_ 51" ' ~1,, - . NOTE. From 1 O, 5'8( 10,49,~ All abo¥ To 10,640 l0,470 10,505 perfora Size of Perfs. :ions have been S No. of Rows 'queezed Distance Bet. Ctrs. vith cemen Method Of Perfs. Jet 4 holes per foot Jet 4 holes per foot Jet 4 holes per foot ELECTRIC LOG DEPTHS 600', 10,370' 10.~_Z89 '_, 11_~_2._8_8 ]_~ .1 1,. 4 7'2' , 10,510' DRILLED BY , . . · ~:' ".':'. :_.'-'~!..,.,.' ". '. Karl B. King Drilling Co. _Rig_ ~ C-1 HISTORY OF OIL OR GAS WELL OPERATOR Ham'ilton Brothers Oil Company FIELD Prudhoe Bay ~NELL NO. DATE Point Storker'sen ~1 December 15, 1969 Sec. 7 T. I2N. R. 14E UM Signed_ Title Production Superintendent Date 6/9 ' 6/13 .. ' 6/1:5' /18-'7/21 ,, 7/2 7/26 8/28 /29-8/30 8/30 ' /'31-9/? This well was drilled by Karl B. King Drilling Co. Rig Number C-1. All depths refer to Kelly Bushing which is 26' above sea level. Finished rigging up. Started to drill' cement in conductor pipe. .. Drilled 15" hole to 275' Ran 7 its 11-3/4", H-40, 42 lb casing and cemented at 275' with 506 sacks perma- frost cement.". Used float shoe at 275' and float co].lar at 235'. Centralizers located at 265', 225' and 155'. No cement returns. Recemented through 1" pipe using 235 sacks permafrost, cement. Recem'ented with 110 sacks of permafrost cement through 1" pipe. Used ~ total of 851 sacks of permafrost cement. No returns. Good returns. Drilled ll" hole to 2744'. .. .. Ran 49 its 8-5/8", .J-55, 36 lb ~T&C casing and cemented at 2031' with 950' sacks permafrost cement followed by 420 sacks neat class G cement. Had good returns. Used float shoe at 2031 and float collar at 1946. Landed casing and installed BOPE. Drilled 7-5/8" hole to 10,381.' Ran induction electrical and compensated formation density logs 10,370 to shoe of 8-5/8" casing (2031'). Drilled 7-5/8" hole to 10,522'. Ran induction electrical, gamma, ray neutron and borehole compensated sonic logs 10,510 - 8600. :~. R '' Drilled 7-5/8'" hole to 10,792. ' ...... p. " · . ~:~9~ .' HISTORY OF OIL OR GAS WELL OPERATO~ Hamilton Brothers Oil Company FIELD Prudhoe Bay . WELL NO. Point Storker§en ~1 Sec. 7 T. 12N R. 14E UM Signed Date 9/12 9/13 9/14 . .. 9/16 9/19 ', · 9/22 ,/23-9/26 9/28 . ,//30 - 0 DATE Title Ran induction electrical, borehole compensated sonic and gamma ray neutron logs 10,788 - 10,400. Ran formation sampler. Ran compensated formation density, sidewall neutron porosity and proximity logs from 10,.788. . ,, Ran directional survey 10,750 to surface-. Ran 343 its $½", N-80, 17 lb casing and cemented at 10,792 in two stages withDV tool at 4006' as follows' 1st stage 450 sacks neat class G cement at shoe 2nd stage 550 sacks neat class G cement at D.V. tool Landea casing, and installed BOPE. Ran cement bond and gamma ray neutron log. PerfOrated 5½" casing 4 holes per foot from 10,580 to 10,640 with 3-1/8" ceramic 'charges. DST~i (Perforated interval 10,580 - 10,640.) 1st flow rate (12 hrs'49 min) 262 BOPD, 22% cut, GOR. 18,200 cu ft/bbl .2nd' 'flow rate (10 hrs 30 min) 381 BOPD; 30% cut, GOR 14,400 cu ft/bbl 3rd flow rate (21 hrs) 315 BOPD 30% cut GOR 16~800 cu ft/bbl Final shut in pressure 5151 psi Final flowing pressure 5034 psi Squeezed perforations 10,580 - ].0;640 with 150 sacks neat cement to 3,000 psi. Maximum squeeze rate 2-3/4 bbls/rnin, , %, ~,:..~ Drilled 4-3/4" hole to 11,277'. (2) HISTORY OF OIL OR GAS WELL OPERATOR Hamilton Brothers Oil Company FIELD Prudhoe Bay '~VELL NO. Point StorkerSen ~1 Sec. 7 T. 12N R. 14E. · gM ., Signed DATE Title Date ].o/13 · · - !0/2 10/.27 '., · 10/28 10/30 11/3 11/4 Ran induction-electric and gamma ray neutron logs from 11,288'. Ran DST ~2 1.1,070 to 11,277. Packer failed. Ran DST ~3 11,086 to 11,277 2 hr flow test. Recovered 2,000' water cushion plus 450' Final shut in pressure 6000i psi Final flowing pressure 1105 psi Drilled 4-3/4" hole to 11,473' total depth. gas cut mud. 'Nc{ 'formation .Water. Ran induction e'le~tric log, bore hole compensated sonic log and caliper log from 11 ;472... Plugged hole to 10,742. Spotted 46 sack plug at 10,912 and 10,480. Cleaned out cement and polished plug to 10,750. Ran and set cast iron bridge plug at 10,742. ,. Ran DST .~4 .(test of previously squeezed perfs 10,580 - 640i. 'Misrun - tool would not go past 7830'. Ran DST ~5 (same as DST ~4) .Misrun - tool would not go past 7830' Ran DST ~6 (same as. DST ~4) Opened tool for 12¼ hr flowing test. Well flowed at rate of approximately 735 BOPD, 0% cut, GOR 1550 cu ft/bbl. Final flowing pressure 5000 psi Final shut in pressure 5267 psi Resqueezed perforations 10,580 - 10,640 with 100 sacks class G cement. Tested squeeze of. perfs ·10,580 - 10,640 with DST tool. Set packer at 10,450. flow. Squeeze tested OK. .. ,,,~ ....,,.? ~,, ,' ..J ...,,...., . . , ~.;. DIVISION OF 0]I_ AND..¢,~j ,. · . No (3) HISTORY OF OIL OR GAS WEI,I, OPERATOR Harai'lton Brothers Oil Company FIELD Prudhoe Bay WELL NO. Point Storkergen ,~1 Sec. 7 T. 12N R. 14E. UM Signed DATE Title Date li/4 ii/4-' 11/6 ,, li/i2 ~i/i4 li/i7 Ii/J9 Ran in and'perforated 5½" casing with 4 jet holes per foot 10,495 - 10,505. Ran DST ~7 (test of perforations 10,495 - 10,505). Set packer at 10,463. Opened tool for .2 hr 5 mtn flow test. Recovered 3100' diesel oil cushion, 570' free oil (39.6©API at 60° F),. 570' heavily.oil and gas cut mud and 285' mud and oil cut water (1100 ppm chloride). " Final flowing pressure 1647 psi .. Final shut in pressure 5102 psi Squeezed perf'orations 10,495 - 10,505 with 75 sacks class G cement. Perforated 5½" casing 10,460 - 10,470 with 4 jet holes per "foot. DST ~8 (perforated interval 10,460 - 10,470) Set packer at 10,426. Opened tool for 1 hr 38 mtn flow test. Recovered 2800' oil, gas, and mud cut water cushion; and 850' oil, gas and mud cut water. No free oil. Squeezed perforations 10,460 - 10,470 with 100 sacks class G cement. Set permanent tubing packer (model "D") a.t 10,555' with wireline. Ran and hung 2-7/8" tubing at 10,558' as follows: 10,543' 2-7/8" tubing .. Type' "X-0" side. door sleeve at 10,543' 2- 7/8" x 2-3/8" crossover 8' jt 2-3/8" tubing Type "N" nipple at 10,554' 2-3/8" x 2r7/8" crossover 3' 2-7/8" seal assembly (top at 10,555) Bottom of tubing open-ended at 10,558 NOTE: Tubing is plugged with a blank in the "N" nipple at 10,554. Displaced hole full of diesel oil. plug in "N" nipple at 10,554. .. Closed side door sleeve at 10,543 and ran blank (4) ' HISTORY OF OIL OR GAS WELL' OPERATOR Hamiiton Brothers Oil Company FIELD Prudhoe Bay WELL NO. Point Storkers'en ~1 Sec. 7 T. 12N R. 14E UM . Signed DATE Title · . Date 1/20 - Tear down rig and move out equipment. NOTE: Blind flanges have been placed on all wing valves and casing outlets. .. .. Prepared by: ., C. ~. Champion D/¥[$10N OF 011_ ~Ni~ e~..~' ,:' ' .~.._.¢tlO~-":e~. ? ....... (s) o , o, i , I · .: i. · . FOR · TVe~. OF sunvz¥:-Su~;v;e~- Oyro::copic ;.':,O.i'.ir;hot Sur£gce · SURVF¥ D~PYH: FROM~ .. · · · . · . _ .~. To. ']'0,750 · , · $ torker scn "' .. I. 'E/,~E:.~ ' ,V/ELL. Icc), ~./:i.~.dcat "- *' ,,or ;n Slope FIELD:.. }lorth COUNTY/PARiSIL.I ,, .,.o:..o ...... STATE .. · e -',,,-, .' ' '.:..Z.'.JOD ,,,.,.__ I')!,TI': OF ..U,,,,:/. Sc~ter'i!)c:;~ .q.3, ]19~9 ,.,~ OFFICE: .... · o · . DIV!~IGN-C F OIL i.N~ GAS' ANCHOI~AG~ I.'. ' : 6 3 ?, .'-. ,., i$00. % "~0 ·., 1.'200. ;. '~,. 20"0 ·. · O[L CO,'4PANY 1 SLOPE TRUE V _P,T -cA[ · cPTH 0.00 · · ioo.o0 '.. 200.00' ,, 300 .'C0 · ~"~' 99 499.9~' · . ~o 91 '599°38 799.87 B99.86 999.86. 1099.86 1:99.86 1299.85 1399 .$4 · 1:,99.84 i'599.84 1899.84 1799.84 !899'. 83 !999.83 t_ ,: ~. 99. o 3 ,,.vg, 33 o. "!NCJjINATION DEG MIN C) SPERRY-SUN WELL SURVEYXNG cOMPANY' I · pAGE ~ 9'-L3-69-. SU?,vEv. DATE ' VERTI. CAL SECT iON COMPUTED ALO,XO CLOSU~ , .. SU-3-16513 RECORD OF sURVEY SEVERITY DEG DEG/~O0 ORIGIN AT 0 0 N 0 0 N · 0 0 .. N 0 45 N 1 .45 N " " 1 30 1 15 · 0'45 ,. '0 0 ~0 0 15 · .0 30 0 30 0 4,5 0 30 0 15 0 0 '0 15 0 30 .0 30 0 0 0 30 0 !5 THE SURFACE 0 W 0.00 0 W 0.0.0 0.00 0.75 .' 1.00 .. N 6 E N 7 E N 1' E · N 2 E N 2'5 E,. N 64 E' ,. . N73 E'' N 73 E S 84 E' S 89 E N 53 E N O E N .40 E N 2'7 E N 38 E .N' 0 'E N 38 E b1'38 E 0.26 0.25 0.5i 0.0! .0,3~, 0.3~ · .. O. 25-' 0.00 0.34 0.25 0.33 0.25 0.25 0.26 ' 0 .,09 0.49 0 ,. 49 0.25 VERTICAL SECTION .. · 0.00 0~00 .... · , · 0.00 '.. 1.!1 ~ 3.88' 6.30 8.33 9.50 I0.67 .,' ,, il.54 1! .90 ., · 13.14 13.63 . · ,. .. ... 14.03 !4.43 . 14.43 ~,. · , · . 14.85 : 15.73 i6.59 · '16.59 · 17.45 17~88 · , RECTANGULAR COORDINATES NOR. TH SOUTH ; 0.00 0.00 0.00 0.00 1.30 .' · ..' '4.35 6.96 9.1;! .10- 43 i!.'74 12.53 ' 12.72 12.97 ' 13.23 is.o · 13.08 13.3/+ 13.34 ,' 15.14 . !5.83 16.17 · · . . , . EAST 0.00 O.0O .. · 0.00 0.00: · · 0.09. · .. 0.36 · 0.63 0.65 0 5° · 1.06' ' .... · 1.46 .' · · · 2.29 ' 2..12 4.43 ...:;;... · ;'.:'%., .. · . 5.30 5.65 . 5.65 5.93 6.32 6°¢.,6 .' . · 6.86 7.40 7.67 WEST .. · · . · . · · · . · .- -0.06 ,. ,. · · ' · · .J . · · . o. · SLCPE - E'.SU?,ED ;l ,- 25C'" · ~' 4C C' · 3,5C3. .:"..300 · · 390'2. , . 4590. 47 '3 O · CC:4PANY 9--13-69 -VEP, TICAL SECT ION SPERRY-SUN WE'LL S'U'RVEYING COMPANY R~CORD OF SURVEY TRUE INCLINATION VEZTiCAL: DEPTH DEG MIN 239'9.82 0 45 ',99. ~" ' O' 45 ~ 0 .2~.~.79 - ~799.~3' 25g~.77 -, ,9.77 3"' 3199.75 3299.75 3~99.75 · '3499 -~599.74 3099.73 3799.73. 045 0 45 0 30 0 3O 0 3o 0 45 .0 30 0 30 .0 45 0 30 0'30 0 0 0 0 o 0 0 0 0 O. 0 0 : '0 · 0 0 '0 15 :., ,9 73 3c;99.73 4099.73 4199.73 4299.73 4399.73 4499.73 -"~599.. 73 ' 4699.73 DIRECTION DOG-LEG SEVERITY VERTICAL' DEG DEG/IO0 ·SECTION· · N 60 E 0.52 18.99 N 60 E 0.00 20.10 N :/9 E 0.37 21.20 · ,* N 85 E 0.26 21.92 S 65 E 0.38 21-°'9 S 65 E 0.24 . 22.04 .- S 56 E S 56 E s 78 S 73 E S 7I E.. S 36 E. S 35 E S 32 E S, 0 E S 0 E S 0 E S 0 E S'0 E S 0 E · · S 0 E 0.07 21.96 0,.00 21.87 0.34 22.23 · . 0.25 0.01 0.",4 . .. 0.25 0.02 ' ' 0 · 49 , " 0.00 0.00 0.00 0.00 0.00 0..00 22,40 22.54 21.97 21.5'8 21.1 . 21.15 21.15 21.!5 . 21.15 2!.15 21.15 21.15 · i. S 0 E, S 0 E S, 62 E 0.00 0.00 o.2 COMPUTED SURVEY S:,TE A,_~..NC- C' "S:''~: SU-3.-- 1651~ ., ..o · RECTANGULAR COORDINATES 'NORTH SOUTH EAST WEST 16.83 8.80 17.48 9.93 17.81 11.65 17.93 12.95 17.37 14." 4 17.01 14.93 16'.52 15.65 16.03 ~ 16.38 ,15.76 . . 17.66 .'15.54) 15'.22 14.16 13.44 12.70 12.70 .. 12.70 12.70 12.70 12.70 12.70 18.49 19.32 20.08 '20.59 21.05 2i'.05 · .21.05 21.05 2!.05 21.05. ', ." · 21.05 2!.05 21.!5 12.70 2!.15 12.70 2[.15 12.50 2! .05 . " 2i.05 ' · . · 2 1 · 43 ""..: '-'- T~U~ ~ }t~ASUX~D .V~RT!CAL u=~T,~ OEPTH 9-13-69 VERTICAL. SECTION COMPUTED SPERRY-SUN WELL SURVEYING .COHPANY '. RECORD OF SURVEY · INCLINATION DIRECTION DOG-LEG· SEVERITY DEG. M!N' OEG DEG/iOO SU.-RvE¥ .DA'E, ALO:,:5 CLOSURE VERTICAL" SECTION ,, SU-3-16513 RECTANGULAR COORDINATES NORTH SOUTH' EAST o WEST : '. '"v'"' ~7oD 73 · "'".', z.E."?, 73 ' · · 5100. 5099-v3 ~ . ' .73. 52:.'3 5=9? SSg5- 5299.73 5/:02. 5399.73 5523. 5.':99.73 53C'3. 559g.72 57m^~. 56g9.72' 5~00 ' ~799'. 72 5~0~ . 5299.72, 6000o' 5~99-'~2 610C'. 60'~9o72 .. 6200- 6199.72 6'300- 62'99-72 6400. 6399.72 ,,o 72 6~-- , 64v,. . 66 ~'~ 6 u,~ - 599-72 6700: 66<)9-72 . 69'C0, 5899-71' ,0C3.. 6¢"~°o70 7t00. 7099.70 0 .0 0 O. 0 30 O' 0 0 0 .0 30 · 0 0 0 15 0 0 O 15 .0' 0 0 15 0 0 0 30 0 15 0 0 0 Q 0 -30 0 30 0 "~ 0 . , 0 ~0 S 0 E 0.25 S .0 E 0.00 S 2i E " 0.49 · ; · ,, S 0 E . o S.. 0 E S 0 E -s DE' ,s o E S,II w. S. 0 W' · S !.0 W S 0 W 86 0 57 S 0 N 56 S 67 ,. s 0 S 0 N, 55 N 53 ,, ,M l~ 53 N 50 E E E ' '. ~ .. E ~ E .' E E E 0.. 49 . 0.00 0.00 0.00 · · 0. '00 · d. 49 0.49 0.25 0.25 0.25 · 0.25 0.25 0.25. 0.49 0,41 0,25 0.00 0 · 49 ,O.OL 0,00 0.02' 21.15 · , 21.15 20.58 20.58 · 20.58 ,:' 20,58 · , 20.58 2o158 : 19.74 ,, 19.74 ' 19.33 , · 19.33 , 19,51 ,, 19,51 .. · 19.47 , · , 19.47. 20.24 20.28 ', '. 20.28 · · 2'0.28 '21.06 · . 21 .'85 -22.65 23.46 12.50 21.43' 12.50. 21.43 11.68 21,75 11.68 11.68 · ti.Os ,' 11;68 !i.68 10 ..83 · 10.83· i0.40 . i0.40' 10.37 .lO.3T 10.i3 · 10.13 10.62 ' 10.45 · 10.45 ,, 10o45 10,95 11.47 12.00 12.56' 21.75 21.75 · 21.75 21.75 . '21.75 21.58 21.58 21.50 21.50 21,94 21.94 22.~0 22.30 23.03 23./.-3 2~. 4'3 2.3.43 24.!4 24.84 25, '34 25,2I %. . .0 J .. .... .;.',.T · "= TH. SLOP SPERRY-SU N WELL 9-13-69 SURVEY 'VERTICAL SECTION COMPUTED ALONG CLOSU?,E SURVEYIN.G. COMPANY ~'.J-3-16513. T~UE : ·INCLINATION ..,EA .%c D V,_.?,T' gAL .- · ":~ DEPTH DEG MtN ~..,.. TH · - 7280. ·7!99.'70 · -'-' '~. -299.70 i .... -, t -4"3. 7399.70 v = ":0 7499 70 T f:.'L:O. 7599,69 -", -..,,"O. 7699 · 68 T.:':"C. 7799.67 79'0. vS"e. ,,.66 ~'~0. 7999.65 ~ '~, -,-' -n 8099 64 .:. -. :,,' lc,,: =..., ~. 3 9.55 ~:330- $299.43 8"~ 00. ~399.35 $5"0.~ 8z'c9.29., .'G$SO. 0599.27 3700. 8699.25 ,..,.:, DO. 87~9,24· 8930. S$99.Z4 9'"00. 8999.23 O: O0 · 90')9 · 22 9 .... " ~ 99 · 21 .- ~tz. ..,) .F ,~uO. 9299.2.0 e.'. '0. 9~99. Z9 ; ~500. 9499.17 · 0 15 0 15 0 !5 0 15 0 45 0 45.. · 0 z+5" 1 0 O' 0 1 0 ' 2: 3O 2 45 2 15 2 0 1 15 · 1 0 · 045 0 45 O45 0 30 1 0 0 <'5 1 15 RECORD OF SURVEY DIRECT DE iON DOG-LEG SEVERITY G DEG/100. VERTICAL SECTION N 22 N 2 N 76 0 ,30 23.89 0.08 24.28 m 0 ' 30 24.57 S 62 S 3 S 18 E o.17 ;-1 0.68 · E . 0.27 24.58 .23.39., 22.49 .'S S S 74 46 0 E 0 ,'70 E . .0.48 E ! .00 22 22.29 22.29 N..46 W' · N !6 W .N 7 E · N 21 E · N 30 E' N 51 E. N 60 E N 60 E · N 76 E 1.00 '1,70 l .07 · 0.78 0.41 0.94 0.30 0.20 S 83 E 0.27 , S 8,'i- E 0,25' N 83 E 0.52 22.76 .25 · 89 30.36 . 34.26 · 37,75 · 41.24 42.35 43.23 43.71 · .44.04 45.04 M 63 E " 0.3'9 46. i2 · . N 60 E 0.03 47.23 N 3 'd 1,05 49.20 · RECTANGULAR COORDINATES NORTH SOUTH' EAST · · · · · . 12.96. 26.37 13.40 26.39. 13.51 26.81 13.30. i 1.99 · , I0.75 · : 10,39. · 9.18 9.13 10.39 - ' 14.58 " · i9.34 27.19 27.13. 27.53 28.79 3.0.04 30.04 28.79 27.59 28,17 WEST · o- : - · · 23.01 26.03 27.40 · 28.28 28.93 · 29.25 29.09 29.00 29.21' 29.80 · 30.46 · 32.64 .. ·, · 29.58 31.32 33.02 34.53 35.66 36.9.3 38.23 . 39. i0 40.83 42.00 43.!3 43.25 -"'0 i T~UE ;':E ,~ SURED VERTICAL uEPTH DE~Tu i i i I ' 91.00. 9599.!l · .O. 9698~'99 9200. 979S.85 'INCLINATION DFG MIN 2 0 2 45 .. 3 0 · · . . · , c'?O0- 9898.72 ' 3 0 ' lOS00. 9998.55 3 15 ~=~0. 10093.42 ~ 0 · o. SPERRY-SUN WEL. L ~C;CO, 10498.14 . 0 45' !0'.50, 10598,12 1 15 " ! ':C.'Oo ~06'=3.07 I 45 ,. 10750. 10748.05 ' 1 45 · .. ':'::'=:'",: THE CALCULATION PROCEDURES HORIZONTAL DISPLACE.v.'',,cNT = R DIRECTI DEG ECORO ON O0 SE D N 22 N 31 N .27 24:4' 28 W 24 W VERTICAL N 12 W N 52 E N 62 E SURVEYING COMPANY SURVEY· G-LEG VERITY EG/!O0 ! .0! 