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Home My WebLink About184-157 Ima~lgroject Well History File' C( e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ! ~ ~- _J ~ ~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) / Co,or items: ~-Jh O~:)~,, [] Diskettes, No. 13 Maps: n Grayscale items: D Other, No/Type 13 Other items scannable by large scanner [] Poor Quality Originals: .... OVERSIZED (Non-Scannable) o Other: . NOTES: ~''~D/': Logs of various kihds [] Other BY; BF_~Y BREN VINCENT SHERYL MARIA LOWELL DATE: Project Proofing BY: BEVERLY BREN V~ SHERYL MARIA LOWELl. Scanning Preparation ~'7 x 30 = <;~ i,O + /S = TOTALPAGES ~ ,~-~ Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES ..~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: ~~ NO E~ ' BY~ BEVERLY BREN VINC ARIA LOWELL DATE . ., 1si ReScanned (individual page [special attention] scanning completed) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS/ General Notes or Comments about this file: Quality Checked {done) 10125/02Rev3NOTScanned.wlxl LOCATION C~,EARANCE REPORT State cf A!ask~ .ALASKA OIL & GAS CONSERVATION COMMISSION -:--~ ~o. ~5" t5 7 Lease A71 No. 'We i ! }fame Ouera~or - Lccat±on Review the well file, and' ccmmenzt on plugging, well head scat-as, and !ocaticn clearance - provide loc. clear, coda. Well head cut off: Marker pos~ or plate: Loca~ion Clearance: Code February 15, 1990 Telecopy No. (907) 276-7542 Amoco Production P 0 Box 160779 Anchorage, AK 99510-0779 Re~ Becharof #l, Sec. 10, Twp 28S, Rng 48W, SM Dear Sir or Madam: In compliance with regulations set forth in Chapter 25 of the Alaska Administrative Code, your company has dutifully submitted to the Commission sepias of various logs run on the subject well. However, due to age and frequency of use, 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 material maintained for permanent reference in the Alaska well log library, the Commis- sion would appreciate receiving fresh sepias of the following logs: DIL-SP-GR DIL-SFL-GR LDT-CNL-NGT LSS SHDT Dual Dipmeter CST RFT BHC/SL Please direct any questions you might have in fulfilling this special request to Larry Grant at 279-1433. Thank you for your contribution toward maintaining a good State well log library. Sincere ly, ~.'~- ...' .' Robert P Crandall Sr Petr Geologist jo/L.LJG.01-02 March 3, 1987 Amoco Production Company Denver Region 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303-830-4040 Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Amoco Becharof St. #1 Cores #1 and #2 As per your request of February 18, 1987 to W. G. Smith of our Anchorage office, enclosed are copies of the core analysis report and core description from core 1 and 2 from the Amoco Becharof St. #1. Sincerely yours, Robert S. Tucker Staff Geologist cc: K. W. Unger - Anchorage RST.1 RECEIVED Alaska Oil & ALASKA OIL AND ~AS GONSEIIVATION'COMMI$$10N /3oo~ PORCUPINE DRIVE We wish to bring to your attention that the Commission has not yet received the following required items on the su 'b~ct well which our records indicate was completed ~-/~- ~ Section 71(b) of Title 20, Chapter 25, Article I, Alaska Administrative Code, stipulates that operator shall file this material with the Commission within 30 days after completion,' suspension, or abandonment of a drilling well. Please submit the missing material listed above. eiely' Chairman jo/C.024 ; Receipt of ExplorationData Form · , Alaska Oil and GAs Conservation Commission Attn' Fran Jones 3001 Porcupine Dr. Anchorage, Alaska 99501 ,. -01232 Amoco Production Company 1670 Broadway ~ ra. I 2~ O~ P.O. Box 800 . Denver, Colorado 80201 D.~e' 10/14/86 Transmittal No. PD- Subjeat: Becharof State #1 We transmit by .the following: REG. NO. First Class DESCRIPTION OF ITEM QUANTITY 1 mylar ~ Dipmeter 8040'-9016' 1 mylar, 1 paper print . Dipmeter 1888'-8055'. . DISPOSITION; Sender'y~ignature PLEASE SIGN AND RETURN ,COPY OF THIS MEMORANDUM Above items received, except as noted: · j - . · · Date ;. White -- Addressee {retain) Yellow --Address (sign and return to sender) Pink -- Sender's "hold" file DN--2 APR--II5 Receipt of Exploration Data Fd~ TO: Alaska 0il and Gas Conservation Commission Attn' Fran Jones 3001 Porcupine Dr. Anchorage, Alaska 99501 N? -61232 Amoco Production Company 1670 Broadway/~ P.O. Box 800 Denver, Colorado 80201 Date 10 / 14/86 Transmittal No. PD- Subject: Becharof State #1 We transmit by Fi rst Cl ass QUANTITY DESCRIPTION OF ITEM 1 mylar Dipmeter 8040'-9016' 1 mylar, 1 paper prinj Dipmeter 1888'-8055' the following: REG. NO. DISPOSITION Sender',~ignature PLEASE SIGN AND RETURN COPY OF THIS MEMORANDUM Above items received, except as noted: Date White -- Addressee (retain) Yellow ~Address (sign and return to sender) Pink ~ Sender's "hold" file DNa2 APR--85 OCT 2 ~ Naska Oil & AGnacShoOr°a;:' Cornmk~s~e. August 27, 198~ AHOCO F~oduction Co~any Post Office Box 100779 Anchorage, Alaska 99510 Attention: Nr. W. Q. Smith Re: LO 84-95 Dear Nr. Smith: On ~une 19, 1984, Amoco applied for a Lease Operation Permit ?rom this office to drill an oil and gas well for the remotely located Becharof State Well No. 1. The well required a temporary airstrip, ~ell pad and an operations camp. On August 22, 1984, this office, in concert with other resource aoenctes, authorized the above activities on state land. On August 12, 198~, you requested that this office provide Amoco with a letter that would release your corporation from any further obligations and close this casefile. Our ~eview of the file indicates that in the intervening two-year period, your corporation and it's contractor built the runway, drill pad and camp, and explored for oil. Upon completion of the exploration activities, Amoco removed the camp including the runway and Gravel pads.-A considerable effort was expended by Amoco to revegetate and restore the lease area to its fo~mer condition. Representatives of the Department of Fish and Gam, e visited the site when they were ~.n the area on reou!ar business. Th.e reports and photographs that they have provided indicate that your efforts at restoration appear to have been successful. With this letter ~ release the ~oco Production Company of any further responsibilities regarding., the reclamation of this well site for activities authorized in the August 22, 1984 Plan of Operations, LO 84-95. Sincerely, Hargaret $~Hayes Regional Nar~aoer MOH:~B:ef:O857e Telecopy No. (907) 276-7542 August 5, 1986 Mr. W. G. Smith District Manager Amoco Production Company P. O. Box 100779 Anchorage, AK 99510-'0779 Re: Final Location Clearance Becharof Well No. 1 Permit No. 84-157 Sec. 10, T28S, R48W, SM Dear Mr. Smith: On September 4, 1985 Mr. Klm Sundberg, Habitat Biologist, Alaska Department of Fish and Game, and others inspected the above referenced location. Mr. Sundberg again inspected the location in June, 1986. Rehabilitation and clean-up were acceptable. The casing had been cut off below ground level, and a marker post with the required information bead welded on it was installed. The rat-hole casing had been cut off at ground level. Consequently, final location clearance of Becharof Well No. ! is approved. Sincerely, Lonnie C. Smith Commissioner jo/A.HJH.24 July 7, 1986 Mr. W. G. Smith District Manager Amoco Production Company P. O. Box 100779 Anchorage, AJK 99510. Telecopy No. (907) 276-7542 Re: Location Clearance Becharof Well No. 1 Dear Mr. Smith: A review of our records shows that final location clearance for the above referenced well has not been approved. In compliance with Section 170(a) of our regulations,-"[t]he location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment or .... " Section 170(b) provides the means for an extension of time if a valid reason exists, and Section 170(c) provides for an on-site inspection. We are, therefore, requesting a schedule from you for this summer when our field inspectors can accompany your representatives to the well site for final location clearance inspection. jo/A.HJH.6 STATE OF ALASKA ~-~_.: ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 RE: Receipt of the following material which was transmitted via is hereby acknowledged: ~QUANTITY DESCRIPTION -~2 Z-~, LF--., ¢1 RECEIVED: DATED: CoPy YES sent to sender NO ALASKA OIL AND BAS GONSEIIVATION*(',OMMI$SION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 09501.1.3192 TELEPHONE(g07) 270,-1433 DATE: L~/V ~'/. /q~" / RE: Well r~ ~o~t ~o. ~ ¢-/~7 We w~sh to bring to your attention that the Co~ss~on has nofi yet received the following required ~tems on the subject well which our records ~nd~cated was completed . ~ . '~,% · Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. submit the above missing material. Please erelx )//~ ~/ Chairman lc:C.026 ~ 01 '85 ANCHORAGE DISTRICT ~D~-_ ' ' ' DF '7-- MEMORAN'uUM State'of Alaska To:Mike Budbill DATE: September 17, 1985 Natural Resource Officer Division of Land & Water ManagementF~LENO:0784-IV-201 Department of Natural Resources TELEPHONE NO: ( 9 0 7 ) 2 6 7- 2 3 4 6 · , ,,. ,unc, ,er,, Habitat Biologis't~ ~' ~ Region IV Habitat Division Department of Fish and Game SUeJECT: Inspection of Becharof State No. 1 Well Site and Hercules Runway On September 4, 1985, I inspected the site of the Becharof State No. 1 well and Hercules runway located on the Alaska Peninsula in Sections 3 and 10, T. 28S., R. 48W., S.M. I was accompanied by Stoney Wright of the Division of Agriculture/Plant Material Center and by Dick Sellers of the Division of Game. Access to the site was by a chartered Beaver on floats from King Air Service landing on a small unnamed lake in Section 2. Our inspection consisted of an aerial overflight followed by a ground survey. Most of the disturbed portions of the site were covered on foot during the 3.5 hours that we spent on the ground. The heavy equipment trail from the site to Pilot Point was surveyed by air. Photos were taken of the site both from the air and ground. Photos were taken of the trail from the air. In general, the well pad, solid waste disposal site (mud pit), and runway appear to have been effectively reclaimed with several exceptions, notably a materials borrow pit on the south side of the runway and a road leading down to the unnamed lake. The seed mix which was applied on or about June 11, 1985, has germinated and overall coverage is good. The most notable grass shoots are Bering Hairgrass followed by Bluegrass and Fescue. A small amount of weed