0.83 0.32 0,15 0 0 ..33 1.33 2,93 1.32 N...62 E . 1'.25 N .24 E 0.80 N 12 E · 0.5[) VERTICAL: SECTION · · 51,44 " · . · 53,89 56.88 · PAY,. 5 9-13-69 SURVEY DA'~E SECTION COMPUTED ALONG CLOS',JP, E 60.09 63.24 66.45 ' N 6 E · '0.56 · ARE BASEO ON THE USE OF 84.48' ,FEET'AT NOR 'SU-F-16513 . · · RECTANGULAR COORDINATES -.. · NORTH SOUTH' EAST WEST 68.78 73..97 · 35.87 . 39.98.. 4%.65 ·4.9.43 54.43 " 59.22" ' .. · . 62.20 65.69 . 76.87 · 77.95 80.1'3 83.06 , · 84.48 4i.9~ 39.47 37.09 34.96 32.30 30,17 29.54 34.01 67.33. 37.09 67.95 .' . 38.24 - .. 69.94 3g.l~ · ~ 72.93, · ~9.77 · · . 74.44 39.92 . · · THE TANGENTIAL OR CHORD'MSTHCD ****' TH 28 DEG. 12 MIN. EAST(TRUE)'"' .. ,. ~ ¡ ; ~ '~::".¡~~'..' >.'~, <'~'~ €:Ë" .¡ .. ,. ., " . " f!!!!~,'- ,"''''"'''""".,.,.,,,,,,,,.'''''', .l.~~~~iJ -;~I !~f]~~~~! -~~¡~~¡ f~J.:i~~-;Ji.~;¡1~J:tlfffiIJj,i[£:!I'JI:[~l~¡.-jIt.I~~~1~¡~-!,'~~!1I!-[*J!f~!~1I¡!~!~;lt:~~~I!{f[~:~rI.~~~~-:~ . ' , 1'." , . \. , ' . ': ,:,";' I I : " : ' I ¡ I i I:! I , I I ' , : ' .: ;:' I I I . : ,. I ' :, ; , , !: 1," I I ' I I. " '- -,' -~,-_:._,.. .,' .-',. -- ,',. ..'.: "..: .--......,.:. ;..1.'_-..1.1...... ....'.. .... ','-~ I"""'j',. . ,.... "... :'"'''':''''-'-'''1''' ""',' ";'1"'-~ '1,..'1..:....,., "", . ....--." ; :' : ,!:",'. '.' ¡ "", I I : : I I I ! : ! I I I I ! I I ' l ! : ¡I, I : ' ' ! I ;,: :, ! , I ,: Ii: ; . I I Ii' 'I: ¡ I ¡ . . . , : : ' ' I .. !~~I;:t ~J~~ ~¡ ~:i~~: ¡-{~~~j: f-~~~~:~i ~~1 ~~~-~I~q~l¡1j~lli1~~~!titjtti,~t~lr~~~+i~~J~f.j ~~tt:¡:tf~~~¡ 1íH:j ~~~jt¡-:-~~È 1~¡t;~:.t~ : j : ~':'-=~-':'-:'-: :~~~' u_~ ~,-:-_-: ..~ ':~: -':-':~l'-:-;-::~:~-i=:-:-;~r:-~::~:" !+t:~' :~r: ~:-;-'~' 'IC~~:~:"~ ~~{~~+~II~!i~:~-';- i~~"TFi~-T';-:"!I-'¡: ~l=¡ -;";~~-- ~-T;';" :-~~I':;~ ';-~' ;-:'-~ :-'~ t t , i .~-:~:: :=:..:,::,:,.~ ]~~-:= ,~--,:=::-'~=L::::l-=!,~! :~.TJ:!~ t _~l=C~~'I!~T~L;,~t.t'IJ::I.:rll J~ f[~r:t..' 't-:! .~:=!~ r'~ j:i:r. :::~I:tTJ .tì:i-!JJ~Ll.[r:~.~~r-t.LI:~t~i::~r1t.-:J:~::r,1 . .tTj :.::r~_;=i~:"1 ~ . I',' .:., 1. ',I'. I í I : ¡ :' I ¡I: I ! :: 'f' I: I f I f : I I I t I I ! I, I : :. !' I ' II. :.;: I ",1 . i : ' , I , '''' : ¡ =~~:~::~~I.!=~~~:~~-==!.~~==~fj~~:-!~~,..~~~,!+2~:."~,8~Ítj~[~~=:J1~8tt~,¡Tif~e:~~E1¡ j~=};fi=tl;It.:j;~:ji.:=!,:~;=J~~~3~:3~=~;j (f .' '.:, . " ':" .,:", it:":I!I!1 :1" f!' :¡II.'!:.lllíl 1.1'" ¡!'I.I'S'I:: I,':, - "I'" I --.-_C . ---.. J --"- .~~..__._., ---T.,_,,_-~-'-.-_.I+r.. .,_.. I-..~--.,,_.,...J .c.u'-_.l.._..__._I_-~---I,..~-1 /-'--~___'__h I-I---C-.---.-. -- '4-- < ~-' -~ -~----_.. t ;~, :._;- 0;~.::,~j- ~'.~::~~: _¡..._i- ; ~; ..;., ¡:~:J- ¡.~.: -~-~.LcLt.J.~1~~'~-1-c¡j:J - ¡ '~~~.t:r:!.:.I-~~- ¡.:li~çtJJ ,I::' ~ -~~çJ' !-:i~L L~,::'-¡ -J:i::::'_!_' L~':~:~;:: "-' -'j . ~ ;~~.=~0::~:_~¡~~ji;I ¡~~få¡i~~~1f~~J~:..~.~itU'ß~~tI;'En:t¡~Æ~Ij~3~E,n~l,",,¡.'~,~,~,','~,i,~.'.!:,;,',f,.r,.,:,;~",;.',;.r.,~.Y. .,~,i~3;¡~J~¿~L,:,-,{:lr: 8 ~~:.¡~¡~F.3~!.~ ~.~:~::Hi~~~ ~ ¡ ,------_t_-- --''''---r--r----.--'''-- ",' '" "', ,1_-.-.-...,_,.......,..,...-" , ..~' l.-_.___I____._L..;------J i~r~II~~~.~~I.~ 1 f -;;~; ;~;, ~ ¡.~:~;. ¡~;~~;; =~;..! ~+.~g~t~f.rt.t~t. ; ~~1iI-¡.f;;;t¡! ~i;Hj~~i~.::~ ¡~j~: ;Lr 1:1 £(1:;:11 ~~~;¡~i~~~HJ;[~~¡~_.¡ i~.¡}t:[;{:i~~:¡ .:.~.=;: ~j~;J. :~j .~. . . : r -- - -,.- --.". -., - - ¡ .. - ...-. --,.. - -., : ..- .._-,. ._- ,._,-,. ! ..,-,... --rr T' '¡ I i "T" li -.-¡ ,.. i r' .,-, I~'.. -'. d .. r ,_. ._.- ,. ¡ -:. '-'-1-, -,. _... I. ,., ,.., .'--1 . - ¡...--'. I ,~...- -" ..- ... j \5' ¡ .' . i I I . .. . . ~-_.,--_.__._-- ._..__.._---..--.:.~~.,!,:-_.- .._..__._-.._---~~~7:~~-~.~~ December I0, 1973 Well P&A and Iocatlon cleanup for f Ina I i nspect~on - ~ ~1, Sec. 7, Ti2N, RI4E, U.M. - Exxon 0II Company P. O. Box 440 Anchorage, A I aska 99510 Dear Sir: We understand that Exxon has. assumed operator status of subject lease. This transfer of responsibility from Hamilton Bros. Oil ~Company should be reflected in our' records. It 'is obvious that a gmat dead of work has been .performed at this location since our pre~lous Inspect'ion visit In August of '1972. If ls also evident from several of the photos that ad'dltlonal cl. ean.up work will be required... As required by State Regulation 2t03 Wellhead Marker, the .christmas tree should be removed and replaced, by a proper P&A marker ~h.lch could be directly .welded to a cappl.ng ~l'angeon the wellhead. Fillets should be used when a P&A marker Ds Installed like as .we have found from past experience that they are quite easily broken down. by the Caribou., State t;~lulation 2108 Location Cleanup,. would require that ~he cd, tar be either removed or filled and covered. The refrlgera.tton pipe around the cellar would llke~tse requlre covering or removal also the mouse, and rathole casements would either require cap welding and covering, ormremoval., Additional hand pick up of miscellaneous trash and debris, both on and off the location pad will. be necessary.. The downhole abandonment of this will .was completed September 2, t973 according to our records and even though a. lot of ~or.k has been done on this location, and it appeaes t.hat ~he remal.nlng work to be done could not be accomplished prior to next summer at the very earliest. Perhaps you have already .made plans tot the above.mentioned work but ~o prevent another years delay of final abandonment of this location we thought is necessary to bring these, details to your a~entlon. Will you please provide documentalon of opera~orshlp of subject lease and your plans for coaple~'tng., the abandonment of this well and location. Thank you, Homer L. Burrell Director , D-,,,R,,-,~NT O, NA, ~,~ Rt 'uRO/ES' DIVISION OFOIL AND GAS~~¢~ TO= ~Homer L. Burrell ~ D i rector I ~ THRU: O.K. G i ! b reth ~~ Chief Petroleum Engineer ~o~: Lonn i e C. Stol ?h -2 Pef~ leum Engineer DATE -' . November 30, 1973 SUBJECT: ' Inspection of Various Locations on the North Slope Tu.e.sday~ September 18, 1973- I departed Anchorage by commercial aircarrler, arriving in Fairbanks at 7:50 a.m. Due to continued bad, foggy weather on the North Slope the flight was unable to continue. Following a six hour delay, the airline returned me to Anchorage and the flight was rescheduled the nex~ day. ., Wednesday, Sept'ember 19, 1973 - I departed Anchorage on the rescheduled flight but the plane was unable to land at Fairbanks due to fog and rain. The flight returned to Anchorage fo.r fuel and then proceeded back to Fairbanks and on to the North Slope arriving at Deadhorse in the early afternoon. I immediately made contact with the' Gay Airways Inc. helicopter pilot and we decided the wea- ther was sufficiently good and the daylight adequate for photos. We took off . at 2:20 p.m. and proceeded to the Mobil West Stalnes location, approximately 50 mi les east of Deadhorse.. On the way we flew' directly over ~wo other loca- tions. Mobl I's Mlkkelsen Bay State #1'3-9-19~ Sec. 13, TgN, R.19E, U.M. This well is approximately 30 mi les east .of Deadhorse. Mobil has not completed the abandonment clean-up work at this well site where the well (item I) was plugged and "Abandoned" September 30, 1970. Photo #1 (see Appendix A for all. photos) shows a large stack of mud supplies (item 2) beyond the open. pit (item 3). Other equipment (Item 4) is stacked around.the perimeter of the pad. This drill · site is vlewed from the west toward the east.. The gravel airstrip .(item 5) and. ., connecting road is in the background. ,. Exxon's East Mikkelsen Bay State #1, Sec, 7, TgN, R21.E, UBM~ As we passed on' the south side of the this dri I.I site, I took Photo #2. This photo sho~s the' rlg, still standing over the well with al'l equipment and the camp .still intact at this location. I was informed by the chopper pi lot that this camp had recently been broken into by bears and as we swept past' the location ! could see the open doorway at the east end of the campsite. (I passed this information to the rig owners who went in tw° weeks later and re-. boarded-up the camp) This well was plugged baCk to 3000' and "Suspended" for 'observation of permafrost on June 9,. 1971. . . · Mobi I's West Stalnes State #!8-9-_23, Sec.~:_lS, T. gN,. R23E, U.M. As we approached this lOcation directly from the west I took the first (Photo'#3) of the nine attached photos (nos. 3-11) of this location. This aerial shot of the West Staines State location, shows the well pad..(item I), pits (item 2), supplies (item 3) stacked on the pad and a building (item.4). We circled the , ' ,' ' . ',.":' I~IN*i'ED ~.¥ 'ri.,[ 8T~,NDAI~O REetel'~R OO,,PAa'f.' U.~.& ZIPSET'~) Homer L. Burrel I -2- November 30, 1973 location, landed and I took Photo f/4 looking to the south showing the wellhead marker (item I) and piles of supplies (item 3) on the south perimeter of the pad. Photo #5, taken from the west si de of the wel Ihead, looking across to the east, shows the capped wel Ihead with the attached P&A marker (item I) the rat hole (item 5) and the mouse hole (item 6) casements were still in place along with the cellar (item 7) and the pilings (item 8) for the rig. In the background can be seen neat Stacks of supplies (item 3), equipment (item 9), a building (item 4), and a fuel revetment (item I0), with a pillow tank rolled up on the ground. I walked to the southwest corner of the pad and took Photo #6, showing a stack of tubing and' casing (item I) located on the west edge of the pad , (item 12) with its uneven gravel and, in the foreground, a stack of fuel drums (item 13), some empty and some full of fuel. Also a box containing a pillow tank (item 14) and a large stack of wood piling, (item 15) is in view. Photo #7 was also taken from the stack of tubing and casing (item l l)~looklng 'across to the east. It shows a stack of miscellaneous pipe and metal supplies (item 16) and across the plt area (item 2) a large stack of mud supplies (item 17) with'the bui Id.lng (item 4) to the left side. Closer examination of the stacked mud' ' supplies showed them to be l'n very poor condition with many of the sacks burst' or the container had-leaked sufficiently to al Iow water and moisture to get to the mud which had burst the sacks due to swelling. Photo #8, a view from the south to the northeast, shows a large stack of pi ling and boards (item 15), the wellhead and marker (item I) in the background with other stacks of supplies (item 3) and the building (item 4) beyond that. The helicopter can also be seen near the lake on the north edge of the pad. Photo ~9, a photo looking to the northeast along the north edge of the pad, shows the 'fuel revetment (item' I0) with the.gravel berm (item 18) partly covered by a plastic liner (item 19) which' has been partly burned along with some boards. The remains of the boards and liner are now trash. A rolled up pillow tank (item 14) can be seen in the foreground .Photo ~lO.was taken from the southeast corner of the drlilsite pad looking from the northeast across the pad at the area where the drll ling crew camp (item 20) had been located for this drlilsite. Scattered and ungraded gravel areas are... evident in this photo as well as scattered boards (item 21) and a trash pile (item 22). 'Photo II was also taken from the vicinity of the southeast corner 'of the drillsite pad, but it is looking back over the stack of deteriorated . mud (item 17), across the tundra to the south. In the background can be seen' pieces of plastic, paper and trash (item 23).' The pit area can also be seen. · in this'photo, it. appears to be just another lake, (item 2).. .. The nine photos at this location show the progress o~ the work to date per- formed by Mobil's crews. This well was plugged and "Abandoned" on July 2, 1971 .and awaits clean-up so that the final location inspection can be made. Major equipment and materials have been pi'led in neat stacks large enough so they may be located in the winter time' when the frozen tundra wi !1 al. low hauling to a permanent' 'location. There appears to' be much work that hasn't been done, such as hand pick-up of'trash and debris. This work will have to done in the summer time when the snow isn't there to cover the debris. The wel I- head work has 'not been completed, no attempt at grading the pad, filling in the cellar, pulling the mouse, and rat hole casements, covering or cutting up. the pilings, leveling the fuel revetment or filling in the pit area, has been attempted.. The paper work on this well, based on a P-3, approved July 15, ... 1971 indlcates that clean-up work was to have been performed and supplies Hcmer L. Burrel ! November 30, 1973 moved out by the end of fall of 1971, as the weather permitted, it appears we are at least two seasons away from the final inspection of this location where the well was plugged 2½ years ago. I recommend that we contact the operator with regards to his intentions and timing to complete the final abandonment of this Iocatlon. We arrived back in the vicinify of the ARCO's base camp at Prudhoe Bay at 3:55 p.m. To the northwest there appeared to be enough light to continue inspection and photos so ! had the pi lot head for the Point Storkersen well. As we flew past the Point Mclntyre landing strip ! noted the tremendous amount of clean-up.work that had been performed In that vicinity. Large stacks of oil drums had been stock pi led in neat stacks. Trash and debris had also been picked up and pi led. I noted a crew of three men working along the coastline at the time we flew past and I saw more pi les of drums and debris stacked along the beach area. ~E. xxon's Point Storkerse'n #1, Sec. 7, TI2N, RI?E, U.M._ When we arrived at this well and circled the location I was amazed at the remarkable clean-up job that had been accomplished for this had been one of ' the unsightllest wel.I locations on the North Slope area. As we swung around the location I took Photo #12 which was the first of eight photos (nos. 12-19) taken at this. location. This photo, taken looking toward the northeast, shows the wellhead (item I), the fl lied in pit area (item 2), a neat stack of mls- cellaneous supplies (item 3), and the old camp area (item 4). We landed and I quickly took Photo #t~ looking toward the east showing the wel I. head with the christmas tree still in place ( item l ) with all outlets~both on the 'cas- ing and the christmas tree, closed with blind flanges. Cellar boards (.item 5), are still in place along with refrigeration pipes (item 6) which can be seen sticking up around the perimeter of. the eel lar, Both the rat and mouse hole casements. (item ?) are still in .place. Pho~o#14, taken looking east along the south edge.of the gravel pad, shows the location (item 4) of the old camp area. .This area was originally one of the dirtiest areas of the location. It is now remarkably clean; however, there are still bits of trash (item 8) such as paper cups,' cans and such that need to be picked up. Photo #i5 is a view of the wellhead' (item I) looking toward the north. This picture is dark even with the camera open to the widest setting. Several things can be seen how- ever, in the'foreground are some boards and also a steel band sticking out of the gravel (item 9). These items obviously were not picked up after the back draggi]ng was complete. Item !0 Is gravel that was never graded level. Photo #16 was looking .to the east from the edge of the gravel pad and shows the lake (item II) east of the location, miscellaneous debris (item 12), both in and around the lake, and one of the buildings (item 13) at the Point Mclntyre landing .strip. Photo #17 was taken looking toward the northwest and'shows the Iarge neat s~;~'c'l~L Of mi sce I I aneous suppl i es ( i tern 3) that are to be re- moved from the location and the northwest corner of the gravel 'pad (item 14). Photo #18 shows two pieces of debris (item 15) located just off the north- west corner of the pad. Photo #19 shows the wellhead (item I). looking to the south and the large neat stack of mlscel laneous supplies. (item 3). *"" ..,'" , f'; / /'"' t" . /"" f . Homer L. Burre I ! --4-- November 30, 1973 This well was plugged and "Abandoned" September 3, 1970 but location clean-up for the final inspection has yet to be accomplished. It is obvious that a great deal of work has occured at this location since my previous inspection here in August of 1972; however, the work is not complete. It is evident from several of the photos that additional hand clean-up, work is necessary both on the pad and in the vicinity around the pad. The weilhP, ad itself, is in an unsatisfactory condition with the christmas tree being left in place. It should be removed and a proper P&A marker instal led. The cellar should be removed and or filled along with removal of all the refrigeration pipes and mouse and rat hole casements. The stack of miscellaneous suppl les will have to be removed prior to the final inspection. It is recommended that the operator be contacted as to the timing and the amount of remaining work so that the final inspection can be performed next summer on this location. We departed the Point Storkersen location at 4:38 p.m.. It was too dark for any further work of this sort, however, it was still light enough for visual Inspection so I had the pilot swing over the Kup Delta location which is very near to this location. (The possibility of this.coastal area being fog bound the next morning was very imminent.) As we swung over the location .I could see that a great deal of clean-up had been done here since my last visit. It appeared, however, that the 30 foot aluminum mast that had been left on the location last year was still there. It does not belong to the operator and he doesn't consider it his responsibility to remove it. In general the location looked good and we swung back south and headed for Dead- horse, arriving at the Gay Airways helicopter landing area on the Deadhorse airstrip at 4:55 p.m. After making plans with the helicopter pi lot for an early morning departure I drove to the'Mukluk .base camp and got a room for the even ing. At dinner I met Mr. Tom Moseley, a geologist with the U.S.G.S., and' found out that he had made plans to use the same helicopter for the next morning. Mr. Moseley was recordi ng temperature data through the permafrost interval in many of the we l Is that had been made ava i l able to their use on the North S i. ope. .Thursday,. Septemb. er ~20, 19.7.3.- We drove from the Mukluk base camp to Dead- horse airstrip and after loading Tom Moseley,s equipment into the helicopter we took off at 7:15 a.m. and headed for Prudhoe Bay where we landed 'at the Prudhoe Bay landing area and picked up Mr. Frank Hunt, an Arco foreman, .who was to help Mr. Moseley with his survey. ARCO's 'North Prudhoe .Bay State #23-12-14,_.Sec.. ,23,~ TI2N.,...R. 1.4E;, U.:,M. We then flew north to the ARCO'soNorth Prudhoe Bav State well where I took Photo #20 an aerial view of t'h~ location from the south. This photo sh~s ~-e well house (item I), the drilling rig matting (item 2) and the open pit area (item 3). After a brief landing to drop off the two men and their equip- merit we continued to the northwest and soon arrived at the Kup Delta location. Homer L. Burrel I November 30, 1973 Continentai's Kup Delta #51-1 and 51-2~ Sec. I1~ TI2N~ RI3E~.p.M. I took Photo #21 from the air as we approached the location from the south- east, the Beaufort Sea can be seen to the north and northwest. This photo shows the wellhead (item i), the filled pit area (item 2), the camp area (item 3), the 30 foot aluminum tower (item 4) and tracks made by a roi I- agon (item 5). These tracks are not as damaging as they might appear, for they only mashed down the grass which appear in the photo to be a heavy deep track. Two wells were drilled from this location, but there is only one surface hole because the second well was kicked off at the 3,000 foot level after the first well had been abandoned. We landed and I took Photo #22., looking back toward the northeast showing the wellhead (item I) with blind flange, the 30 foot aluminum tower (item 4) and the cellar (item 6); the helicopter can also be seen in this photo. Photo #23, was taken looking toward the northwest from the edge of the old pit area and shows trash (item 7) scattered over a considerable area. Photo.#.2.4.~ was taken from the woutheast portion of the pad looking back toward the west and shows the wellhead· and cellar (item !) and some trash in the foreground (item 8). Photo #25, was taken on the tundra looking north along the west end of the pad and shows some 3" X 12" boards that were left. embedded In the 'tundra (item 9). This well has .been "Suspended" since August 26, 1970'and considerable clean- up work has been performed here since my last visit, in August of 1972. We departed the Kup Delta at 8:55 a.m. and headed west for the Milne Point loca- tion. Placid's Plagham Beechey Point .Supply OePO~..[...Sec..14,.. ~...I..3N,. RI..I~, U.M. As we flew west along the beach we soon approached Placid's Beechey Point Supply depot and I took Photo #26, which shows the.gravel stock pile (item I) six full pillow tanks of fuel (item 2) and a large.supply of casing and pil- · ing (item 3). This location seemed to be i'n the same clean condition as on n~ previous visit last year. Continental's Milne Point #18,1, Sec; .11, ..T..'I3N',. RI'OE,~ U;M._ After 'flying slightly past the Milne Polnt location we circled back and approached it from the southeast and I took Photo #27. from the air which shows the we l I- head (item I)~ the fuel revetment with two pillow tanks (item 2) and the level- ed pit area (item 3). We landed and I took Photo~_#28, looking toward the northwest, showing the wellhead with blind flanges on the christmas tree (item I) and the cellar and rig matting still in place (item 3). I then took PhotO_#29, looking west along the north edge of the gravel pad, showing the fuel revetment with two full pillow tanks in place (item 2) and a wellsign on the edge of the pad (item 4). Photo #30, .was taken on the east edge of the gravel pad looking north. It shows trash and debris scattered off the north- east corner of the pad (item 5). This had been the location of 'the crew quarters. Photo #31,'is looking from the middle of the pad toward the north- west and shows scattered debris on the northwest corner of the pad (item 6).. This well was "Suspended"'July 18' 1970 and considerable clean-up work had been done slnce my last visit in August 1972. .. We took off at 9:25 a.m. and headed .west for the Col'vi lie River delta area. Homer L. Burrel ! -6- November 30, 1973 Gulf's Colville Delta State ~i.t Sec. 9, TI3Nt. R.6E.~. Ll.M. There was very little to distinguish this location Since it is on the Colville Delta, which is semetimes under water at high tide or when the river runs high. We soon located the well and ! took Photo #32, from the air, looking toward the west which shows the wellhead (item i) and a stack of material (item 2). We landed and ! took Photo #33, looking toward the west which shows the welihead with P&A marker in place (Item I), a stack of material in the background (item 2) and some pieces of trash which were plastic material (item 3). Photo #3--4 was a slmi lar view, taken from the north looking back to the south, showing the wellhead..P&A marker (item I), a stack of material (item 2) and several pieces of plastic trash (item 3). This well has been plugged and "Abandoned" and this was the final inspection on this location. Although there still remained a' small stack of materials, mostly boards to be re~noved from the location, I filled out a Field Trip Inspection Report (attac'~'e'd) statin.'rg .that the final .inspection would be approved when these items were removed..{commu- nlcati'on with Gulf and a duplicate photo of this location resulted in the re- moval, of the trash and materials and a formal release of the bond on this lo- cation was approved). ,. We departed the.G9lf lo. cation at I0:00 a.m..and headed back 's.ouf'l~ast where we soon flew past Mr. Bud Heimricks house and airstrip., located' on :~he C°l- vi lie River Delta. I took Photo #3.5 as we flew past showing his house and miscellaneous buildings (item I), his ~irstrip (item 2) and a large stack of fuel barrels beyond his house (item 3). Un ion's Ka I ub i k's Creek Unit ~ I, Sec. !0, T!__2N,, RSE,, UL..~~. This well was plugged March .27, 1970 and is now waiting for clean-up and final' location approval. Mr. Helmrick has a contract to clean up this 'location. As we flew past, I took Photo #36 .. showing the wellhead wlth marker (item I), the pit area (item 2), supplies and equipment still on the location (item. 3) and the location of the rig stacked at the mouth of the Kalubik River (item' 4). As we proceeded.back t° Deadhorse I took Photo #37 showing BP's new P'rudhoe Operations Camp under construction. The installation construction crews were at work putting it together. It shows the main building (item I), tanks in the background (item 2), and the Spine Road (item 3). Just a little ways down the road we came to the BP Central Power Plant where ! took Photo #.3...8, showing the power plant under construction (item I), the transfo~ners (item 2) and the gas supply well location in the far background (item 3). We arrived back at the Gay Ai"rways helicopter landing site at the east end of . the Deadhorse strip at 10:37 a.m. and I quickly made. arrangements to depart Deadhorse on the Wein flight at .11:00 a.m. I noticed the drilling rig had been moved from the location of the Socai well #31-25..at Deadhorse and a new control tower had' been constructed just to the west of the old Socal pad. Some suppl ies have been stacked up around the wel Ihead but all of the rig equipment, debris and trash have been removed. The north edge of this pad had at one time been a regular "dump ground" for camp trash. Homer L. Burrei I -7- November 30, 1973 I departed Deadhorse on the 12:15 p.m. flight and returned to Fairbanks and Anchorage by 3:00 p.m. On this field trip i took 38 photos of ten different' locations on the North Slope coverlng an area from 50 mi les east of Deadhorse to 55 mi les west of Deadhorse and as far as 20 mi les north of Deadhorse. This field inspection trip has already resulted in the final approval of the "Abandoned'~ Colville Delta location (Gulf) and it has shown the degree of clean-up work that has been performed by operators on other locations, which gives a good idea of the work yet remaining to be done. It Is recommended that we talk to certain operators concerning work remaining undone where wells have been plugged, such as Exxon's Point Storkersen and East Mikkelsen wells, Mobil's West Stalnes State and Mikkelsen State wel Is and Unlon's Kalubik Creek well. Attachments APPENDIX A Attachments PHOTO NO. SUBJECT PAGE NO. 3-5 6-8 9-11 21-23 24, 25 26 27-29 30-31 32-34 35 36 37,38 Mobil's - Mikkelsen Bay St. #13-9-19 .............. I Exxon's - E. Mikkelsen Bay St. #1 ............... 2 Mobil's - West Staines St. # Mobil's - West Staines S~. # Mobil's - West Staines St. # 8-9-23 .............. 3 8-9-23 .............. 4 8-9-23 .............. 5 Exxon's - Point Storkersen # ................. 6 / Exxon's - Point Storkersen # ....... ' ......... 7/ Exxon's - Point Storkersen # .... 8/ Arco's - N, Prudhoe Bay St, ~23-13-14 ....... '9 . Continental's - Kup Delta #51-1 & #51 -2 ............ !0 Continental's -. Kup Delta #51-1 & //51-2 ............ Ii Placid's.- Beechey Point Supply Depot ............. 2 Continental's - Milne Poin± #18-1 , . ...... · ........ 3 Conii nenta I ' s - Mi I ne Poi rli # 18-'1 .... ' . ,. , . ....... 4 Gulf's - Colville Delta St, #1 , , , . .............. 5 ., Gulf's - Colvil le Delia St, //! ....... ' ' , ....... 6 Union's -'Kalubik Creek Unit #1 ................ 7 BP's - Operations Camp and Power Plant ............. 8 12 14 ~'.m~~~-~ ~ W-~~~~~H_~- ---~ 15 ,'" 17 18 19 ,f) ,\" ;, , ~' --J ~i' HAMILTON BROTHERS OIL COMPANY 1600 BROADWAY . DENVER,COLORADO 80202 Mr. Hoyle Hamilton Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 94501 Gentlemen: Please be advised that an Induction-Electrical Log was not run on a two-inch scale on the subject well. Yours truly, HAMILTON BRarHERS OIL COMPANY f'1 J1 fI ~/J/\ - ~~~ Donald C. Herron Chief Engineer DCH/ca &ttrcEI'E OCT 5 . . !DJ DIVISION - . 1913 . vP OIL ANCIiORA.G~NO GÂ$ .;I, i TO: ALL JOINT VENTURE PARTIES Continental Oil Company P.O. Box 2197 Housion, Texas 77001 (713) 225-1 511 RE: JOINT VENTURE AGREI~IE}~ OF }~RCH ].2, 1969 ALASKA STATE L~SE ADL 34623 PT. STORKERSEN LEASE Gentlemen:' There being no dissenting votes, Exxon Company_, U.S.A. will, ef~ective_imme~tiat, e.