contamination including Mustard, Rape, Clover and Lambsquarter was also noted. No significant regeneration of native vegetation was observed except where the vegetation mat was incorporated into clods of organic materials. The clods of organic material that were spread while in a frozen state during early spring have created an irregular hummock landscape that may develop into islands of native vegetation in the future. These provide habitat diversity and topographic relief and they may be used for Arctic ground squirrel and vole burrows in the future. The hummocks have an additional benefit of discouraging the landing of wheeled aircraft on the reclaimed runway. Both caribou and fox tracks were prevalent throughout the site. Some of the peripheral areas around the site appear to lack organic soils and are consequently sparsely revegetated. This may be due in part to thin organic soils KELE~vEu 02-001AfRe¥. 10179) A~$k8 Oil & G~$ Gons. Oommission Mike Budbill -2- September 17, 1985 stripping as well as losses due to handling the materials during stripping and respreading. A notable area at the southeast "turning" area of the runway has the appearance of sand dunes. A native beach rye grass (Elymus sp.) is invading the sand dunes from the adjacent tundra and may in time revegetate this area. Sandy patches similar in appearance to this area are an occasional feature of adjacent portions of the Alaska Peninsula tundra. The unvegetated borrow pit encompasses approximately two acres and consists of a gravel-sand-silt highwall, several benches and a water filled depression. Gullies, slumps, washes, and other erosional features are prominent along the side slopes of the pit. The side slopes are approximately 1:2 with some areas 1:1 and 2:1. No successful seed germination was noted in the pit. It is likely that the seed has washed off of the slopes and been buried in sediment. The muddy areas around the pond may eventually revegetate in sedges although no revegetation was noted. It is anticipated that the side walls will continue to erode and fill in the lower portions of the pit until stability is reached. Revegetation of the pit will be very slow until the soils stabilize and an organic layer can be reestablished. The road leading to the unnamed lake in Section 2 is also unvegetated. While it appears that some efforts were made to respread organic materials over the road bed, it could not be determined whether the area had been seeded because there was no evidence of any grass seed or sprouts in the soil. Fortunately, the soils do not appear to be eroding even though parts of the road leading down to the lake are relatively steep. Soil erosion would probably cause turbidity and other water quality problems in the lake. This area may be amenable to hand seeding although natural revegetation may also occur from the respread organic material and surrounding tundra. Other observations include: · · The "plugged and abandoned" monument is in place. A well casing adjacent to the monument is expg_s~_ at th~ grou-n-d-s~ac~.a~.~!~s.~ ,_fill?~.~ith__~w~t~ The solid waste disposal site including the mud pit is bermed and revegetated. No evidence of solid waste was seen. 3. Most of the litter has been removed from the area. A few pieces of metal and~i~.~_~e~e_.sq~tter~d ~bout. Mike Budbill -3- September 17, 1985 · The test course on the tundra where two D-8 dozers were driven on frozen and lightly snow covered tundra on March 12, 1985 was examined. The dozer tracks are clearly delineated by brown (dead) vegetation. It appeared that the track that had been modified with welded shoes resulted in a greater dead loss of vegetation. Although the soils and mat are compacted, the loss of vegetative cover may result in eventual soil erosion and "blow outs" in the future. If the vege~.ation loss is a temporary event, the invasion of plants from the adjacent tundra will revegetate the tracks. This test course should be monitored to observe how the vegetation and soils react in the future. · The heavy equipment trail from the well site to Pilot Point is more or less clearly visible from the air as a brown (dead) stripe on the tundra. Individual dozer tracks are noticeable in several areas where they deviated from the trail surface. There is no significant damage to soils visible from the air but the loss of vegetation may lead to future wind and water erosion of the trail surface unless plants successfully reinvade from the surrounding tundra. If additional traffic occurs on the trail surface by off-road vehicles, revegetation will be retarded. Valuable information on long term impacts to the tundra surface may be gained by monitoring the trail surface in the future. In summary, the reclamation of the Becharof State No. 1 project site appears to be generally successful although two notable areas, the borrow pit and the lake access road have not been revegetated. To be totally effective, additional work in the borrow pit will require that heavy equipment (i.e., dozer, loader) be moved back to the site. However, the disturbance caused by moving heavy equipment back to the site would cause more impact than the benefits realized by successfully reclaming the pit. The