~v,_as~sum~ oDexa~/oBs of the cautioned lease under the Joint Venture Agreement. s very true, '// , · John R; Hultman . Supervisor Alaska Task Force copies to: attached list All Joint Ventur(" ~rties June 1, 1973 Page -2- Ashland Oil, Inc. P.O. Box 18695 Oklahoma City, Oklahoma 74118 Attention: Mr. R. D. Gordon Ashland Petroleum Corporation P.O.. Box 18695 Oklahoma City, Oklahoma 74118 Attention: Mr. R. D. Gordon Cities Service Oil Company 1600 Broadway Denver, Colorado 80202 Atte~ion: Mr. Bob Pasque ,/ E~X~on ~Ompany, U.S.A. ~4800'Avenue of the Stars' · Los Angeles, California 90067 Attention: Mr. George B. tlickok Hamilton.Brothers Oil Company o 1600 Broadway Denver, Colorado 80202 Attention: Mr. Frederic C..Hamilton Highland Resources, Inc'. O 1201'San Jacinto Building Houston, Texas 77002 Signal Oil and Gas Company Golden Center I O ~800 North Loop West Houston, Texas 77018 Atten'tion: Mr. David A. llatcher Signal Oil and Gas Company P.O. Box 2828 Long Beach, California Attention: Mr. R. M. House Sun Oil Company 4151 Southwest Freeway llousto~, Texas 77027 Attention: Mr. W. T. Storie, Jr. Union Pacific Resources Corporation c/o Champlin Petroleum Company P.O. Box 9365 Fort Worth~ Texas 76107 Attention: Mr. Neal L. tlurley Mr. R. K. Aaker, CONOCO, Houston Mr. J. A. Wilkerson, CONOCO, Houston Mr. F. E. Ellis, CONOCO, Houston Mr. J. W. ~cReynolds, CONOCO, ?onca City Mr. John Bond, CONOCO, Ponca C! ty Mr. Lee Drown, CONOCO, Ponca City Mr. Duane Barrels, CONOCO, Anchorage O~'.Ov1B STAT: of A.' .. SK~. DEP,.', '~EN~ ' --' ~."'L..'~AL P~SOURCES DJ,:V ON L- v, ~ ^,up GAS . ,/.'i,,/,! ,,,~ ~[:i:'i ? ... "?o1~,:~ '..--~,gl neet ,% . DATE ,'....,~" 13, 19T.. : ...... Trlp R~po~- ' - Ir :.~,2~:'/ '.-'- BP-Hell '. C-... ,i~-:v,... ..';. ".a~e Abar, .'.~d ' Luc:-'::~;.:'.' Clean-upH~.:. ', 2'~o~';'.~;':; - Poi nt S ..... rk,:.-" ..: :. ":' .:'::nes..'....,?_ Aprl 1~4. 1973- I departed Ancnor~ ~.',' 7:0(:: ,,'.,1 for ~he North Slope. The purpose of Th~ tri:; ~:::,s to check :..' '~'e~';' ...ti i llng ~c-.:-Ivl,~y and othe~ ~peratlons In ~hat ..; ,-~..~ ,.:.., .. .... .~ f~c.:[ ~'[~/ ;[ still ac?ivy:, as '.",dlcated b'~. ir~s':':,.';:..:~;~t ~adlnos .,'..~vlr.,. ..... ,,~n b ',,, . ..' ';~o ~r~e~ ~n ?he fie~, ;:.,.':, I drove nom'hw~;'::' ,,...'.: ~e Spi~ ' Rc i notlc.::::J ~" '~'' ,'*ha, ?,.:.:::.:~ gravel was ;ei;,g hauled~ pla~o, :,:....,.'ead, and a~p~'.... ?;.,~ ~ .,. :'."::,t ?~:. ~..~,.:.'* ";t.~fral Pad No. 3. T:'~ls pad Is n~ o~:.o~ated by Ar,:...;... .,'t a~'-~ ,;x'?en~,,' ":'h;~ pad and laying a bern for a msen,~' ~lt adja~,. .... . '. p~.:::.'..,;::"epa~a',":,.~.?, ~o drilling a 5-spot pa~e~n of s~',a~ ~ ~ells to ..,,. ..... ,,.' gr~.we~ ~'-~"'~ o¥' '~';he fu{'ur'e BP electric po~er gen~'.~:'~'.. ,:.:::;-: s?~:."~lon ha0 .:,...-~ ".' '~d of ~;o~' ar~ ~: s:':,ai I cre~ of surveyors were s~;-',:.n9 s~akeso ro¢. ..;., ..... ',~ '~',~ ,'-.'!'~'~ - ~'~o., C-4 develop;;;~,.,";' ~:"~,'lng well. I ~t ~ I I ~' .~' ..:. · [ ~';~er, Oon R;~so., and the Bri ~';...:~:,:':.,.off t~l pusher, Evere~ '...:.'.~r:, T'.?~ .:;few ~as pu~l[~'; ~e dtllls'; .... ?:::.~j' out of ~ "~.~' .';.~. mpl~.::~'= ?n,:~ ~u~,'. '.. ~.'-;,;~ at 5,529' [r~:~,,.~ured dep~; .~" 5,077 i~r;a verti~ ,,;~.:;~.. h~....., p ~c .. .,; :; ~ re ?~;?~d ~e blow, out prevente~ ~.;'u~p~en? ~as? Sunday....:'.,fl so i r~, ..~;,sted a BG°E operation test, ~n Reese beca~,e ;nvolve.,.... ~roup ~':' ...P executives ~hlch ,-~ere finn In for a fts~,:: tou~, so ~o~er :.:%"e ~e a grand tour c;: ~e ~p, shops, s; .,:. :.:.~.;; ...";le t;:..~t., .::~.,ed p',., ;,ng the pipe ~T of ~e hole. W~-~.'.. th(;: ~'; c:."..~:: ,:;.~'~: ~, :- s'.. ..' ~e '.;~;,:, ~ey cl~ed and ope~d ~e ;t.'yc;"~'~ wh'ich ,.=.:~., ~::.;~u:~ s...'~ · '-...: d~t., ~ rig flor. Then ~e last drl ~, ~ ~i la',* w;,:.,~, r,:m.~':ve~ aha, wlt~ ' . .:.a Ir.. ":,,e hole, the bllnd r~s and Pit. .... r~s war,:: .,;.':..,~..~;~ and · '.:in v.': ,:;aw ~e BOP~s cl~e fr~ ~e r: '. flor. ~v......' .;: ...... e~osed ..'.;d .~ ke[, ',~ck. ~e ,:.becked ~he flor va;,:;~s and w~r~ :..'.;c:.~ ~,~:'. .p~ : .... · ..., oper' ..::-.'..~ thes~'~ v'::~:ves. Eve~ then s:~ed me *h.~ ;':.,.:..',::.';~ :', ....'... ,5'::~t~, c;~oke ma[~;~old, ;5~)P st~k~ and ~s~lat~ f{ ~;.... :.,;i~' ,'... Ho'~e r L. Bu rte I I -2- April 13, 1973 [':e looked at fha mud return flow m~fer, mud level Indicating system and gas indicators. Everett then demonstrated the use of the panel on the floor assoclated with these safe17 devlcos, Includin.Q testing of the alarms. I visited with Everett and Don Reese, and filled out the Field ~nspectlon Report regarding Inspection of BOPE and drllllng operations. I ,qave Don Reese a copy of the report, mai led a copy to A. K. Howard, DP Operations Manager In Anchorage, and a copy Is al~ached to this report. i drove by the future EP ope~atlons camp site. There was a huge crane, electric power plant., and a lot of other equlpment Indicatlng some con- struction actlvlty. There were no workers on location at the tlme but some steel pi Ilngs had been Instal led and It appeared that others were in the process of being Instal led. I drove by BP Gathering Centers No. I and No. 2, then to the end of the malntalned road at ?he Rivers construc- tion camp. ~4ost access roads to drill sites and gatherlng centers looked accessable but were blocked by locked chains across the entrances. I returned to ~he base subsistence camp for supper. .T_.h.ursda¥, ^p~!l._5 I.~.[~.7.~q7~- I checked out of the base sub.slstence camp at 7:00 AH and drove to Deadhorse. Gravel was being placed at a rapld rate at the west end of the Deadhorse al. rstrip. Also, a road rlght-of-way had been cleared of snow and surveyed which wl II shorten the dlstance to Deadhorse. I drove by the Arco HI [ton base camp and by' Arco Flow Station No'. 2. Beyond the flow station to'~he northeast, a new flow line road had been constructed. This eXtended to a new gravel flow Ilne manifold pad adjacent to Arco Drlll Site No. 4. I proceeded on to the Prudhoe By dock. There was a new ice road extendlng off the end of the dock and onto the Ice In the bay. I followed thls road about 15 miles to the end which was at the Haml Iron Brothers-Point Storkersen No. I abandoned well. location. Nabors Drl Il'lng Company had a crew cleaning up the location wi.~h a 13-8 cat,. a fork Ilft, a front end loader and a blg truck. The Nabors drll Ilng rig had. been purchased by Brlnderhoff, who moved It and stacked It at the A~ood storage yard between the ~ukluk camp and Dead- horse. As a polnt of Interest there is currently one rlg running and · ~bout 18 rlgs stacked on the North Slope. At thls location Nabors was digging barrels, sacks of drllllng mud, steel, timbers and other mlscell- an,3ous Junk out ot the snow. The noncombustible large Items were belng back hauled to Prudhoe Bay whlle the tlmbers and other combustlbles were being burned. Some Junk will be left under the snow which will requlre ftnal clean-up next summer. This crew will finish their work Thursday, Aprll 6~ 197~. I drove back to the Arco HI Itoh and looked up Bud Lund, the North Slope operations superlntendent. He said Arco's only effor~ at this time was constructing gravel manlfold pads, flow line roads, and extending the BP Central Pad No. 3 preparatory to drll I.Ing the §-spot pattern of temperature and subsidence observation wells. ~;c~er L. ~urrell I returned to the Deadhorse airport arrivlng at il :20 AH an::J left plck-u~ r.io. 2-31 there for l~ukluk ~o pick up later. I doparted Deadhorse by Wien aircraft at 12:15 PH for Anchorage, arriving at 3:00 in sumary, this field trlp was made to keep abreast of North $1op~ drill- lng and operations activity, to keep personal contac~ with operating per- sonnel, and in general 'to perform housekeeping chores. In partlcular, bio,- out preventer equl pment was Inspected and BOPt s were operated at the BP No. C-4 dri I ling well. Also, abandoned wel I location clean-up efforts were checked at the Hami Itoh Brothers-Point Storkersen No. I. .. Febrqary 22, 1973 - / ' TO: ALL JOINT VENTURE PARTIES JOINT VENTURE ACREE~fENT OF MARCH 12, 1969 ALASI~A STATE LEASE ADL 34623 ~;en t 1caen: This letter will comprise notification to each Joint Venturer under the Operatin~ Agreement attached as Exhibit "I'.' to the cap- tioned Agreement, as sho%~ on the attached distribution list, of the resignation of Hamilton Brothers Oil Company as Operator. We are aware of the required ninety'day period durinE which present Operator must continue in that capacity; however, if any successor Operator selected is willing to assume operatorship at . an earlier date, we.wou}d be happy tO make'our resignation effec- tive at the earliest apRropriate time. Very ~,.~1o¥ yours, Frederic .C. 'llamilton President BL:Jt 'e Ashl:,ud (}il, l~c. P. O. Box 18695 Oklahoma City, Oklahoma 73118 Attention: Mr. R. D. Gordon Si. gual 0[1 and (;as Company P. O; l;ox 2828 Long Beach, California Attention: Mr. R. M. }louse Ashland Petroleum Corporation P. 0.. Box 18695 Oklahoma City, Oklahoma 74118 Attention: Mr. R. D. Gordon Exxon Company, U.S.A. 1800 Avenue of the Stars Los Angeles, California 90067 Attention: Mr. George B. Hickok · Continental Oil Company P. O. Box 2197 Houston, Texas 77001 Attention: Mr. R. K. Oaker Union Pacific Resources C'orporation c/o Champlin Petroleum Company -' P. O. Box 9365 Fort Worth, Texas 76107 Attention: 'Mr. Neal L. Hurley Cities Service Oil Company 1600 Broadway Denver, Colorado 80202 Attention: Mr. Bob Pasque Highland Resources, Inc. i201 San Jacinto Building Itouston, Texas 77002 Sun Oil Company 4151 Southwest Freeway Houston, Texas 77027 Attention: Mr. W. T. Storte, Jr. Signal Oil and Gas Company Golden Center I 2800 North Loop West tlouston, Texas 77018 02.001B !, ~,. STATE '- -: of TO: ~" Files O.K. G i I b reth Ohlef Petroleum Engineer DATE , September 8, 1972 SUBJEO: Hamilton Brothers Wells Kup Delta Point Storkenson Mllne Point Wednesday, September 6, 1972, Mr. Jack Foggerson of Hamilton Brothers visited with Homer Burrell, Easy Gllbreth, Lonnie Smith, John Miller, and Car~ VonderAhe regarding permanent abandonment of their wells on the North Slope. Mr. Foggerson had prepared dlagrams of the present condition of each wel I. The main reason for the dlscusslon was to determine If additional down hole work was necessary to permanently abandon~ the wel Is. In each of these three wel Is, Hamilton Brothers left water base mud behind the production string of casing and In the annulus between the production and surface string. Also cement had circulated on the surface string and the conductor string. A concensus of those present indicated we believe the wells are completely safe slnce the water or water base drilling mud has now been frozen. Mr. Foggerson had recently taken a wire line unit into two of the wells and was able to spud 12 feet down on one and 20 feet down on the other, indicating hard Ice In the hole. It was our feeling that the ice made a satisfactory plug and any down hole work that we require might,result in thawing of the area around the well and create a greater/Z~~+W+han now exists. We informally told Mr. Foggerson that If he would go ahead and prepare his P-3 on each well that we would approve them. Under certain conditions, the equipment above ground level was to be removed. In one case he indicated this may extend a foot above the ground and we told him he should place gravel around the marker and spread the gravel out to make a smooth surface. Also we gave him permission to weld the marker on a plate and weld the plate to the upper casing flange for at least two of the wells, providing he gussetted the marker so that it could not be knocked over by caribou. He will discuss the procedures with the owners and operators and if they get approval they will submit Form P-3 for a permanent abandonment of each of these wells to be accomplished this coming winter. .;.¡.;.~",.........,.,,¡.. "~~~"",,,'<.,,.......... ,¡¡,¡..,.~,. "''''''¡' -~~~"~:';'"._~-;''--'-''~_-';;;'~'''''4~:''--'''_''''''~''''''''''~~'':'''''-''''~-~-~''' I' ( Log depths" of. ~hese records relate to: D Schlumber ,_!ine measu~ements, :I " " -_-__~H"" ~çc: 21ated by CCl to Radioactivity l05urements. ~,. ,~jJ,.;.~ Schlumberger Depths WEll ~,',KETCH 'Driller Depths " f",:",' U ' ' t . ! ~ , ,:~,":'~.:\,; 1 \tJI !, 'ò,',.~~ ~:' ':.r: I' ~ D. I ::r:""'~¡"',',"!~'nl~'" oJ, ' .... . -.:' \ -.."'''- . . tl " ' . ~,' . '~~~ì' .~~ i ¡/.,.....~r.; ,~'o '.. i) "4~ 0"; ", ~ r¡)~C) '}", '\" ... .... ..: .... ( ) E .' ' , .E VI ':;) U . <1> , , -£ ., ~. . >- ...0 '"'0 ( ) ..t::. III 'ë '~ ", ... .. 0 õ , ','"'0 <1> u c: ,<1> ... ( ) ~ r 1.11 ,- (-t,'f'!,I] [ ') f, tQ()~\. ì :~ '" r, I ,,\; - L' , ," ¡() 82:" (ì~J 23^II.l, .C' ~ ( ) ~ A vA! " I uS 4. e,q c¡¡ AI rei 'ì',~ () /z-i ..bG 6 0' Tc §' qq 1 f p 9)) ;) ~ ~~ U 'iI, , T U ~~ I N G &. 1\ N N U ~ ~ I S CEMENTED FROM' 6182 TO :3SP ON 23 AUG ¡O ANNUL. US CE~1ENT[D FROM '/ L~20 - 86 :-/1 0 N 2 ~ AU,,";. ',70 \ : - -. ? [R r 0 Rf':. .0 '~ s S Q ) ~ [L t<) . ...' ,. ..'. ,.... '..¡ .~".' ...".' , ..' .'.. ....'. ... ." ,'.. .... :'".., '. .,'.".........'" Q :; .-- ". T ", f7 2 '"'" 'J 1 \,., å '-- ' I: . .. ~I " J -) , . ' 2~ N-80 ,('Uì OFF ~ ~ f~ ; ~ .~~ û ~ ~ ~ ~ C ~ . 1 , , .. . X-OVLR 'i ¡,><fl,.,','..,!,1 [)<; , L-rLJ-¡ ~, U 0 I, ",--1' Î ,.~ '" - 8,~ T; ¡:' : N'" u ,: :, 8 '\j, ¡ I., I :, ' 'ì}, ("\ 1, ",,'~ ~ I ~\ ! ¡ P ë) ~ S',.. "...), ' .'. .,1','4 t "', ", '0.:.:;;, 2~X2;_; X<JVER ~ ; tl~' E. R I I ,) II p.~ (':< [R 1,) -: :. 2 ,i ~ [, ~ . t. S ~. I i>~~ 8 ¡Yß-rD 10742 rw' 1 J e.tnrD fil 'JDffJó deviation in production zone Open hole diameter .. Diameter and weight of casing and tubing Position & nature of perforations (bunets, conventional SC,capsules, etc.) ". ';J '("~ ' I' 'Jfz',/.., . ': ",' , "I\i,:, ,,',',1' "',,-'/,', ':-6,",,'","'''''''' ~,,~4¿'<C2-",,'.:L-/. , " 'I ¿-it, '~""c,7-" ,.,' -- "," , "''' ,¡". , , ' ' ,.' . , ,,' , I ",'" ,'" " I--""~" np~~~<~'~:~~{:;i:,~?""":~~:~:,~;~,~,,.:')~,~j:..::~~:'::f:~7~:r;'.?~~t .... STA¥~ · of ALAS~(A,..,. O ~ r~c~or TNRU: FROM: Pet'roleum Engineer ,. . DATE : SUBJECT: August' 23, J972' North Sicpe inspec?ion.of Iota%ions for .AshJand OJ t , . . , .,,.. ,.,, ,,: .:. m :,, -2- ~,~ hel icopt-er c~ rede ~he drl ~ ~ ~ng :~=.4 once end ~'rom ~'ha air and four more pho'~os fran The ground affer we landed. ., l~ho1'o ~¢lZi' was ~'"-',- ' ................................................ i? 1~ a va~/ btur~W phoi-o, bur ~ h~ve mar~ad savar~.:[ fha field and p~ area; l'fe~n ~Y2 ~he ~pproxirna*~e lacat'ion of ~ha wei ihead~ ifem ;I~ sceptered ~*rash end debr~ o'¢~ ?he No~!~eesi· corner of ~he , dr[ [ting pad; and I~e~ ~,-z4 several ~s'oodan s~ '- ~ ......... ~--,4 ~rner of ~he drilling pad ~n i'h~ ~' .... n- Tundra' ~ appeer~ ~hera i~'a 9reaf.deal of.~ebri~, hot.¢ever). 1'his .~ ~Usf '. . leveled gravel i'ha~' ha~ been spread, ou-~ oa' 1'he Tundra. ... .". , . . ~ . ...... . .,, .,.. . . . .' , · .. ,. . .' . , :. ''. . , .' . , ', . . ... , . . ; . ". . ' ....' ....~?~-o,¢1.?, ..?. ?.. v~e,...~o.. ~he. so,~.h~+ .of?. ,~he d~ t t.;~g ~. *h~,,i~ " ..... " . ':". · ' I'i~m. [~1: the ~'tl ea~' ''" """'"' :' :~' "' ' ' ' .... ~ '* ' ' ~:' """ ' '" ' ..... '".' . ..: ' ~_.:;...j,';_,. -,.. '?~ ....... cO~n~r 'Qf.....~:~]e.'. dEi.I...I.[rig pad; .t~:~ ~2 ~ ~1 te. o¢ ' "'"' "'.'. '" ..' ' . ...... .. .... '....:..' .~, a.~l'~:¢i:Tn ~ca~e~.d.,.$~a~.;'~nd.~ebrt;.., ",~,~,,;~ ' ,.L:' . .:' _". .'.' .'-'_.; ,.. ' ".'. ' '. "' . .... ' . .....:... :...................;: .....:...... .::;,:;,=::.;.. ...:..... :...?....:.., : "..'.";~.' ?".' ":'..'.'."::':" '. '.".:':' '::';..." .:P~.¢:~:.:' ~.l'~..;.'::';'.'.'i::~'...'.~'.';.~; e~.'.'.;~'F ..... .t~"" ' '""" .......... "i'" :.~'r~:e'~ ¢o.f :'.. ¢~e...p~..;. ~*~rd ~e" '.'.' ;'?":' ' :':.' "' :. :';:' ""' ' ".;. ";':'":.': ...".....':'......~'";'.' :'.:..'....~?¢hues~,.'.:c~e.¢;.:..~:..~,..a~:..:.....s~ ~ ;e,;'.:,.~.~:.~..¢'"' ~.~¢ :,'..s~. 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'...........:.,, ...: .,,.',. ;:..:.~..:. ,..?.,:.~:! ~.%¥..,~,~,'.,? ::"~i.~!~i~!~ '..., ~!~.%:,~,,:? Form No. P--4 REV, 9-30-~1 OIL AND GAS CONSERVATION COMMI'rrEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS APl NLrMEKICAL CODE $. LEASE DESIGI~A~ION AND S~-~IAL NO. 4 DL 3462306 W~LL 8. U'NIT,FARM OR LEASE NAME Pt. Storkersen 9. WELL NO. 1 2. NAME OF OPERATOR HAMILTON BROTHERS OIL COMPANY 3. ADDRESS OF OPERATOR 2820 "C" Street, Anchorage, ALASI~ 99503 ,. c,, P., .F... C .t"v"E.i.) 500' FWL and 500' FSL of Section 7 ~¢0 1fiT.0 T12N R14E UM ~. ;'. ;'..' '~ · "' !': :.';' .' .!i'~ :".,' ~.: /\ I' ,*' .'" i. I (' .C.L' ,.~ ,' '; ? 10. FIELD A_ND POOL. OR WILDCAT Wildcat -11. SEC.. T.. R., M.. (BO'I'FOM HOLE oa,mc'rnr~ SW7-T12N-R14E-UM 12, PER.MIT NO. 69-33 13. REPORT TOTAL DEPTH AT F~D OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS, JUNK L~ HOLE AND SIDE-TRACKED HOLE AND ANY OT'H~P. SIGNIFICANT CHA2/GES IN HOLE CONDITIONS. A'U'G~JST 1 2, 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 Ran 2" rotary shoe to 10,500. Circulate and displace w/lO~ calcium chloride. Circulate and mix calcium chloride. Lay down drill pipe. Nipple up B.O.P. and Hydril. Attempt pull tubing hanger. Ran cutter to 778'. Did not attempt cut. Pull cutter. Pick up 1¼" D.P. to 1/),525'. Could not circulate. Pulled back to 3800'. Well unloaded all.kill fluid. Mix 11.7~ kill fluid. Rig DeGa.sser. Ran d.p. back to 10,425. Circulate OK.. Ran to 10,538. Circulate. Light kick. Mix mud and circulate. Cut tubing at 785 w/Dialog cutter. Pull tubing. Mill casing (5½") to 4¼" ID. .Mill casing to 792. Mill off top of tubing to 792'. Ran 2¼" tapered mill in tubing to 801', Fish for 2-7~8" tubing, Cut tubing at 823', Pulled fish OK, Attempt mill casing. Lost guide off mill. Recovered w/tapered tap. Mill casing w/3- 3/4" mill. Mill w/4¼" mill 801' to 824'. Mill.ed over top of fish. Fish for 2-7/8" tubing. Caught fish. Go through fish w/1¼" DP to 3777. Circulate. Lay down drill pipe. Rig Schlumberger. Went to 8520". Ran 1¼" D.P. to 8258. Circulate. Pull out of hole. Backed off 2-7/8" tubing at 892'. Screwed into fish at 892'. Would not circulate. Attempt perforate tubing w/Schlumberger tubing gun - negative. Attempt perforate 2-7/8" tubing w/Schlumberger tubing guns - negative. Perforate w/Dialog gun at 8831 - 8832'. Circulate OK. Cement through perfs,.w/ 100 sx.::.class "G". Displace w/49 bbls fresh water. ,, ~ ':,.:i "' !~" ': "" " , ~ ~,, ' ;:,~ ,.,.' ~ No. ~.-4 "'~ ~ ~'~ ~ ~ ~ ~ ~EO'~'~ " L. j C. ENQ ~. ,.~ STATE OF A~KA su~ OIL AND GAS CONSERVATION CO~I~EE AND WORKOVER OPERATIONS 0~ WELL ~ GA8 ~ OTHER 2. N~E OF OP~TOR 8. ~M~TON BROTHERS O~T. COMPANY Pt. Storkersen ~. ADDRESS OF OPhiR _ 2820 "C" Street, Anchorage, ALAS~ 99503 4. ~CA~ON OF W,;L~. 10. FIE~ ~ND P~L. OR WILDCA t ~ CONFEE: . 500 FWL and 500 FSL of Section 7 Wildcat SW7-T[ 2N-RE 4E-~M 13. P~IT NO. 69.33 13. ~PORT TOTAL D~ AT ~D ~F ~nN'='H ~a~.~ ~ u~.~ =,~ ' CASING A~ Cs:~IENTING JOBS INCLUDING DEPTH SET ~ VOL~ USED, PERFOR-ATIONS, TESTS ~ ~SULTS. FI~ING JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE ~ ~Y O~ SIGNIFIC~T ~~ IN HO~ CO~TIONS. .~ULY 22 23 24 25 26 27 28 29 30 31 Rig up, Rig up, Bleed off well to burn pit. Rig up, Mix calcium chloride for kill fluid, casing and tubing, Rigged Schlumberger unit, Ran 1-11/32 sinker bars to 793' Unable to tell what status of tubing was, Wait on 1¼" macaroni drill pipe· Wait on drill pipe. Picked up 1¼" d,p, Milled 811 - 813', Clean out to 4500'. Unable to circulate kill fluid due to collapsed · Ran impression block, Stopped at 811'. Went in. w/mill, Start milling to 2" at 811'. Picked up 2¼" tapered mill. Milled 811 - 813', Free to 2720', Plugged, Pull out. 14. I is true axed correct sm~ Drillin ScJ-~9.~erintendent n^~ S_.~flptember 3, 1970 NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. 'j Memo to Fi 1 e, Hamil ton Brothers Point Storkerson No. 1 At approximately ll:O0 AM, August 4, 1970, Mr. Chuck Champion with Hamilton Brothers called from Point McIntyre to advise that they now have the subject well under control,~ hmve circulated killing fluid and there is no danger whatsoever of blowout. Lonnie Smith was there and had given advise regarding our requirements. There are now preparing to go in the hole after tubing, after pulling tubing will spot cement plug approximately 200' over- packer and set an~,iadditional 200' plug at approximately 2,000' and suspend the well. The well will not be P & A. This w$tl give adequate time to determine what measures will be necessary to place a well in a producable condition. 1G ' , "Lc 2 i t $ T'~:t 2 d , ;(~o~ ......... For~ No. STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING ~,. L~,SE DES:O~A~O.~ Axo sn~a", so. AND WORKOVER OPERATIONS ~LL 2. N~E OF OP~TOR 8. t~IT,F.~{ OR LEASE 3. ADDRESS OF OP~TOR 9. WELL 4, ~CA~ON OF W~ 10. ~'I~ ~D P~L. OR WILDCA~ 11. SEC.. T., R., M.. (BO'I~OM HOLE 12. PERMIT ~0. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~WGES IN HOLE SIZE, CASING A/q~D CEMENTING JOBS INCLL'DING DEPTH SET AND VOLUMES USED, P~O'~TIO~S. ~TS ~ ~SULTS, FISHING JO~. J~K ~ HO~ ~D SIDE-~C~D HOLE ~D ~Y O~ SIGNIFIC~T ~G~ ~ HO~ ~ITIONS. 22 24 25-28 Ran temperature survey. Found top cement 7420' in annulus - 8750 in tubing. Perforate w/Dialog gun at 8735 - 8736 w/5 shots. Could not break down and pump. Perforated 7350 - 7351 w/5 shots. Cement thru perfs w/100 sx Class "G" . Displaced w/32 bbls 11.7~ mud. Ran Dialog tubing cutter. Cut off at 6050'. Pull up 5' spotted 40 sx plug At 5995' in5½" casing 335' plug. Layed down tubing. Cemented from 820' to surface w/190 sx Class "G". Nippled down B.O.P. Install tree. Cement bottom of cellar w/25 sx Class "G". Blanked off all connections on tree. Tearing down. 14. I hereby ~e~Y th~the~egoin2 i~ true ~ ~olTec't szGN~ ~ ? ~,----~-_~ ~ Drilling Superintendent DAT~ .. September 3, 19 7.0 m ' ~ ' i NOTEmReport c~'this form is required for each calendar month, regardless of the status of ope.rations, and must be filed in duplicate with the Division of Mines & Minerals by the lSth of the succeeding month, unless otherwise directed. FORM SA- lB MEMORANDUM TO:[-- ~ouer L. But-tell Director 1TIRU: Oo K. Cilbreth, Sr. /~.. Chi~f Petz~leum F~gineei~e~' State of Alaska CONFIDENTIAL DATE : ~t 11, 1970 FROM: ~:~tl:lie Co Slaith ..:, ,- SUBJECT: Inspect Operatioas HaUl.on Petroleum F~gineer ~./:" :'~: .~- - July 29~ 10 A.N. X d~ Co ~a~o~se ~d C~d wZ~h the H~I~ BroChe~ ~O~i~g ci~ ~-W~ lo.rig the '~li~p~er ~ich fli~ 8~plteo to their we~ sites. At t~s tt~ t~ heE~t'er w~ ~r~ing ~e 1" t~iug that w~ to ~ .~ed to ~ter ~d work ~ the Point Stor~en ~11. ~e fo~ ~.fo~d ~ th~ J~ F~.~, t~ H~i~ ~he~~ dealing 8~e~te~at, w~ ~ l~ti.~ at ~e wall,. I ga~ him ~ c~d ~o p~s ~ to ~. Fo~~ ~d Cold h~ Z ~t w~t ~ ~8tt ~ie ~l after work ~.. ' . ~_~t_?:.::~.,....ll::~/~,~,~..:ay inqutr~ at. 'ttm I~dhone airstEip I lea,m~ t~t ent~ ~Co ~ well ~th ~ 1" t~ h:~ be~ .~d.. ~. Yo~s~ is s.~ll ~ 1~i~ s.o I fXs~ed that ~eE ~ t~ ~e~ I w~d ~ ~o get m.r to ~e ~1 si~e,. 8:40 A.,~.. ~htle driving vea~ to the British Petroleun s~' '~r~ the ~o~c Stor~.n~ ~1I fo~ ~t ftfte~ t~ ~It~ ~thers:* helical,mr .f~ the Point ~e ~i~ i~:t. ~ t~e m t ~~ ~ t~ Storke.rs~ well ~ t~ Po~t Storke.~eu ~ll, I ii~ ~ ~ .~ a to ~ ~ t~. PE~ B~ ~t:~p., whe~ I left .~ ~.cie., ~d ferriC..~ to ~t tm 't~ Pe~ Stmfke~$~ ,lo~i~ ~eEe I ~~.~ the .~ ~d. VÆ'!+IC'J.E ,~ t J.A I(I:~ x 7 Form I~-'V. 9-30-6? Submit "Intentions" in ~rtpl'isate & "Sub~quen~ Reports" Jn Duplicate ,STATE OF ALASKA OIL AND GAS, CONSERVATION. COMMI'rl'EE SUNDRY NOTICES AND REPORTS ON WELL5 (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) OIL ~ GA8 [~ WELL WELL OTHER 2. NAME OF O~,F, ATOR HA.MILTON BROTHERS OIL COMPANY et al 3. ADDRESS OF OPERATOR 440 Eagle Street, Anchorage, ALASKA 99501 4. LOCATION OF WELL At surface 500' FWL and 500 FSL of Section 7 T12N R14E UM 13. ELEVATIONS (Show whether DF, RT, GlO, etc. Check &ppr~pria~e i~x To I,ndir~te Nlamre of N~fi'c'e, Re, 5. AP1 NU'MERICA.L CODE I~', '/. $.LEASE DESIGNATiON A_ND S~ NO~ :. ~L 34623 OG 7. IF I1VDIA.N', A.L,LO~ OR 8. UNIT, FAR~ OR LEASE NAME .......... Point Storkersen 9. WELL NO. ~:1 10. FLELD A~D POOL, OR WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T12N, R14E UM 1~.. P~I~f. IT 1~1'O. 69-33 )orr, or Other 'Data NOTICE OF INTENTION TO; FRACTURE TREAT j__j MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CARING SHOOTING OB ACIDIZING ARANDON,%fEI~'TS (Other) (Other)Suspend Oil Well (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log form.) 15. DESCRIBE PROPOSED oR COMPLETED OPERATION'S (Clea,[ly state all pertinent details, and Ktve pertinent dates, including estimated date of starting an~' proposed work. It is proposed to suspend this well as follows: (all depths T.H.) 1. Set Model "D" permanent .packer at 10,555' 2. Run and hang. 2-7/8" tubing at 10,558' as follows. 10,543' "2-7/8" tbg Otis type "XO" side door sleeve at 10,543 2-7/8" x .2-3/8" crossover 8' jt 2-3/8" tbg Otis 'type' "'N.".. nipple at '10,. 554 2-3/.8." x.2'.~7/8" crossover 3' Baker 2-7/8" seal assembly top at 10,555' bottom of tbg open ended at 10,558' ~WO~ OF OIL AND. 3. Tbg is plugged with a blank in the "N" nipple at 10,554 .]Perforated interval 10,580., 10,640. (squeezed with 100 sx cement) ,6. I hereb, ~ertl? thst~, f~'lne ,s ~ue and eorre~ sm~~~ /~~/ ¢,~= Drilling Superintendent..._ ~,¢n.pecember ~ ~969 COSDm0~S or'~P~eo~L, z~ ~: ' ~' / ........ ApprovsI subjec~ to ins~llstion of blind'flsnges or plugs in e~c~ tubing'snd cssing outle2 opening. ..~ ................ - .; .... [[:. . "",c ~" ......... F~rm ~o. P.--4 REV. 9-30-$'~ STATE OF ALASKA OIL AND GAS CONSERVATION CONW~ITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. OiL ~r EI.,L [~ GAB ----L,. ~] o,~--, Drilling Well ,. N~-- OF OP~TOR HAMILTON BROTHERS OIL COMPANY 440 Eagle Street, Anchorage, ALASKA 99501 4.'~LOCATION OF WELL ( SUBMIT IN DUPLICATE 4 DL 34623 06 ~' IF INDIAL~. A~OTTEE 0]~ TR ~l~-"~~~, ~~ OR LEASE NAME Point Storkersen ~1 10.~. OR WILDCAT Wildcat -- 500' PWL and 500' FSL of Section 7 ~tl~J'~ T12N R14E UM 1969 12. P~IIT NO. ~ ~I~I$10N OF ~ ~.. 69- 33 ]3. R~ORT TOTAL D~ AT ~D OF MON~, ~G~ ~N~~.~_~ C~NG JOBS INCLUDING DEPTH SET ~ VOL~S US~, P~O~TIONS, 'I~TS ~ ~SULTS. FIB~NG JO~, J~K ~ HO~ ~D SIDE-~CK~ HOLE ~ ~Y O~ SIGNXFXC~ ~G~ ~ HO~ ~ITIONS. NOVEM BE R 1 SWT-T12N-R14E- UM 9 10 ] i Unseated packer. Pulled 7 stands. Dropped P.B. 10,742. Bar broke circulating sub. Reversed out oil and gas and gas cut mud. Circulating and conditioning mud. Mud out 8.2 in 10% 28 gusting to 48 knot winds. Condition mud. Wait on high winds to pull test tool. Pull out of hole. Lay down test tool. Pick up Iohnston squeeze tool and packer. Going in hole. Circulating and rigging up Dowell cement track. Squeeze perforation 10,580 - 10,640 w/100 sks. Pull out-perforate~.'10,495 - 505 w/4 shots ft. Pick up Johnston D.S.T. tool going in hole w/same. Ran D.S.T. tool in hole. Set packer at 10,450. No surface flow. Pulling test tool. Pulled D.S.T. %7. Perforations 10,495- 10,505. Rec. 3100' desselcushion .. 570' free oil. 285' heavy oil and gas cut mud. 285' heavy gas cut mud. 285' muddy oil cut water. Going in hole to squeeze perforations. Squeezed perforations 10,495 to 10,505 w/75 sk. Released packer reversed out cement. When this completed,packer stuck at approximately 10,476'.. Worked up hole to 10,470. Circulating. Waiting on orders. Went in hole w/free point and string shot. Pipe free to top of packer. Discharged shot in packer with tension. Did not release. Pulled line. Rigging string shot to back off tubing .. Ran string shot. Backed off tubing above. Cement retained. Pulled tubing. Picked up bumper sub - jars and 15 drill collars. Going in hole. Screwed into fish- jarring and bumping. Jarring on stuck packer 24 hours. Worked and jarred packer loose Sunday morning at 9:00 am. Pulled packer out of hole. Ran ring gauge. Stopped at 7832. Picked up bit and casing scrap and ran to 10,475'. Form No. P--4 ~zv. 9-~o-s~ STATE OF ALASKA SuB~ IN ~L~CA~'= ~. A~ N~I~-RICm~ CO~E OIL AND GAS CONSERVATION COMMII-I'EE MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS LEASE DESiG~TATION AND SEKIAL 1~O. 1. T. IF INDIA]~, ALOTTEE O1~ TRIBE N~klWXl~ W,LL W,LL OTHE' 2.N~E OF OP~TOR 8. L~'IT,F.~., OR LEASE N.~E 3.ADDRESS OF OP~TOR 9. WELL 4.