lake access road is probably amenable to additional reclamation (i.e., seeding) using hand labor. In the future, land use permits should contain a stipulation requiring inspection by Division of Land and Water Management (DL&WM) of the grading and recontouring of the site before heavy equipment is moved offsite. This will maintain the option of accomplishing additional restoration work while it is still feasible and practical. The land use permit stipulation that requires sufficient ground frost (i.e., 1 foot) and adequate snow cover (i.e., 6 inches) Mike Budbill -4- September 17, 1985 should be retained for all future authorizations of overland transport of heavy equipment on the Alaskan Peninsula. It is apparent that the low ground pressure (rollagon) mobilization during September 1984, and the high ground pressure (dozer) demobilization during March 1985 caused at least a temporary loss of vegetation along the trail surface. The way in which the trail surface heals could provide us with some valuable information for future surface disturbance on the Alaska Peninsula. Additional annual monitoring by ~he state should continue to determine the success of this reclamation effort and the eventual restoration of the heavy equipment trail. cc: Stoney Wright, DA/PMC Tom Zimmer, Amoco Production Co. Dick Sellers, ADF&G Tim Hostetler, BBCRSA Bruce H. Baker, ADF&G Harold Heplund, AOGCC~-- ALASKA OIL AND 6AS CONSERYATION COM¥1SSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 995014-3102 TELEPHONE (907) 279,--1433 DATE: TO: RE: Permit .No. We wish to bring to your attention that the yet received the following required items which our records, indicated was completed Commission has not'- on the subject well o/- 17- · Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. · erely. )/~ Chairman lc:C.024 Amoco Production .Company Denver Region 1670 Broadway P.O. Box 800 Denver, Colorado 80201 303 - 830-4040 June 28, 1985 Hr. Mitch Henning D.G.G.S. Eagle River Complex P. O. Box 77-2116 Eagle River, AK 99577-2116 Re' Chips from Amoco Becharof State #1 Sec. lO-T28S-R48W SBM , re 1' 2722-2746 re 2' 3663-3694 -e 3' 7895-7942 ] Core 4' 9013-9023 · Enclosed are chips from the Amoco Becharof State #1. Cores 1 and 2 were cut in unconsolidated sediments with a sleeved core barrel, hence the disaggregated nature of the samples. Should you have questions, please contact me at 303-830-4479 Robert S. Tucker Staff Geologist RST/lp Enclosure MEMORANDUM TO: THRU: FROM: stateof Alaska ALASKA OIL A~D GAS CONSERVATION COFR4ISSION C_. V~z~at terton Lonnie C. Sm±th?? Comm±ss ±oner Doug Amos ~-~. Petroleum Inspector DATE: February 26, 1985 FILE NO: A. ADA. 4 TELEPHONE NO: SUBJECT: Witness the P&A of Amoco's Becharof No. 1 Well. Sec..10, T28S,R48W,SM, Pe~t No. 84-157 on Parer Rig No. 122. F~iday, January 18, 1985: I traveled this date from Anchorage to Amoco's Becharo{WellN~ 1 to witness the two top plug's for the P&A. Saturday~ January 19, 1985: At ~:10 am a cast iron bridge plug was set zn the 7 casing at 4,15 . 30k !b's of weight was used to set the plug and a 1 bbl 27' Class "G" cement, plug at 15.5 ppg was placed above the bridge plug. At 8:30 am a second cast iron bridge plug was set in the 7" casing at 120'. 35k Ib's of weight was used to set the bridge plug. The plug was tested with 1500 psi for five minutes, then a 3 bbl 100' Class "G" cement plug at 15.5 ppg was placed above the bridge plug, extending to the surface. The stack was removed and the 7" caszng was cut approximately 3' below final grade. A 1/2" steel plate and a 2"x4"x10' steel marker post was welded to the 7" casing stub. As the attached pictures show the required information was bead welded to the marker post. Attached to this report is a summary of all perforation and plugs placed in the wellbore before my arrival. In summary, I witnessed the final two plugs for the P&A of Amoco's Becharof Well No. 1. Pictures in file/Attachment 02-00IA(Rev. 0t791 W. G. Smith District Manager February 25, 1985 Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 File: TJZ-O68-WF PERSONAL AND CONFIDENTIAL Mr. C.V. Chatterton, Chairman Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Well Completion Report Becharof State Well No. 1 Bristol BaS, Alaska Attached in duplicate is a State of Alaska Form 10-407, Well Completion or Recompletion Report and Log, for the subject well. The well was abandoned on January 19, 1985. We plan to notify your office for the final onsite inspection of the location in September 1985. An inclination survey, well history, additional well logs, and core chips from Core No§. 3 and 4 are included. Core chips and analyses are still being obtained on Core Nos. 1 and 2 and will be forwarded as soon as possible. Very truly yours, W. G. Smith District Manager Attachment KLS/dds RECEIVED Alaska 0ii & Gas Cons. C0mmissl0m Anchorage STATE OF ALASKA ALASKA's,, ~ AND GAS CONSERVATION-C(~.~IlSSlON 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED ~zi ABANDONEDJ~ SERVICE [] 2. Name of Operator 7. Permit Number Amoco Production Company 84-157 3. Address 8. APl Number P.O. Box 100779. Anchorage: Ala_~ka qg.gl, rl 50- 285-20001 4. Location of well at surface 9. Unit or Lease Name 500' FNL, 1,000' FEL, Section 10, T28S, R48W, S.M. Becharof At Top Producing Interval 10. Well Number At Total Depth 1 1. Field and Pool' 500' FNL, 1,000' FEI_, Section 10, T28S, ~ .S.M. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 201.7' KBI ADL 304952 '"II~,! _. DOAT 12. Date Spudded 11-16-84 13. Date T.D. Reached 12-16-84 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mploti°ns 01-19-85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9,023 0' - 0' YES [] NO ~I N/A feet MD 0' 22. Type Electric or Other Logs Run See Attachment 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 13.375 5~,.5#72# K55;S-95 O 82' ,Driven N/A Nnne 9.625 .~7# NSO, K095 0 1,888' 12.25 800sx Class 'G' None NT-95 + 22 sx TOP JOB . 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) NONE RECEIVED N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~'E~ 2~' 1~85 DEPTH INTERVAL (MD) AMOUNT& KINDOF MATERIAL USED 4,217-3,560' 100 sx Class 'G' Behin'd-'- Alaska Oil & Gas Cons. Commission 7" casinq Anchorage 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS'OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. COP E DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Core No. I on 11-26-84 from 2,725 to 2,750 feet - recovered 25 feet fine grain sandstone and siltstone - core analysis to follow. Core No. 2 on 11-28-84 from 3,666 to 3,716 feet'- recove*red 31 feet of sand and shale - core analysis to follow. Core No. 3 on 12-05-84 from 7,895 to 7943 feet - recovered 47 feet sandstone and siltstone - see attached core analysis. Core No. 4 on 12-17-84 from 9,013 to 9,023 feet - recovered 10 feet of metamorphozed green schist - no core analysis done. Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. SEE ATTACHMENT 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true a~correct to the best of my knowledge iNSTRUCTIONS - General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". 30. Formation Testy DST NUMBER DATE 12/26/84 2 12/27/84 3 12/28/84 12/30/84 5 12/31/84 12/31/84 01/01/85 8 01/02/85 01/03/85 10 01/04/85 11 01/08/85 12 01/10/85 13 01/12/85 14 01/17/85 15 01/18/85 BECHAROF STATE NO. I INTERVAL FEET PERFORATION AND RECOVERY DATA 8,300 - 8,332 Perforated 4 SPF, 0.5" holes. DST soul foiiure, nu r~cover~y.. 8,300 - 8,332 No recovery. 7,780 - 7,880 Perforated 4 SPF, 0.5" holes. Total recovery 2,392 feet (15.7 bbl) drilling mud, water. No shows. 7,470 - 7,550 Perforated 4 SPF, 0.5" holes, DST tool l_~d, 0.9 bbl recover3/, dri 11 ing mud. 7,470 - 7,550 6,860 - 6,960 6,860 - 6,960 Flowed gas to surface, 30 MCFD 30 . ~psig Perforated 4 SPF, 0.5" holes. DST tool failure, ~ Perforated 4 SPF, 0.5". holes. DST tool failure, no recover_y_. 6,860 - 6,960 F1 owed gas to surface, 50 MCFD @ 10-50 ps ig. 6,640 - 6,655 6,640 - 6,655 7,660 - 7,760 Perforated 4 SPF, 0.5" holes plugging DST tools, no recovery. Flowed gas to surface, .t 10 MCFD @ 14 psig. Perforated 4 SPF, 0.5" holes recovered 1,900 feet (12.5 bbls) muddy water - no shows. 7,660- 7,760 Recovered 1,000 feet (6.5 bbls) of muddy water. 6,030 - 6,090 Perforated 2 SPF 0.5" hOles ReCovered 597 feet (4 bbls) of water. 4,201 - 4,211 Perforated 4 SPF, 0.5" holes Recovered 1,019 feet (6.7 bbls)- gas cut water. 4,201 - 4,211 Recovered 1,430 feet (9.4 bbls) RECEiVEDo water. FEB 2 5 1985 ~l.s~ Oit & Gas Cons,.Oommission Anchorage '30. Formation Te'~.~-~ (continued) DST NUMBER TEST TIMES AND PRESSURE DATA Test Times- IO 13½ min.; ISI 69 min.; Final Flow 15 min. Final SI 40 min. IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START 4197 728 749 749 749 4123 END 749 1457 749 1089 DST NUMBER TEST TIMES AND PRESSURE DATA Test Times' 16½ min.; ISI 109 min.; Final Flow 230 min. Final SI 476 min. DST NUMBER IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START END 3982 779 997 997 1804 3726 997 3469 1804 3469 TEST TIMES AND PRESSURE DATA Test Times: 4 min.; ISI 63 min.; Final Flow 45 min. Final SI 130 min. IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START END 3687 753 1103 1003 529 3724 1103 2588 529 3375 · :.~ as Cons. Anchorage 30. Formation Tes~.-~s (continued) DST NUMBER TEST TIMES AND PRESSURE DATA Test Times: IO 245 min.; ISI 475 min.; Final Flow None Final SI None. PRESSURE DATA (psi) START END IHP 3389 IOP 1387 2419 ISIP 2419 3153 FHP 3377 DST NUMBER 10 TEST TIMES AND PRESSURE DATA Test Times' IO 11½ min.; ISI 68½ min.; Final Flow 62½ min. Final SI 144 min. IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START- END 3290 232 853 900 1325 3227 853 2631 1375 2842 DST NUMBER 11 TEST TIMES AND PRESSURE DATA Test Times: IO 127 min.; ISI 37 min.; Final Flow 37 min. Final SI 100 min. IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START END 3739 1225 1924 1994 2030 3736 1924 2937 2030 3286 REC£ VED Gas Cons. CommiSsion Anchorage 30. Formation Te"_,-~_s (continued) ~-~ TEST TIMES AND DST NUMBER PRESSURE DATA 12 Test Times: IO 122 min.; FSI 240 min. PRESSURE DATA (psi) START END IHP 3669 IOP 580 981 FSIP 981 3076 FHP 3669 DST NUMBER 13 TEST TIMES AND PRESSURE DATA Test Times: IO 240 min.; FSI 240 min. PRESSURE DATA START END IHP 2934 IOP 774 FOP 896 FSIP 1749 FHP 2934 896 1749 DST NUMBER 14 TEST TIMES AND PRESSURE DATA Test Times: IO 5 min.; ISI 30 min. Final Flow: 5 min.; Final