~CA~ON OF W~ 10. FI~ ~ND P~L. OR WILDCAT .,..... .,'., ..... JI~_IilON OF OIL AND. GAS I1. SEC., T., R., M., (BOTTOM HOLE oB.r~cTrv~ 12. PEP, MIT NO. 13. i~PORT TOTAL DEPTH AT E/%TD OF MONTH, CHANGES IN HOLE SIZE, CASING AND CE!ViENTING JOBS INCLUDING DEPTH SET ~ VOLLT1VrES USED, PF-~IFO,I~ATIOI,,'S, TESTS A1N"D I~ESULTS, FISHING JOlt, JU'NK IN HOLE AND SIDE-TRACKED HOLE A1N-D ANY OT~ER SIGNIFICAI%TT CI-IA~G~-~ IN HOL~ CONDITIONS. November (Continued) 11 Pulled bit and scraper. Ran gauge ring. Going in hole to perforate 10,460',to 10,470. ,,, 12 Perforated 10,460 to 10 ,470. Pulled out..Ran..... ~......~_.__T_,...__9_,8.10,460 to 1'~, 470 . Opened tool w/very weak blow. Rec. 190' heavy oil cut water - 3500'". slight to heavy oil, gas and mud cut water. Ran Rtts packer squeezed perforations v¢/100 sks. Reversed out. Pulled out of hole. Picked up bit and scraper. Went in hole circulating on top of cement. 13 Circulate. Drill out cement at perforated zones to 10,742. Circulate out. Pulling out of hole. 14 Pulled out of hole. Laid down drill string. Rigging up to run Baker Model D production packer. .. 15 Ran gauge ring. Ran Model D Baker packer set at 10,555'. 16 Preparing to run production equipment and 2-7/8" tubing. 17 Ran 2-7/8" tubing w/tail spear and side door choke. Set tubing down. Rigging to displace mud. 18 Attempted to run bottom hole plug. Stopped at 10,380. Hooked up mud line. Circulated tubing w/mud. Ran~.l.u_q set in seat~i,n..g,~.~n_i.~p..~..e....,.a.,.t.,.l_0., 5x_~53'. ~emoved B.O.P. Hooked up displacement lines. Install xmas tree. Preparing to dis- place tubing. 19 Displaced hole with water, then diesel oil. 20 Ran Otis closing tool on wire line..C.~.~.e.`d..~--S.`i.-d-e`-`d.`.~.`9~r``.`~-a~..-b.-~-V~e-.`p-9~.`C`~k..`e-r`~' ...... h o !.e...b .1,.a..nk p.!. u...g.,,....i...ri.......p..!...a..g...e......a,,,t._...!..9_:_ .5...5...4.,. 21 - 30 Tearing down, preparing to lower mast. Lowered mast, moving out rental equip- ment. Storing equipment. 14. I hereb h .iG~ _k~_,~h~'~'" ? F~~ =~u Superintendent ~.~ December 3. 1969 ii NOTE--Report ~ this form is required for each calendar month, regardless of the status of operations, and mu~ ~ filed in du~cate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. H~mn?o~ Baoxa~.}tS 0~. SUITE 2 EAGLE BUILDING ANCHORAGE, ALASKA 99501 November 12, 1969 FILE _ ,. State of Alaska Department of Natural Resources Division of Oil and Gas Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Gentlemen: Enclosed are two copies of the completed P-4 form for the Point Storkersen $1 well for the month of October. Please acknowledge receipt of this report by signing the enclosed copy of . this letter in the space provided and return it to this office. ~.~we [/~ Very truly yours, HAMILTON BROTHERS OIL COMPANY ~,..,. .... ~. ,_../' Jack Fogofson Superintendent /F:ams Enclosures a/s cc ~N. J. Linton F~rm No. P~4 P,.EV. 9-30-6'~ STATE OF ALASKA OIL AND GAS CONSERVATION COAMAI~EE SUBMrr IN DUPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL ~t'KLL [---] GAB ~t' ELL ~-] OTHER DrillingWell ,. N=E OF OPerATOR __HAMILTON BROTHERS OIL COMPANY 440 Eagle Street_~_c___~chorage, ALASKA 99501 4. LOCATION OF WF.J~ 500' FWL and 500' FSL of Section 7 T12NR14E UM APl N%r~. iEITICAL CODE -- ~S:ONA~ON A.',-D szmA: 4 DL 34623 06 ~O]{ TRIBE NAME ~~:~A'! OR ~ASE Wildcat 11. SEC., T,, R., M., (BO'I~I'OM HOLE SW7-T12N-R14E-UM 12. PI~VIIT NO. '~ 69-33 13. ORT TOTAL DEPTH AT END OF MONTH, .CHANGES IN HOLE SIZE, CASING A.ND CEMENTING JOBS INCLUDING DEPTH T ~ VOL~S USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CH. AN~ES IN HOL~ CONDITIONS. OCTOBER Page 1 of 2. 1 - 10 Drilled from 10,824 to 11,276. 10 - 11 Logging - Gamma Ray, Neutron. 11 D.S.T. %3. Packer failed. 11,070 to 11,277. 12 Circulate and condition hole. Pick up test tool. 13 Trip in hole with test' tool. Open tool at 7:57 am. minutes. Test 11,171 - 11,277. Recovered 2,000' cut mud. 14- 21 Drilling 11,277 to 11,473. 22 . Ran Gamma Ray, Neutron, Sonic and Caliper logs. 23 Circulating waiting on orders. 24 Ran drill string open ended. Spotted 48 sack cement plug at ll 067 at 3'00 pm. WOC ' 25 Ran bit - check top cement 10,778. Drilled out to 10,786. Pulled bit. Ran drill string open ended. Spotted 15 sack cement plug. 26 Ran bit in hole. Cement stringers at 10,700. Drilled stringers. 27 Drilled stringers and soft cement to 10,9,~6 - hard cement. Pulled bit. Ran 'drilling string in hole open ended. Spotted 46 sack cement plug .at 10,912. 28 Wait on cement. Ran bit and casing scraper. Drilled out hard cement 10,480 to 10,750. Pulled bit. Ran Halliburton cast iron bridge plug set at 10,742. 29 Ran Johnston 4¼" D.S.T. tool in hole. Could not get to bottom. Pulled out. 30 Waiting on 3½" Johnston tool. 31 Picked up Johnston MEF 3½" D.S.T. tool. Went in hole set packer at 10,555 Opened with very strong blow. Flowed to pits for a clean up. Switched to separator and test equipment. Testing well 10,580 to 10,640. · .nA~ November 12, 19_69 Wi'll ~O:~ivi~J;r:~ Mines&Mineral' . ....... din duplicate Very weak blow. Died 45 water blanket- 450' gas .~ i~/~ '77 HAMILTON BROTHERS 0IL COMPANY SUITE 2 EAGLE BUILDIN~ 426 EAGLE STREET ANCHORAGE, ALASKA 99501 October 8, 1969 HLB TRM, ~ OKG KLV ..... I ,, ~It . . State of Alaska Department of Natural Resources Division of Oil and Gas Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Gentlemen: Enclosed are two copies of the completed P-4 form for the Point Storkersen $1 well for the month of September. Please acknowledge receipt of this report by signing the enclosed copy of this letter in the space provided and return it to this office. Very truly yours, HAMILTON BROTHERS OIL COMPANY G. F. Chapman Drilling & Production Superintendent GFC:ams Enclosures a/s cc W. J. Linton STATE OF 'ALASKA OIL AND GAS CONSERVATION COMMrl'rEE MONTHLY REPORT O'F DRILLING AND WORK OVER, .OPERATIONS OIL W~'LL [~ GAB WgLL ~] OTWgl~ ~.--'~'~OF OPERATOR SUBMIT IN DUPL/CATE . . -~. A~! NX~XERICAL CODE ' " Drilling Well HAMILTON BROTHERS OIL COMPANY Suite 2, Eagle Building, 426 Eagle Street, A~chorage 99501 500' FWL and 500' FSL of Section 7... T12N R14E UM 1' ~I¢~--ION AND SEKIAL NO. --- 4 DL 34623 06 8. I/I~'IT.FARAJ OR LEASE NAME Point Storkersen %! Wildcat -- 11. ~f.,' T.. R., M., ~JO~'OM HOLE' -- SWT-T12N-'R14.E-UM ..:.1! '....(7'. Drilled'.frem,,10:,58.2::.tev..1..0,..,..:?g2.... . . Page 1..of'2 .... :~'-..8 ,.'.~e.a:,... a.~.:%is...:z:o:~..:.~;i~.:~. '.':t?...~::o.,.4a.o....... ' '" ... " .... .', :,:". ,"., ',. ".. "~ :S-c.s'..'.~..0..:;..7,....?:.8,' t,e'." i.~:; ... '" ' : '""Te'sted'::Wi:.'th.'.":fOrma't~n:":t'e:'s.,ter'.at . . :.1.0.,·4.6..5 9.,~.. ' 9"" Tee k"! DS,T'. .~ i '., :.':,'. 'M.i s:~..h .... ..' .'.'.'?.....'.. '.......'. i..".: .'......1., 0.., 65.0' .-. -. 2t'3'-' 3 :.,.:..I:'..5...0 ..,. ,..~,o.,,..n .~.,..:,,,.,e,,,. "O~.~..r.~,,,'.":C~,ai,t".~:~:,,i,~..,h:,oze.,,''', .,." '. z:2'.' "n',"'~ia~!~,",, :'~a.~.".'~"D¢::':Z;:e'.,':,?~8.'.4.. ',.'.:8';.;..e.O.0.' .... . .:':,..:.:S:'.N.P..1.,e.?~8.6':" ~"'8...,~i0)0~0..:..... . . : ..,,...,.',..'":~:~',~c..,l,:e.;:7.:82,,:.,.":8,.;,:e,,O,o', : "~: ' "'" :.":"'"' !3' ' "Ran'"S'~err;y"S'ur~'::'Dire:ct'i.o. na1~, :$.U~ey:'from"I.0.,.7'50 (actual ~,e. pth). ~o surface.' .. ". :... :.aa.a..~i.pmet. er;.'.!8'.,:.,7;[8272...:2..0..35,.i..... '::'." .' ' ' ' · ' ' ' ' . I'.:4"- '~'5' .' ..Raa'.34.3'.:j.~..S:...'..':5~':,~.:'."'.~:...N8o.',i::.....::.'...' "...'.. ' .... '. :.' . . ."" '"':'.' ." ".':"." '. .... :,.'.'I · ..": j-. ..... .' ..,'...'~..at...~4006,..',... ".'.'!".:~lb"..c..as'~mg' .s et:..., a, ..1:,,.,7.'92' .and. ceme,~ed...:,n :.2 's.t,~j.e.s...'.':.'.' '! 1. st' St:a'ge'::.450' sae.kS.:./.~e.at'..C.i..a~ss.....G...cement, ..: ... . '. ' 2'~d:'::Sta:ge' 'sso's:acks."'.:n t:C!a, ss, G..c t, 1.6'.~'7. !.8 .w.:'.,.'o,c ad.' h'e U'P" emn ' " ' :" '" '.,.'.':. a arding: ea,. '"., :' '....' ..'... '.:. '..'.'.'....' ' "' " i 0"'":"' ""'"'Leg'~'i'ng';': R:a,n'i.'"c,:e:men't."b~ .::d. . .':, '' ! .... .".' '~'d.:..1..eg.. a.~ ',GR..lgg,.2 " ' '"" '" ' . .. . ,, ' . ..,.' .' ',"'C,e:n:~tien.,:.hote' a.nd'., m~id', "'.'., ... ..... . . ',, .'. '.,'" ,.. , '"/ ... 22 ..... . ..,..:Perf01rat.~d. W~/t.h...:'.3..~'.~/8....e.'.erami¢. ch:arg.e s -. 4. Shots per ft' .from ~ 0., 5.8.0.: ~e'....l.0:.'i'.'~.0'.,'" ..'.": :' .23:.'..-:.2:4~, '" ...... '" "' ' ....... "' . , Drill"'.stem:,:.~o~'.,tes',i,'.,~:f ,per,,.f..era. ted:iiaterval,. "',.' , ,. .,, ,, ,' . ',' ".,.."', ...... ?.:.'v.,..:. '2:5.-.26 ' C.l.ea. red'.:t:°.el'..201, minu.:t,e~...,' '.. i..ai.tial..shut 'in:. 45 minut.eS:,'...Pressure '5:I=53' P'SL ' ' ' ..... ' ,i st Flew:.',:', l':2:',.'h,r.s,,49.."'mi~s'.,'. "'.,FFP,,,'50 ,3'2 PSI ' ' '" '~'"'*'-'"'~'~i~~*~'' "' · "'l '" ' ' ' ..... "'" ......,. ' ........ ,' . ''¥~.'iV,~....".:'....'. .:,,,~ · ' F',l::a,~. ,'~.'~l~"j~.: ':,'~"~"~"~'!': ]~:~,~),'~' ,&.~, "~'~'~1'.O1 TT ,'~'~' ''"~ .... .,J ,. · , l"mTa No. P--4 REV. 9-30-6? STATE OF ALASKA OIL AND GAS CONSERVATION COMMI~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. 2. NAME OF OPEi%ATOR 3. ADD~ESS OF OP~TOR ~i LOCATION OF W~ 0T~ER SUBMIT D; DUPLICATE APl NL~[ER/CAL CODE 6. LEASE DESiGI%tATION AN'D SERIAL 1%70. T. IF INDIA]4', ALOTTEE OR TRIBE 8. L.~'IT,F.~d:~A{ OR LEASE N.~E 9. WELL NO I0. ~'I~'-L.D A_ND POOL. OR WILDCAT SEC., T.. R.. M.. (BO~FO~ HO~ OB,rEcTrvF_J 12. PER.MIT NO. 13. REPORT TOTAL AT END OF MONTH, CHANGES SIZE, CASING ANT) CENIENTI~G JOBS INCLUDING DEPTH HOLE SET ~ VOL~r~.s USa. P~O~T~O~S. ~ ~ =~S. ~S~ JO~. ~ ~ ~O= ~O ~O~-~C~O ~O~ *~ ~ o~ ~nc~ ~m ~ ~o~ ~o~s. SEPTEMBER (Continued) 23-24-25- 26 3rd Flow: 27 21 hrs. FFP 5034 PSI. Flow rate 315 BOPD 30%H20. GOR16,800. Fourth and final shut in 21 hrs o 515I PSI. NOTE: DST charts show plugging in tool. Recovered test tools. Preparing to squeeze. Page 2 of 2 28 29 30 Squeezed perforations with 150 sacks neat cement to 3000 PSI. rate 2-3/4 bbls/min. WoOoC° Drilling 4-3/4" hole from .10,792 to 10,824. Max squeeZe COT 9196 DIVISION OF OIL '14 I hereby cea'tifyr4ttmt~he ~g~g i~ %rue arid colTeCt ~_~ ~ ~ _ ~ ~ ~ --~ ..... ~-; ! /( i-%~ . ~rllllng e ffroauc~lon . ~a~-~ [~,_~ ~~~u Suoerinta~dent .... ,~ October 8, 1969 NOTE--Report on this form i~required for each calendar month, regardless of the status ~ operations, anO must ~ file~ in du~icate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~i~ directed. FORM SA- I B MEMORANDUM State of Alaska DEPARTMENT OF NATURAL RESOURCES Division of Oil and Gas TO: I-- Homer L. Burrell Director ~hrough: O.K. Gilbreth ~~-~~e~ Chief Petroleum Engin FROm: Robert E. Larson ~.~ ' Petroleum Engineer CONFIDENTial DATE : October 1, 1969 SUBJECT: Field Trip Report Bros-.- Point Storkersen #1 On September 25, 1969 I traveled to the Hamilton Brothers Point Storkersen No. 1 well to witness the tail end 'of a drill-stem test. The well was being tested from a 60 foot interval through perforations in 5%" casin§. The test tool had been opened at 8:00 a.m. on September 23, 1969 and they had flowed the well at two different rates with a shut-in period after each flow rate and were on the third and last flow rate when I reached the location~ which was at 9:00 p.m. At that time the well was flowing at a rate of 600 BOPD and 260 BWPD with a gas-oil ratio of 8000 to 10,000 cu. ft. per. barrel. The gravity was reported to vary from 36" to 39°API. It is presumed that the true gravity is prob- ably closer to 39° and the lower gravitywould be due to contained water. The test tool was closed at 6:00 a.m. September 26, 1969 for a 19% hour final shut-in pressure. REL: jw HAMILTON BROTHERS OIL COMPANY 426 EAGLE STREET ANCHORAGE, ALASKA 9950! September 15, 1969 State of Alaska Department of Natural Resources Division of Oil and Gas Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Gentlemen: Enclosed are two copies of the completed P-4 form for the Point Storkersen ~1 ~vell for the month of August. Please acknowledge receipt of this report by signing the enclosed copy of this letter in the space provided and return it to this office. Very truly yours HAMILTON BROTHE'RS OIL COMPANY G. F. Chapman Project 1Viana.ger GFC:ams Enclosures a/s cc ~Af. I. Linton QJ~qr.SK)N OF OIL A~ID 0~8 ~JVJaON OF OJL~.Ni~_ GAs Form REV. STATE OF ALASKA OIL AND GAS CONSERVATION COMMII-I'EE SU~.MIT IN DL~LICAT~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. o.,~ [] G,. [-] o~ Drilling Well WKLL ~ELL 2. NAME OF OPEP~ATOR HAMILTON BROTHERS OIL COMPANY 3. ADURESS 'OF Ok'~.a~TOR " Suite 2 - Eagle Building, 426 Eagle Street, Anchorage 9950 4. LOCATION OF w,gJ~L $00' FWL and 500~ FSL of Section 7 T12NR14E UM ?-.IL'~. ~ ",RM ~ ~. A~'I m.~.¢ERIC,~L CODS KLV ~- ...... 8. %~SE D~S:GNA~O~ AXD S~I~% ~O REL ~ ' ,, , ~D~3~230~ ~ , i , ' T. IF INDIA~. A~T~E O~ TR1Bk NAM~ 8. L.~TIT, FAi~,! OR LEASE N..kM.E 9. WELL NO. Point Storkersen %1 10. Fllgl..~ A_ND POOl... OR WILDCAT Wildcat 11. SEC.. T., R., M., (BOTTOM HOLE o~rv~ SW7-T 12N-R 14E -UM 12. PERMIt' NO. 69-33 ,,__ 13,REPORT TO~AL DE!~I'H ~T END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING AND CENIENTING JOBS INCLUDING DEPTH SET AND VOLUiVIES USED, PEP~FOI:LATIONS. TESTS AND i:~ESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TI:tACKED HOLE AND ANY OTHER SIGNIFICANT CHAN~ES IN HOL~ CONDITIONS. August 1 - 31- Drilled from 4987 to 10,582 No other significant activities. olv~ao~ o~: O:L ~ Gas DIV~tK~ OF olt ~ e~ ...... ~W~ .... S~G~~~. "'~q~.,. ~ Project Manager ~¢¢ .September 15,. . 1969 NOTE--Report on this fo~ is required for each calendar month, regardless of the a'tus of operations, and must be filed in duplicate with the Division of Mines'& Minerals by the 15th of the succeeding month, unless otherwise directed. ~ ;~TERNAL ~O,~R:S, ONDENCE 'i To' Mr. D. E. Jessup $ub ject' ;uqC0-HORCO Well Elevations Prudhoe Bay Area _ Arctic Slope, Alas;:a From: W. C. Penttila Date: September 17, 1969 DM. Pat. Patterson with H~ble Oil & Refining, and Mr. C. B. Thomas with ARCO, both surveyors, obtained the following - ~ , ~e~ elevations: Well Name and Location ~offland Bros Prudhoe Bay State #1 Sec. 10, TllN-R14E D~lta State #1 Sec. 10, T10N-R16E Gravel Deck Braden Kelly Pad .~ Floor Head ~ 25.0 26.0 26.~ 41.0 Lake Stat e [/1 Sec. 24, T10N-R15E ~owan Rig .#35 Put River State #1 Sec. 7, T10N-R14E ,.. Southeast Eileen St. #1 Sec. 35, TllN-R12E Rowan Rig #34 NW Eileen State #1 Sec. 28, T12N-RllE ~abors Rig #9_ Sag River State #1 Sec. 4, TION-R15E' Brinkerhoff '#42-H _ 20. ~ 21.4 -- 36.4 36.2 36.8 -- ~1.8 · T: ! , ., 47.9 79.4 '. 48.7 .. iii 47.8 · 38.8 68.6 .37.8 39.4 Kup River State #1 Sec. 21, Ti2N-R13E 58'.0 '. 