SI: 61 min. PRESSURE DATA (psi) START END IHP 2028 IOP 495 ISIP 826 FOP 1331 FSIP 1336 FHP 2028 826 1749 1336 1749 AI~Ska Oii& Gas Cons. commiss~on A,~choF~g~ 30. Formation Te-~-~-s (continued) DST NUMBER 15 TEST TIMES AND PRESSURE DATA Test Times' IO 3 min.; ISI 30 min.; Final Flow: 15 min.; Final SI 60 min. IHP IOP ISIP FOP FSIP FHP PRESSURE DATA (psi) START END 2028 754 824 824 1138 2028 824 1750 1138 1750 RECEIVED Alaska Oii& Gas Cons. Commission Anchorage RESERVOIRS, ItlC, COI,E ANALYSIS DATA => ~ u5 Company Amoco Production Comt'any ~ g ~-~ Well Amoco Be<:harof State #1 ,.I.oD ~ Location Section 10, T. 28S, R. ~ 9' Date Field County December Bristol , File No. RMD857/DRC102 17, 1984 Page 1 of 4 Interval 7895-7943.4 ft. Bay State A1 aska Fluid Saturations Sample Sample Porosity* Water Oi 1 Number Depth (ft.) (%) (%) (%) Perm. (md) Grain Density (gm/cc) Description 1 7895-96 1.0 69.5 0 7896-7901 no sample 2 7901-02 8.]] 63.3 1.3 . 3 7902-03 8.3 69.5 3.0 4 7903-04 5.9 71.2 1.6 5 7904-05 6.5 52.0 15.6 -0.01 .07 0.13 0.05 0.14 3.11 2.66 2.67 2.64 2.62 :.siltstone'g?ay brown, well cemented, dense, slightly dolomitic, argillaceous, minor shale laminations, trace mica, fossilized plant rootlets. siltstone-light gray, fine-coarse grain, angular, poorly sorted, moderately cemented, slightly dolomitic, slightly argillaceous, trace~ bitumen, slight intergranular porosity. siltstone-light gray, fine-very coarse grained, angular, poorly sorted, moderately cemer.(~ ~, slightly dolomitic, slightly argillaceous, t~'oce bitumen, slight intergranular porosity. siltstone-light gray, fine-very coarse grained, angular, poorly sorted, moderately cemented, slightly dolomitic, slightly argillaceous, minor shale laminations. siltstone-light-medium gray, fine-very coarse grained, angul'ar, moderately sorted, moderately cemented, slightly dolomitic, slightly argillaceous, shale and coal laminations, slight intergranular poros i ty. 6 7905-06 7.3 61.5 7.7 0.13 2.65 siltstone as aboVe. Sample Number S amp I e Depth (ft.) Poros i ty* (%) Fluid Saturations Water Oi 1 Perm. (md) Grain Den s i ty (sm/cc) Description Page 2 of 4 7906-07 7.0 73.0 3.2 0.09 2.66 7907-08 6.8 48.9 5.1 0.07 2.65 7908-09 no sample 7909-10 4.3 69.1 13.8 0.04 2.61 7910-11 6.2 59.8 21.7 0.15 2.61 7911-12 7914-15 7915-16 7.1 67.1 2.9 0.10 2.65 7912-14 no samples 7.6 63.9 7.1 62.0 1.0 5.3 0.06 0.12 2.64 2.65 7916-17 8.3 69.4 5.4 0.29 2.66 siltstone-light gray, fine-coarse grained, angular, moderately sorted, moderately cemented, slightly dolomitic, slightly argillaceous, minor shale 1 ami nat ions. t~,~' siltstone as above. siltstone-medium gray, very fine -medium grained with trace coarse grains, angular, moderately sorted, well cemented, dense, slightly argillaceous, shale laminations. siltstone-medium gray, fine to very coarse grained, angular, poorly sorted, moderately cemented, slightly argillaceous, slightly dolomitic, shale and coal laminations. siltstone-light gray, fine-coarse grained, angular? subangular, moderately sorted, moderately cementec( slightly dolomitic, slight intergranular porosity. siltstone as above. siltstone-mottled gray, fine-very coarse grained, angular-subangular, poorly sorted, moderately cemented, dolomitic, slightly argillaceous, shale laminations, slight intergranular porosity. siltstone as above. 7917-18 no sample Page 3 of 4 Sample Number Sample Depth (ft.) Poro.~ ~ty* Fluid Saturations Water Oil Perm. (md) Grain Density (gm/cc) Description 15 16 17 7918-19 6. ~ 71.7 9.0 0.03 2.62 7919-20 7920-21 3.9 65.9 O' 1.0 57.7 0 0.02 0.01 2.72 2.72 7921-22 3.8 63.8 3.5 0.06 2.64 8.6 2.7 7922-23 7925-26 0.40 0.05 67.9 0 7923-25 no sample 5.5 60.9 2.66 2.61 · siltstone-interbedded light gray, very fine-medium grained, subangular, moderate-well sorted, well cemented, dense, shale laminations, trace mica. siltstone-brown gray, well cemented, d~'ns(' dolomitic, slightly argillaceous. siltstone-light gray, very fine to fine grained, subangular, well sorted, well cemented, calcareous, dense, slight shale and coal siltstone-light-medium gray, angular, moderately-poorly cemented, slightly dolomitic, shale and coal laminations. laminations. fine-coarse grained, sorted, moderately slightly argillaceous, siltstone-mottled gray, fine-very coarse grained, angular, poorly sorted, moderately cemented, slightly dolomitic, moderate intergranular porosity. siltstone-medium gray, fine-coarse grained, angular- subangular, moderately sorted', moderately well cemented, slightly dolomitic, slightly argillaceous, shale laminations. 7927-28 7926-27 no sample .89 60.5 6.4 -0.01 3.16 7928-29 3.7 54.2 28.9 0.03 2.54 siltstone-medium brown, well cemented, very extremely dolomitic, slightly argillaceous, shale laminations. den se, mi nor siltstone-dark gray, silt-coarse grained, angular, moderately-poorly sorted, well cemented, dense, slightly argillaceous, minor shale laminations. Page 4 of 4 Samp 1 e Number S amp 1 e Depth (ft.) P or o s i ty* (%) Fluid Saturations Water Oi 1 Perm. (md) Grain Density (gm/cc) Description 23 7931-32 7929-31 no sample 6.4 73.9 24 7932-33 5.9 82.8 7933-38 no sample 25 7938-39 5.9 65.9 26 27 28 3.0 3.3 6.7 0.13 0.30 0.03 29 2.65 2.53 2.63 7939-40 5.4 84.6 3.3 0.02 2.63 7940-41 4.1 72.1 7.2 0.05 2.62 7941-42 6.6 83.8 1.6 0.02 2.65 7942-43 8.3 77.8 4.0 0.08 2.63 siltstone-light-medium gray, fine-very coarse grained, angular, poorly sorted, moderate cemented, slightly dolomitic, coal laminations. siltstone as above. siltstone-medium gray, very fine-mediu~ grained, angular-subangular, moderately sorted, moder~:tely cemented, slightly argillaceous, minor ~hale laminations. sandstone-light gray, silt-medium subangular, moderate-well sorted, well dense, slightly argillaceous. grained, cemented, siltstone-medium gray, dense, slightly argillac, ou' minor shale laminations. siltstone-light gray, fine-medium grained, subangular, moderate-well sorted, well ceme~,ted, slightly dolomitic, shale laminations, trace mi, a. siltstone-light gray, fine-coarse grained, moderately-poorly sorted, moderately slightly argillaceous, micaceous, intergranular porosity. ang lar, ceme' ted, sight F = fractured *Boyle's Law 9013 9014 Becharof State ~1 Core 04 9013-9023 Core Descriptions broken rubble - min. ass. chlorite fep qtz (calc. veins) green schist. Lbd.(?) -mafic ig or vol. rx broken rubble + 14 1/4 veins of fep(?) + qtz in chl. groundmass 9015 possible relic course grain fsp phenocrysts in schistose chl groundmass; heavily brecciated & fractured 9016 9017 9018 as above not so schistose w/relect hbd(?) phenocrysts? almost gabbro meta gabbro subhedral "hbd" - chloritized, green schist facies metamorphism more feldspathic breccia w/chl, groundmass 9019 as above 2020 f.-coarse grain meta drorite w/subhedral fsp pheno. in chl. groundmass 9021 as above 9022 rubble green schist some breccia 9023 rubble green schist Ail the core has no porosity except for fractures which are heavy at times. Entire core is probably meta-diorite to gabbro in compositoin with occasional deformed veins of fsp & qtz. RAN:das 020885 RPT880 8434 8402 8387 8356 8329 8326 8319 8295 8249.8 8289.8 8225 8210.1 8184 8138.2 8106 8086.2 8010 7975 7955 7964.9 7881.6 7868 7861 Becharof State ~1 Sidewall Core Descriptions v. poor rec. m. gr. sst. it. gy (poss. qtz diorite) good rec. bio. diorite m. c. gr. lt. gy. - partially decomposed good rec. med. dk gy silty claystone v. good rec. dk gy silty claystone poor rec. dk gy shale v. poor rec gy ~shale v. poor rec. dk gy shale ok rec. med. gy silty claystone good rec. lt. gy m.-c. gr. sst. w/v. sm. pebs. of chert, qtzose w/clay matrix poor rec.° dk gy - bk shale good rec. c.-v.c, gr. lt. gy sst. chert & qtz. w/clay matrix · good rec. m. gy siltstone w/fine laminations v. good rec. gy - br. siltstone - claystone : good rec. lt. br v. f. gr. sst. w/coal frags. v. good rec. lt.-m, gy shale good rec. gy c. sst. w/sm. peb. w/clay matrix good rec. f. gr. lt. gy sst. clay matrix good rec. dk br. woody lignite fair rec. coal fair rec. coal fair rec. coal poOr rec. coal good rec. v. f. gr. sst. dk gy 7840 7610 7474 7388 7250 7222 7092 6960 6928 6640 6546 6511 & 6420 6365 6752 6789 6866 6917 6956 7020 7206 7338 good rec. bk shaly coal good rec. dk br. shale - 7610 No rec. good rec. dk gy siltstone - 2 samples good rec. coal good rec br. claystone organic rich v. good rec lt. gy shale good rec. coal good rec. lt. gy siltstone fair rec. by claystone good rec. lt. gy siltstone - v.f. gr. sst. good rec. lt. gy v. f. gr. sst siltstone No re good rec dk gy shale - 2 samples med. gy. v.f. siltst, w/ approx. 5% visiable dk. grains (mafics?) predom, qtz & fsp. no vis. por. No C.S.F. dk br. coaly sh. - v.f. laminations - no vis. wood frags. Souce smple No C.S.F. f. gr. sst it gy to dk gy. 5.10% biot. & other mafics - qtz. & fsp 70-80~ - cherty rx frag. approx. 10X - poor vis. por. well sorted sub ang. - NO C.F.S. as above only med gr. well sorted mod. vis por No C.S.F. Micaceous siltst, it. gy well sorted 10X mica 90% qtz-fsp No C.S.F. no vis. por. dk gy micaceous siltst, no vis. por. No C.S.F. as above v.f. gr. sst it. gy ang-subang, well sorted poss. carbonaceous streaks 5~ mica = 5%-10~ dk gy grains (chert?) No C.S.F. 7346 7581 7589 7720 7870 6310 6240 6i85 6150 6112 6050 5982 5723 5710 5692 5690 550O 5460 5455 5326 5323 5225 ~5190 v.f.-f, gr. sst. lt. gy subang-ang. <10~o bio. + musco, minor hornblende(?), chert(?) dk gy - br. claystone - siltstone w/minor mica no vis. organics No C.S.F. as above v.f. gr. siltstone dk. gy to lt. br. well indurated siltstone-detrital abundant organic frags (carbonized wood) lt. br. - f.-c. gr. poorly sorted v. good rec. gy claystone v. good rec dk gy claystone v. g. rec dk gy clayst v.g. rec. A.A. v.g.rec gy siltst. fair rec. clay(?) good rec.- dk gy - br. clayst good rec. dk gy clayst good rec. dk gy clayst good rec. dk gy shale A.A. good rec. dk. gy. micaceous silt good rec. lt. gy f. gr. sst. g. rec. it gy f. gr. sst laminated w/dk gy silt g. rec dk br. clayst A.A. g. rec. coaly shales v.g. rec. dk gy sh. 5064 5058 4847 4640 4535 4570 4520 4410 4024 4020 3925 3924 3860 3800 3620 3538 3528 3510 3500 3446 3360 3340 3285 3275 4035 4055 g. rec- it. br. siltst. g. rec. it. br. siltst.-v.f, gr. sst. g. rec. it gy v.f. gr. sst. -2 samples A.A. - samples g. rec. dk gy siit- clayst No Rec. g. rec. coal g. rec. v. f. gr. sst lt. gy g. rec. f.