39.0 -- 7.9 8.3 -- z6.8 Toolik Federal #2 ,Sec. 5, T8N-R!2E 121.5 .... '(This well elevation was' obtained by altimeter) . . . . Carl B. King Point Storkersen ' ' .".' .. ~ . Drlg. Co. Sec. 7, T12N-R1.4E' "" 2~'.0 (~1') ~ig C-! " .. 133.~ (+-:~,) W. C. Penttila WCP: aba Mr j Rex Smith - H~_O, Los Angeles These elevations were obtained by differential leveling (exeept for'Toolik Federal #2)' m and should be accurate within ~-0.5 feet. .... ,: ' " ,. HAMILTON BROTHERS OIL COMPANY SUITE 2 EAGLE: BUILDING ANCHORAG£, ALASKA 9950! August 13, 1969 State of Alaska Department of Natural Resources Division of Oil and Gas Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99504 Re: Point Storkersen $1 SW7-T 12N-R14E-UM Gentlemen: Enclosed is the luly well report for the captioned well. Very truly yours, HAMILTON BROTHERS OIL COMPANY GFC:ams Enclosure cc W.J. Linton G. F. Chapman Drilling & Production Superintendent l~rm No. P---4 REV. 9-39-67 STATE OF ALASKA SUBMr; IN D~?LmAT~ OIL AND GAS CONSERVATION COMMI~EE Ill/ION?lilY RI:PORT OF DRIllING AND WORKOVER OPERATIONS 1. OIL ~' ~' L.T., [] GAB ~-.,-L [~ o,.~. Drilling Well 2. NA!~IE OF OPI~L~TOR Hamilton Brothers Oil Company Suite 2, Eagle Building, 426 Eagle Street, Anchorage 99501 4. LOCATION OF WELL 500' FWL and 500' FSL of Section 7 T12N R14E UM %. API NL~IER/CAL CODE 4DL 34623 06 T. IF INDIA~, ALOTTEE 0]~ T1RIBE NANII~ 8. L.'NIT,FA/~A! OR LEASE 9. WELL NO. Point Storkersen ~1 ~, OR WILDCAT Wildcat --11. SEC.. T.. R.. 1%i.. (BOT'TOM HOLE OB,mCTIV~ SW7-T12N-R14E-UM 12. PEP.MIT NO. II~ 69--33 RE~ORT TOTAL DEPTH AT END OF MONTI-I, CHANGF.,S IN HOLE SIZE, CASING AND CE1ViENTING JOBS INCLUDING DEPTH SET ~ VOLLrlVIES USED, PERFOP~TIONS, TESTS ANT) RESULTS, FISHING JOBS. JUI~K IN HOLE AND SIDE-TRACKED HOLE ~ ANY OTI-IF, R SIGNIFICA~NT CHA~GES IN HOI~ CONDITIONS. July 1 - 31-Abandoned fish in hole (9 - 7-3/4" drill collars and 10 singles 4" drill pipe Total length 572'.) ' ' Ran temperature survey base of permafrost at 285'. Ran three cement plugs of 450 sacks, 500 sacks and 550 sacks of Class G cement prior to sidetracking fish. Directionally drilled 11' hole off of cement from 373' to 2744'. Ran 8-5/8" - J55 - 36 lb casing. Could not get past 2031. Cemented same at 2031 with 950 sacks permafrost cement followed by 420 sacks of Class G neat cement. Plug down with good returns 3:30 a.m July 24, 1969. ' Headed up with 900 series double gate preventor and hydril. Depth 4987' midnight July 31, 1969. with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. (:'. ( HlJ 1M 11M "~" . OKG .fIIf:1(¡:::. 1"onn No. P-4 STATf ,OF AlASKA SUBMIT IN DUPLICATE REV. 1-30-6'l 5. API NUMERICAL CODE kLV OIL AND GAS CO NSERV A TION COMMITTEE HWK ~ MONTHLY REPORT OF DRI.LLING 6. LEASE DESIGNA nON AXD SERtA4It!l / -= "'1.-- AND WORKOVER OPERATIONS 4DL 34623 06 - 1. 7. IF INDIA)f, ALOTTEE OR TRIBE Nf8E OIL 0 GAB 0 Drillinq Well WELL WELL OTHER 2. NAME OFO:PERATOR 8. UNIT ,FARM OR LEASE NAME HamiltQn . BrQthers Oil Company 3. ADDRESS OF OPERATOR 426" Eagle Street 9. WELL KO. Su~te2 -~9g1e BuUding Anchoraae. ALASKA 99501 PQint StQrkersen #1 4. LOCATION OF WELL 10. FIELD A.~D POOL. OR WILDCAT 500. FWLand 500 I PSL of SectiQn 7 Wildcat 11. SEC., T., R., M.. (BOTTOM HOLE T 12 N R 14 UM oBJECTIVE) E SW7-T12N-R14E-UM 12. PERMIT NO. 69....33 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS "INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNKIN HOLE AND SIDE-TRACKED HOLE AND ANY 9TaER ,SIGNIFICANT CHANGES IN HOL]¡; CONDITIONS. Elevation: Ground 12' KDB 19' #1 Conductor: 65tof 16"TD - 24 "OD Thermos conductor set 651 in ground (841 KDB) with 254 sacks 'permafrost cement tQ surface. 12 'CÖndÙctot: Set 11-'3/4,t -E:I'f)~'~~:'Ibdâstng;t~2;t5Itœåñ.ð.Cemènted.sàmewith'S'51 sacksper.mafrostcement with. returns to surface. Headed up' 'With ,Itf" -9(B'OseriesFIydr!lBOP . Drilled ahead tQ 130(}'KDBw'ith 10-7/8 II bif. Stuck in hole with string bottClm@ 10901. '11, '1 , , Jt~(ft . r&t it /. tJA./".(VtI .. {{ ,", t, ' ",' . ÌI, J '7' " '" f\ )Þ,' f ( '. .,7f,i""t~')~' ~, . ", j( ,< YV"," . yt. A4' t.4, i ¡tI<!t þ«(~!) f7' J Cl'l~" ~,. è,~ '1 ~,vl i \/), "" ~),> /,,,,,'1 Backed offpipe.@ 542KDB. Washing over stuck pipe in hQle. JUL 1 1969 DIVISION OfO:tA:'"m GA3 ANCHORÞGE SIG Drilling and Pro- TITLE duction Superint,?ndent DATE. June 30 I 19ffi9 NOTE---Report on this for is required for each calendar month, regardless Qfthè ,status of operaliQns, and must be filed in duplicatt with the Division, of Mines & Minerals by tlte 15th of the succeeding mo nth, unless otherwise directed. June 12, 1969 ( \ ~ ~~.~ iiWlM PI~ O~G - . '):,-'. tiN" ~';:~:....:.., ~,.",.-~" ,~- .,.,..-( ~ ~\~ ."",' L~-- ~.:.~: ,., C~= ( t.r-' i\ ~_.... . HAMILTON BROTHERS OIL COMPANY SUITE 2 EAGLE BUILDING 426 EAGLE STREET ANCHORAGE. ALASKA 99501 ----~J - . "'-''''''''' .---."'-----~ FILe ------~ Mr. Pedro Denton Division of Land Department of Natural Resources 529 "C" Street i\nc:horage, ,Alaska Re: Hamilton Brothers Oil Company Pt to Storkersen * 1 8W7-T12N -R1.4E-UIVl DearMr " Denton: 'This is to advise that the captioned well loc a tlon was spudded in the morning of June 12, 1969.. Due to laok 'of clear radio oomn'lunicat1ons, an ex,act time 1$ una va Hable to us. Vie will include the time in our end of the month report. Yours truly" HA!vHLTON BROTIiERB ()II. eCH,,,!]? ANY ~~~~~ G. F,. Chapman Production 8uperintendel1t GFC:ame l"/' co Petroleum, Branch Division of Mines a,nd h;11nerals 3001 PorcuPine Drive Anohorage, l\laska, 9950 1 þ./{r It BUl Linton Supervisor Oil & Gas United States .Geological Survey 508 Vlest' 2,ndAvenue - Skyline Suildin!g Anchorage, Ala.aka 99501 ~. , 1\ ~ ~,&'! "11 ';I:(~I ' ') ~,ï ---'; '-ì \.1 ~ ",,:" J Df;ISJrû.1 (': ,"~ ': ,¡J (~\.) J\\",:',~::~ ~ ~'¡'l'~ I""~'>~ JUN 1 0 1969 June 9, ]969 Hamilton Brothers Oil Company 1517 Denver Club Building Denver, Colorado /[ HLB L~--J;., , T~M '"" OKG ~ KLV HWK '" IIEL ~ FILE ~ Re: Point S'torkersen #l sec 7, TI2N, R14E,. UPM Dear Sir: In reference to the subject dri]l-site, the following stipulations are required to protect and preserve fish and game resources: 1. Prior to start of drilling a gravel pad of sufficient thickness to prevent degradation of permafrost will be constructed. a. Access to this site shall be by all-season 9ravel road or by, aircraft. b. Access to this site by winter road will be on!y when surface conditions are such that land damage will not occur. 2. Prior to' the beginning of drilling, a'sump of sufficient size to contain all waste fluids will be constructed. This.sump must be lined.wi:th material impervious to oi'l and oil products at all seasons during the year. Prior t'o abandonment of che site, the sump must be cleaned of all oil and covered. 3.' The operator must dispose of all waste, including garbage, by burning, with non-combustible material and un-burned residue disposed of in a manner and in a location acceptable to the Alaska Department of Fish and Game, i.e., in some locations burial may be suitable, in others removal from the site may be required. 4. Sewage and waste water wi]l be disposed of by lagooning or the cesspool-septic tank method. No stream or body of water will have any sewage or waste water added to it. ., 5. The Habitat Bio]ogistls of'fice, 1018 East International Airport Road, Anchorage, Alaska 99502, will be notified prior to abandonment of this location. cc: B. Hilliker FI. Burrell HAMILTON ]~ROTHERS OIL COMPANY 1517 DENVER CLUB BUILDING DENVER, COLORADO 80~O:~ May 29, 1969 Mr. Homer Burrell State of Alaska Department of Natural Resources Division of 0il and Gas 3001 porcupine Drive Anchorage, Alaska 99504 Re i Dear Mr. Burrell ~ HLB .... ,, OEO KLV FILE Hamilton Brothers 0il Company Application to Drill No. I Point Storkersen Section 7-T12N-R14E-UPM Shown below is a revision of the casing and cementing program for the subject well. Hole Casing Setting Sacks of Kind of .Size Size De.D~ Cem®.n.t Cemen..____t Rema~k.$ 36" 16"x24" 60' 400 sks. perma- 100% excess* (Thermos frost at. ) 15" 11-3/4" , . 10-7/8- 8-5/8" 300' 300 sks. " 100% excess* 3000' 800 sks. " 50% excess _ 300 sks. Class G Amount of cement 1100 sks will depend on call- per survey. 7-5/8- lO,OOO 1600 sks Class G 50% excess Set DV tool at 6500', Cement back to 8-5/8". *Will use enough cement to insure cement returns to surface, If you require additional information, please advise. Very truly yours, DCH, ams HAMILTON BROTHERS 0IL COMPANY Don C. Herron Chief Engineer MAY g 9 I969 FORM Sf, I B MEMORANDUM State of A I"'sl,a DtVlSIOB OF ofi' ~ ~ TO: í Dale HallingtOtl Deputy Q:ma1aaloner DATE i\pril 24, 1969 FROM: Homer L. Burrell Director Point Storkeraen 11 Hæ11ton Brothers Oil ~any Operator EncloHd are the approved applicatiouforpendt todbill, plat and a SUBJECT: cheek in the amount of $50 for fi.l1na fee. iU:" laclø...a FORM SA i B MEMORANDUM State of Alaska DEPM.DIDft' OF BAftIAL USOURCES DIVISIDII or OIL A\ID GAS TO: í .Joe 1181 Dep_taeat of PUb aud c.e DATE: April 24. 1969 FROM: 8Dœer L. ~ll Dtnct- S U BJ E C T: Poiat Stor-"'- 11 HetUoa koth..-s Oil ~.aay Operator .1- flad _lo88d -Wltatkm for: ,end.t to drill ad 1ocatloa plat for the ..... eapt:t.øaed 811.Pl...adYt8e U then. .. .tIJtSY Pløbaad .CJ88. etlpa1atioD1l ,.. wish te have.,.... OR tbe pentk.. PlMø l'8""e1O..-.,1,. 8captioMd above. &at ja &lel..-- FORM SA I B MEMORANDUM State of Alaska lJEPA&DtElffOPIfA1.'UL\1. a.uouaœs D1V1S1t11 ØP OIL ABÐ GAS TO: í Boa it. Shepar. 1acIuatr1al Safety la8pector Depa~ of Labor DATE: April 24, 1969 FROM: I.IDmer L. ButTeI1 D1nctør SUBJECT: Point S~... 11 Bailton Brot11era Oil ~any Operator EaeJ.oøøt! is Ii cop, of tbeappl'OveGapplkatton to _111 for the above capt1øøedwel1. 1&I:jm _18.... , L /7 / r ,I ( HLB TRM _._.~ OKG --."..- KlV -..- }-l'':''.:-: --- --'--- ;'h."'. ~--~- lit~a: .. ,F.., r) P .') -.,~ 1.969 h t' _\ t...-# D'¡~(;I,il~)~~ ila~;ilt;;:.~'f~ '~~t¡'7tbðr.'1~ ,¡:a.l (;t:~~¡p~I'rlY 1511 1}~~1f:V't,Ift Cll¡;!b n~\::tf,1~;;11~f~ *hi$~1'¡V \tS;j¡"r.'(~~) 1 'fr.¥~~;k¡, 011 ,,11nd .G.ti1;$ &t,stil1J(~d,d~ì: :r;kl'!i~d i~Ú112 ~ti 1'¡¡;t~1ßll'" 2~:} 1!J~!tt~ .t: 1 fl~ìhitt~'¡!¡¡::i<ï.i:P¡~~RY ~H! " ~~u 'b,\Mi ~.: tæ:,~d QI $t.~t,'~Wtil'¡i1~ i~iJ, ¡¡It¡~::ul ;¡~J1,ì.!!i kll>tl\1,d \¡ti.t}¡'ï Ul1d.t,~Mt Sti~~;es 'ld~,::l.it)1' ~;U',ltl (~ì1;¡¡¡~.tf¡¡¡¡f.~t::':" ,1t,~ v~~1r.~t1' t"4~.f~1~ :t.\¡'~ ;t~hl~ bo:¡:,¡;~,~ i ,$ b:øt'~;d b(~1~!d, f~,l.~~ wÍ&~;.~~f~¡¡t'Ut'"\~~. ,~t~:M1:a1.:f4~:,a:$\(!!;:t\~ f~~¡~dl~~., ir'.. J. tKillt (~. ,-S-' ,-) r,~'~Jn't¡tï,n::li .~~I J ¡ t¡;:!;.~~. :C,~,": ~~, :~., ~~il~2;~ ~,t)¡')¡;t:t.I;~td ~U:'¡iH;,q;~$ C~tl t't;j~ ~. S,t'!!'~æ.c..tlt:j. ~~~~hi~1q~t;¡,,)~:':, t:il ':¡;~ d. (;~~<, ~;1(NI~ta.r L" ~~Ï$,rr~d.l ~ f¡';)'i.J::~~,~~t¿:n: ,1H.vl$.i{;j'f.l I.()i)f ;():tl X1ið:,JG~,!i'i, ) ¿/'/ í:? ('~~ '0~ Œlr.;~ì\ \-C.,CiI. ~ .- ~"~ :[1 ~~,? \f¡. 'fJ) \l\'t-:i ~.... ~ f-\PR '2 4: ~\959 N Of on. AND GAS DN\S\O At-I,CH<Jí~¡,~!GE: Irm DL-11 Jane, 1962 ( STATE OF ALAS1L~ DEPARTmeNT OF NATURAL RESOURCES Division of Lands STATEWIDE OiL AND GAS BOi{D APR 969 DJ¥I$10N OF OIL .AND GAS ANCHO~.~E No. 677g1-13- 500-69 K,~0w ;,~.',. tuck; ~',' t'~.:s~ pmcs~m's ,-h,~r ,,e. HAMILTON BROTHERS OIL COMPANY, a Texas Corporation, 1517 Denver Club Building, Denver, Colorado 80202 as prtn,:ipal. ,,n,~ UNITED STATES FIDELITY AND GUARANTY COMPANY whose address ls BALTIMO~__~_MAR~ as surety, are held and fir,nly bouud unto the State of Alaska in {'lie sum of Cme iluiidrcd Thuu.q;imt Oullar8 ($100,000.00), !owful money of the United States for the use ami benefit of (1) the State of Alaska, (2) any owner of a portion of the land subject to the coverage of this bond who has a statutory right to compensation tn connection with a reaervation of the oil and gas deposits to tile State of Alaska, and (3) any lessee or permittee under a lease or permit issued by the State of Alaska prior to tim issuance of an oll or gas lease for the same land subject to this bond, covering the use. of the surface or the prospecting fox' or development of other mineral depgstts tn any portion of such land, tox be paid to the State of Alaska. For such pa~,mnt will and truly to be mad~ we bind ourselves and each of us and each of our'heir~, executors, adminis~rator~, successor8 and assigns, Jointly and severally by these present~. The condition~ of the foregoing obligations are such that, whereas: . A. The principal in one or more of the following ways has an interest in oil and gas leases on land~ of the State of Alaska 6ader the Jurisdiction of the Division of Lands of the Department of Natural Resources~ (1) a. the lessee of such leases. (2) as the approved holder of operating rlght~ In all or part of the lands covered by such leases under operating agreements with the lessee, and (3) as designated operetor or agent under such leases pending approval of an assigmnent or operating agreement. B. The principal is authorized to drill for, explore for, develop, produce, process, and market and gas deposits In or under the lands covered by. such leases and Is obligated to comply with 'certain covenants and agreement~ ~et forth In such leases. %C. The. principal and surety agree that the coverage of this bond shall extend to all 6f the principal's holdings under such lehses In the State of Alaska, and without notice to the surety shall also extend to and tnt I ude: 1. ~y such oil and gas lease hereafter issued to or acquired by the Principal, the coverage to become effective ~ediately upon such issuance or upon approval by the State of Alaska of a trax'Bier in favor of the principal; Z. ~y such operating agreement hereafter entered into or acquired by the principal, the coverage ro become effective lnmedlately upon approval by the State of Alaska of the agreement or of a trax. let of *uch an agreement to the principal; 3. ~y designation hereafter or the principal as operator or agent of a lessee under such a lease, the coverage to become effective /mediately upon the filing of ~uch a designation with the State of Alaska; and 4. ~Y extension of a lease covered by iht. bond, ~uch coverage to continue without any Interruption due ~o the expiration of the tem~ ~ec forth i~i the lease; Provided, t~ the surety may elect to have ~he additional coverage authorized under this Paragraph.C become inapplicable an to all interest8 of the principal acquired more than 30 day~ after the receipt of ~ltten notice of ~uch election by the Division of Lands. . D. The surety hereby waive~ any right to notice of and agree~ that rhl~ bond ~hall re~ln in full force and effect notwithstanding: ' 1. A transfer or tranafer~ either in whole or In part of auy or all of th}~.'leasea or of the operating agreements, and further agree~ to reumln bound under thi~ bond as to the .interests either in the lease8 or tn the operating agree~nt~ or In both retained by the prlnctoal when the approval of the tranufer or tran.fer~ beco~, effective; '2. ~y modification of a lease or operating agreement or o~<[,l:8a,t,tona thereunder whether l~de or effected by commitment of such lease or operating agreement ~o unit, coopetrartve, Conn~u{lttlzatlon, or storage agreements, or development contracts. 8u}~penulo{l~ of operations or production, waivers,' s/~spen~lon~, or cbs{igc in rental.' mtn/mrna royalty and royalties, compensatory,royalty paMnent~, o*'otherwt~e .. ~, . ". g. The principal nnd .urety agree that notwlth.tamllng the termination of a~y leave or operating agreements, or dealg.ation~ aa operator or,agen~ ci,verud by this bond, whether the termination t. by operation of law or otherwise, the bond ~hall remain tn full force ami effect as to all renminlng leases, operating agre~ment~, or de~ignattou8 covered by the F. '['he I)L' LITe tl)a l 1t~ oPc. r,~ll'of oI- d.~',~.ill' ()l' ~,pl)ro¥(.(! a~. (,t)(.,'~,Lor ill c()[t:~l(l(.rdl i-,, ()! I)~.i~},, I)~.r.tilll-d l() I.r,ii~li L]llj~4 bond in jit. u of the lcss,'cs agrt0(.b lhou~h he ~eze thc il,. Thc prl,lcipul ami ~urety agree II,al Lhe m:Rlec£ o,' f,rt.l,,aran~e of l{,c lessor In cnforcln~ againsL the lessees of such lessor, the i)aymenL of rentals or royaltlc~ or the perfor,nnnc~, of any other either of ~hcm from lilly liai, lli~y under Lhis bond. H. Tl~u principal and surely ngree I. hal in th~. t. vunl o[ any delaulL under the Icl, scs I:he less;or may ¢onm~ence a,{d pros~.cuLe any cl.~l,n, suit, action, o,' oLh~.r proceedi,u4 a~lali]sr Iht. principal ,,nd surely eiLher of Lhe,n ~i{hour rhc ncccssil:y of joining £he {e-~s~.us. NOW TIIEREFORE, if said pri,icipal shall l,t all ruspucL.s faithfully comply with all of the provlsion~ of the leases referred to here£,mbove, then the above obligatiu,~s az',: to be void; otherwise to remain in full force and e~fect. ' this 19th d,,y o,: March __. 1~ 69 HAMILTON BROTHERS OIL COMPANY ....... : ~~.k~:-._.2_.,%~".~'..- ........ ,VICE -':- " a RESIDENT UNITED STATES FIDELITY AND GUARANTY COMPANY' // ' ' / .... ..' ' Odette Landrum,"-'~ittorney- ~n-Fac'~-=---- ~--~ ~~ Su~-e~y APR 24 1969 DIVISION OF OIL AND GA,5 ANCHORAGE Page T~o HAMILTON BROTHERS OIL GOMPAN~f IS17 DENVER CLUB BUILDING DENVER, COLORADO 8020:~ April 22, 1969 Mr. Homer Burrell State of Alaska Department of Natural Resources Division of 0il and Gas 3001 Porcupine Drive Anchorage~ Alaska 99504 HLB ~ /::-'" ' - OKG KLV HW'.( REL ~-,~ :---, ,,~ -,.~ ~ ...... FiLE ~ ,...,0 ~ DIVISION OF O;L AND ANCHOg...D~. Re: Hamilton Brothers 0il Company Application to Drill No. 1 Point Storkersen Section 7-T12N-R14E-UPM Dear Mr. Burrell: Shown below is a revision of the cementing program which was submitted on our '~pplication For Permit to Drill:" Hole Casing Setting Sacks .of Siz._.__~e Size _Depth Cement Kind of Cement 36" 16" x 24" (Thermos Jr. ) 15" 10-3/4" 60' 315 sks. Permafrost 300'** 360 sks. Permafrost 3,000' 355 s.ks.. Permafrost 440 sks. Type G-4 ~o?e 9-7/8" 7-5/8" 795 sks. 6-3/4" 5-1/2" 10,500' 250 sks. Type G-4 )6,~' 4-3/4" 2-7/8" 13,500' 250 sks. Type G-4 3o~o' *Will use enough cement to insure cement returns to surface. Remarks 100% excess* 100% excess* 50% excess Amount of cement will depend on Caliper Survey 40% excess Amount of cement will depend on Caliper Survey. Plan to cement 3000' of casing. 40% excess Plan to cement 3000' of casing. **Setting depth could be as deep as 1000' depending on the amount of gravel. If you require additional information: please advise. Very truly yours, HAMILTON BROTHERS OIL COMPANY DIVISION OF OIL AND GAS April 2~., 1969 R.e: Po:l.nt Storkersen 11 Haœf.ltonBrotbers 011 Coq¡.any Operator *. it .Ð.'Holt Opecat'i0D8"".~ ~1:bJDBrøtheJ:80'tlC&mp_y 151 )DeaftI'CluBu114t_, Deav.. Celeraclo 1028,2 Dul'St't: ¡&cIoNd pl,e...fiadthe.."roveCl .,lkatføa iø ,emit to 4t'111 the reiet'eDCedwl1..Vell ....I,..aa.deo~e chi'p!saJ:ereqø:tt'ed. App.roval. ofthløpermit 1,$ ,øubJecttoe-.liaec.e w1thtl1ie folløw1-s st.tp'ulatioa8: l. BOrE ,'roar- 1$,øt1a;factoI'Y telO.,SOQ.. feet,. If'wll!.,. drilled be10v tht_ðepth. .Serles lS00'IOPEaltoald he need. 2. Suff:tcieate,ement he ._.51/'211 .and.:;! 7.1St1etud.DI'to eo... :al1potaøtlal1, product'"--- ,aM all eu'tass.trb1s- sueY be t.iedtu w1thcemeat. .3 c :Sub jeet to CoQsenat:l.oa 0I'4e,rUo. 12- Alaøka Ðepartœntof P;tab. _dC.. .tipulatiea., .he.received, w111 be fowardetl tøyou aad w$.11 'bècomecODdttiDn:8;ofsub jeet P8N1t. 1. the 4"i1'el\.t of abaadonmea.tti pleue ftCtl£ytlttsoffit:. ad...tely 10 .....80 that we .., 'have. a vt:mes8;pn'.ø!t. Very truly years, ~L.I\Œrell D1:reetor U:j. Eael0,sur,ê Operator Lease & w~ ~ · ', ~ ~ 1 Hami 1 t o~{'-~r other s Point Storkersen #1 '~'~p ud Date The following information is in the b::::::i: :ile: 1. P-3 ~eport Date . oan~ File 2 -a..-' om "ion Report 3 '~-,: ,: s t o ;-: y 4 '-' 2onal Survey 6 -' ' i gy N d og Blue line ~ Sep ia ~ Sep ia ~, 7. 0,: nc.-.',: Log 8. Fi~:id Trip Report, dated 9. O the'~- HAMILTON BROTHERS CANADIAN GAS COMPANY LTD. 14S0 GUINNESS HOUSE: CALGARY 2, ALBERTA April 16, 1969 Mr. Homer Burrell ALASKA OIL & GAS CONSERVATION COMMITTEE 3001 Porcupine Drive ANCHORAGE, ALASKA 99501 U. S. A. Dear Sir: We.'have received Conservation Order No. 72 granting Hamilton Brothers Oil Company a permit to drill an exploratory well in Section 7, Twp. 12N, Rge. 14E U.M. We very much appreciate your cooperation, as well as those on your staff, and your favorable consideration of our application. The forthcoming Alaska State Land Sale is as you well know, a very popular topic of conversation throughout the Industry and particularly those operating on the North Slope. There have been indications and speculation in certain journals and publications that the sale would be in September. Also we have heard that October is a month which the State is perhaps considering. Hamilton Brothers Oil Company is presently making preparations to drill the Point Storkersen No. 1 well and is presently making studies and evaluating data in an effort to be in a competitive position at the time this sale is held. Therefore, if a sale date has 'not been selected, we respectfully request that consideration be given to a sale date in October or later as oppOsed to a sale date in September. Yours very truly, ,,o~ o~ o~}, ~'? oAS HAMILTON BROTHERS CANADIAN GAS COMPANY LTD. General Manager. MLR/hh HAMILTON BROTHERS 0IL 1517 DENVER CLUB BUILDING DENVER, COLORADO 8020 April 11, 1969 Mr. Thomas R. Marshall, Jr., Acting Chairman State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 RECEIVED .~. ~ ~'~ 1. ~ 'i~.~q ply,sic, oF OIL ^.r, ANCHORAGE Re: Hamilton Brothers Oil Company Application to Drill No. 1 Point Storkersen Section 7-T12N-R14E-UPM Dear Mr. Marshall: As a supplement to complete the subject application to drill, we are providing the following blow out preventer information: Casin$ Set 10-3/4" BOP System 10" Series 900 Hydril and choke manifold Size Hole Bein$ Drilled 9-7/8" 7-5/8" 8" Series 900 Shaffer Type LWP double hydraulic preventer 8" Series 900 Hydril and choke manifold 6-3/4" 5-1/2" 8" Series 900 Shaffer Type' LWP double hydraulic preventer 8" Series 900 Hydril and choke manifold 4-3/4" If you require additional information, please advise. Very truly yours, HAMILTON BROTHERS OIL COMPANY Don C. Herron Chief Engineer DCH: ib RECEIVED DIVISION OF OIL AND JAMES J. DELANEY, JR. EUGENE F. WILEs DANIEL A. MOORE, JR. GEORGE N. HAYES JOHN K. SRUSAKER DELANEY, WILES, MOORE & HAYES ATTORNEYS AT LAW 360 K STREET ANCHORAGE. ALASK~A 99501 March 17, 1969 TELEPHONE 279-358! AREA CODE 907 Alaska Oil and Gas Conservation Committee Division of Mines and Minerals Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 Re: Application for Drilling Permit and Well Spacing E. xception Gent lemen: You will find enclosed herewith an application for a drilling permit and a verified Application for Well Spacing Exception with attached plat. The application is submitted on behalf of our client Hamilton Brothers Oil Company. Inasmuch as there are no affected operators..as.,.:c.on- templated by Section 2061, of Title ll, Division 2, Chapter l, Subchapter 2, Drilling Regulations. of the State of Alaska, we served no notices on other parties. We are, however, enclosing herewith additional copies of the application if you desire to send out complementary copies. Your early and careful consideration of the foregoing application is greatly appreciated. Yours very truly, EFW/cs Encl. D~NEY, WILES, MOORE & HAYES L.~'"'/ . /' ]Form I~"V. 9-30-6; SUBMIT IN Tr,' (Other fnstruc6, reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DEEPEN [-] IR. TYPE OF ~VORK DRILL OIL WELL ~ GA8 WELL PLUG BACK [--1 8INGLE OTHER ZONE [] MFLTIPI,E ZONE [] ~mi ltnn 2~nth,=.w.~ Oi 1 anm~nv ~.t al 3. ADDR~-~ O~ OPF, R~TOR- ~ 1517 Denver Club Bldg. ~ Denver~ Colo. 4. LOCATION OF WELL At surface 500' FWL and 500' FSL of Section At proposed prod. zone T. 12,Ns R14E. , UM Same 13. DISTANCE IN MIT.mS AND DIRECTION F-~OM NEAREST TOWN OR.POST OFf'iCE* Approx. q00 miles north 14'BOND INFOrmATION:Bond iS being applied for - will De rile~ .~,t. ,,' pgddi · .. TYPE ,,!~J'~ ,':..' ..' .:...r. ,' Surety and/or No...': {. '[. ' " · ....... ': ' .' , .... ) ' .','" , ., / / t~ .i' / 15. DISTANCE FROM PROPOSED* LOCATION ~ NEAKEST P~oP~TY o~ L~AS~ u~m, ~T. 2 -- ~ 0 (A~ to nearest drip, untt, ff any) ~8. DXSTANCE ~O~ PROPOSED ~CA~O~* TO NEA~T WE~ D~ILLXNG, COMPLEX, OK APPL1~ FOR, FT. Approx. 9.5 ~1. ~.mV~TIO~S (Show who~her D~, ~T, ~, etc. t16. NO. OF ACRES IN LEASE 2~227 ~. PRoPos~ D~ 13,500~ Ground 12 ' PROPO..~;,~ CAS.lNG A_ND CEMENTING PROGRAM AP1 50-029-20016 $. LEA~E Da.~IGNATION AND SERIAL NO. ADL 3~623 0G ~. IF INDIAN, ALLOTTEE OR TR~E NAME 8. UNIT, FAI~/I OR TJ~.A.~I~. NA1VXE ' Point Storkersen ~). W~r.r, NO. # 1 ~0. F~? .D AND POOL, 01% WILDCAT Wildcat 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 7, T12N, R14E, ~efore ~?. No. ACRES ASSIGNED TO THiS WELL Approx. 100 + 20. ROTARY OR CABLE TOOLS Rotary 22. APPROX. DATE WORK WILL START* May 15, 1969 " UPM SIZE OF HOLE PER FOOT GRAI~E SETTING DEPTH QUANTITY OF CEMENT 255' cu. ft. I AR :1. I969' ~,~I$1ON OF OIL AND GAS 1~ ABOVE SPACE DES'CI~BE PROPOSED PI~OGI~A.~: If proposal ~ W dee~n or plug ~, give ~ on presen% p~du~ive ~ ~ proposed ~w p~du~ive ~. II P~sal is ~ drill or d~n ~e~ '.on~ly, give pe~nent ~ on subsu~ ~ca.~ ~d m~s~d ~d ~ue ve~ical dept. Give bl~ut preventer p~gram. ~. Z hereby ce~pshat t4~oregotn~is~e ~Corre~ (This spa~ ~or S~te offi~ u~) CONDI~ONS OF ~P~V~, IF ~: iSAA{PT.~. AND COI{E ;-"~'S REQUi~-~, ~ yES [] No i DiP~EC'r~ONAL SURVEY YES [] NO P~TSO ~''~' - ,.5 3__,, ~OWL~A~ April 24 1969 o~ec~or ' APPROVED BV ,~z~.,,.,Div. of 0il & Gas DA~ April '24~.. 1969 *See Inductions On Reve~ Side * Ser~es ~500 BOPE required belo~ 10,500 fleet. Cement sh~ll cover ~11 potentially . productive ~ones ~nd ~1 c~s[n~ s~r[n~s sh~ll be ~[ed in ~[th cement. I LAT. 70° 124' 09.73" I LONG 148° 41' 48.47" I-- -Y- - 5,998,5c. 2 X = 660,0 96 24 I I I 19 25 · CERTIFICATE OF SURVEYOR I I I 2q i 27 i I I i _ _ _1 SCALE-' I"= IMILE T. 12N I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a Iocotion survey made by me or under my supervision, and that all dimensions and other details are correct. ." Date. MAR 18 I969 ,DI¥1~ION O~= OIL AND GAS DETAIL PT. STORKERSEN NOI U.M.AK. Surveyed for HAMILTON BROS. et. al Surveyed by F.M. LINDSEY I~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYO'RS 2502West Northern. Lights Boulevord Box 4-081 Ancho,roge Alosko 4. 1\' 5. ~~, 6. I,"",." 7. ~'I' " ì', ,1, ~ ~" CHECK-LIST FOR NEW WELL PERMITS 1. Is well to be located in a defined pool.............................. y~,~. M,£Io Remarks ,dM. 2. Do statewide rules app ly ........................-.................... 1t\1 3. Is a registered survey plat attached......... .f........... ~. 0........ (1)\.1, - Is well located proper distance from property line.................. - ~ Is well located proper distance fro",1 other wells....................~ - Is sufficient undedicated acreage ;'.vailable in this pool. 0.......... Is we 11 to be deviated... 0 .. . . . 6 .. . .S . . . . . . . . . . . . . . . . . . . . . . . .' . . . . . . . . .. L <JM 8. Is operator the only affected party ....0............................ .Œ1 mt{- Is 'e.onduetorstrtDg.prov1ðéd'........ ~.~,...~.~...~....~~~~..~ïI:.,' ' Is tmougbcementused to circulate on conductor ,and su~~~;~......... ¿51 , surface csg. internal burst equal .5 psi/ft. to next~tring .. .., Jd. Will ::e::s::-:v:u::::a:e i:::::d::t:o::~se and tension...:::: :;XJ¿ ,,,. 9. Can permit be approved before ten-d¡lY \.¡ait .......................... 11j¡;:: ' ~.} . ,"i 10. Does operator have a bond i.n force................................... ¡l¡, " :,,~ ' It:.', ..1.1. . 0'. ¡",þ,l~ '. ~j~;i)lt. /'/" ).6~.",,- Will cement eover\allpossible productive horIzons . . ~'. . ... '. . 9< 0 .. . .. . . . ~;:: . ,Will surface caslng cover al1freshwáter zones.......... ~....... ...... itJ.. \1M ~::; f~v c. 0 . '7 L e.la'if,e5 ç'-~'L. C.O 7 L- _""''''''''",,>,-., :."Þ''''''..a.~'~'''-~\'''''w " , I ( [' .~ <1M - ~..... I'IU\ '~~Q.~~wll e AQL ß6~d )16 + '1 ~f-v~~'el!. .~~_:~ . J;I:III~---'--I\Q<;;I;""''r.,.,q"".' :.1 9 ..-.,,',; \.',:. ; '-~~ r~i~';;;;;-- 18. Does BOPEhave sufficient pressureráting ..1~r- ~ ......t.................... Ii;; ~ I ;~i:';<19 \~. , '~r:~i}¡::~ , iA.pproyalReçommended: ~¡~ , /U ~~A'~,/. '..'.'.'. .'......)'.'.., "<"i..>.~~be,I'~>E~~~r~()~ ..'. .....~.'-!--. f:cf/~~!!,~~~..~.'$~1!~~~ M~-~.ý~~ _LL__-'-----1.-~:_J¡¡J'~'::3?~~~;';::~t.::...~.:c_~-~~~~~~ ~:;C?:;E; -~-_.. .. ..-'=" --"._--- .'. - ...-".--- =--=-=~ r.,' ;~~:.' Harry .W. Kuglér,' ;¡¡1,;¡;V1,.o. K.' Gilbret'h~:ir.' i:~:~<- ~. -.;,. ;~I~~¡;"~'<;::(.. ":, ~. . ~.. .. . ~!.._:ß(i!~~~~.~:~~-~.:~.-- -------. -~~-_.'.J .