-m. gr. sst. it gy- 2 A.A. g. rec. f. gr. sst. lt. gy salt & pepper A.A. A.A. w/organic streaks A.A. - 3 samples good rec. dk gy f. gr. sst. -2 good rec. dk gy shale A.A. - 2 good rec. c. gr. sst. w/sm. peb. m. gy. poorly sorted v. good rec. v.f. gr. lt. gy sst v. good rec. dk gy. siltst. v. good rec. dk. gy. shale v. good rec. lt. gy f. gr. sst. -2 v. good rec. it gy siltst. v. good rec. dk gy v. f. gr. sst. v. good rec. lt. gy. f. gr. sst. w/clay matrix v. good rec. dk gy f. gr. sst. 4205 42O7 44O0 6420 6511 7610 A.A.m. gr. A.A. A.A. f. gr. dk br. shale v. good rec. coal vo good rec. dk br. claystone 86 total intervals + 10 duplicates RAN:das 020885 RPT879 CORE ANALYSIS REPORT FOR AMOCO PRODUCTION COMPANY BECHAROF NO. 1 WELL UGASLIK, ALASKA RECEIVED Alaska Oil & Gas Cons, Commission Anchorage CORE LABORATORIES, INC. Petroleum Reservoir Engineering TULSA. OKI_AHOMA July 15, 1985' rEPLY TO 7304 EaST 38TH STREET TULSA OKLAHOMA 74145 Amoco Production Company 1670 Broadway, Box 800 Denver, Colorado 80201 Attn' Mr. Bob Tucker Subject' Core Analysis Data Becharof No. I Well Ugaslik, Alaska CLI File 3408-850099 Gentlemen' Unconsolidated plug samples from the subject well were delivered to the Tulsa facility by an Amoco representative for special testing. Samples were mounted in lead sleeves and confined @700 psi and 900 psi, according to depth, to properly seat the sample in the sleeve. Fluid removal was accomplished by the Dean Stark method using toluene as a solvent. Organic salts were removed by leaching with methanol Samples were then dried in a humidity oven at 140 F. and 40% humidi~y until sample weights stabilized. Pore volumes were measured at confining pressures of 400 psi, 700 psi, and 900 psi. Grain volumes were measured in a porosimeter using helium as the gaseous medium with an injection pressure of 200 psi. Porosity was determined at 400 psi and (¼ depth)psi confining pressures, using the respective pore volume measurement at that pressure and the measured grain volume. Horizontal plug permeability was measured at requested confining pressures without Klinkenberg correction. Tabular data for samples tested at 400 psi confining pressure may be found on pages one through four. Tabular data for samples testing at (¼ depth)psi confining pressure may be found on pages five through eight. Samples have been returned to Amoco Production Company core storage facility in Tulsa, Oklahoma. Thank you for this opportunity to be of service. Very truly yours, CORE LABORATORIES, INC. J. Michael Edwards District Manager JME'jk ~OCO PRODUCTION COMPANY ~CHAROF NO. I WELL £LDCAT ~ASLIK, ALASKA CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE : 7-1 2-85 FORMATION : DRLG. FLUID: LOCATION : PAGE I FILE NO. : 3408-850099 LABORATORY : TULSA, OKLAHOMA~' API WELL NO.: ELEVATION : DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @400 PSI OVERBURDEN ~MPLE DEPTH PERM MD He OIL% WTR% ' GRAIN JMBER FEET PLUG POR PORE PORE DEN M DESCRIPTION I 2725.5 2311. 33.6 0.0 97.1 2.62 SD FN-MED GRN 2 2726.5 2040. 43.2 0.0 98.8 2.53 CHLK W/SD INCL MICA 3 2727.5 3649. 35.9 0.0 98.1 2.63 SD FN-MED GRN 4 2728.9 2176. 37.1 0.0 97.2 2.62 SD FN-MED GRN 5 2729.4 2046. 36.1 0.0 99.3 2.62 SD FN-MED GRN 6 2729.5 681. 34.1 0.0 96.2 2.62 SD FN-MED GRN 7 2729.6 819. 34.6 0.0 85.6 2.63 SD FN-MED GRN 2730.4 TOO BROKEN FOR ANALYSIS 8 2730.5 1698. 36.8 0.0 95.4 2.62 SD FN-MED GRN 2730.7 TOO BROKEN FOR ANALYSIS 9 2731.5 2301. 34.9 0.0 97.1 2.61 SD FN-MED GRN 10 2732.5 1659. 34.6 0.0 97.2 2.61 SD FN-MED GRN 11 2732.6 2986. 36.9 0.0 98.5 2.62 SD FN-MED GRN 12 2733.5 2098. 36.5 0.0 99.2 2.67 SD FN-MED GRN 13 2734.5 3470. 36.9 0.0 98.7 2.62 SD FN-MED GRN 14 2735.5 3575. 38.0 0.0 98.2 2.63 SD FN-MED GRN 15 2736.5 3893. 41.7 0.0 98.8 2.62 SD FN-MED GRN 2737.5 TOO BROKEN FOR ANALYSIS 16 2737.7 362. 30.7 0.0 97.1 2.62 SD FN-MED GRN 17 2738.5 565. 30.7 0.0 98.6 2.64 SD FN-MED GRN 18 2738.6 2129. 35.3 0.0 97.1 2.63 . SD FN-MED GRN 19 2738.7 2181. 35.2 0.0 96.8 2.64 SD FN-MED GRN 20 2739.4 1989. 35.1 0.0 97.3 2.65 SD FN-MED GRN 21 2739.5 1680. 35.8 0.0 97.5 2.64 SD FN-MED GRN These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core L~boratories, inc. (ali errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or othe~ mineral well or sand in connection with which such report is used or relied upon. ~OCO PRODUCTION COMPANY DATE :.CHAROF NO. I WELL FORMAT CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS : 7-1 2-85 ION : DEAN-S PERMEAB ~MPLE DEPTH PERM MD He OIL% WT JMBER FEET PLUG POR PORE PO 22 2740.4 2623. 36.2 0.0 23 2740.5 1950. 35.9 0.0 24 2741 .5 1096. 36.1 0.0 25 2742.5 1183. 37.1 O. 0 2 6 2743.5 1 043. 37.5 O. 0 27 2744.5 1052. 38.3 0.0 28 2745.5 1386. 35.8 0.0 TARK CORE ANALYSIS ILITY MEASURE,D @400 PSI OVERBURDEN R% GRAIN RE DEN M DESCRIPTION PAGE 2 : 3408-850099 : TUL SA, 98.3 2.64 SD FN-MED GRN 98.8 2.64 SD FN-MED GRN 98.3 2.65 SD FN-MED GRN 98.6 2.65 SD FN-MED GRN 99.0 2.65 SD FN-MED GRN 97.7 2.65 SD FN-MED GRN 97.7 2.62 SD FN-MED GRN FILE NO. LABORATORY OKLAHOMA 3667.0 TOO BROKEN FOR ANALYSIS 3667.5 TOO BROKEN FOR ANALYSIS 29 3668.5 4663. 34.7 0.0 97.9 2.64 SD FN-MED GRN 30 3669.5 2978. 34.4 0.0 96.1 2.62 SD FN-MED GRN 31 3669.7 4969. 37.2 0.0 98.7 2.65 SD FN-MED GRN 3670.5 TOO BROKEN FOR ANALYSIS 32 3670.7 3378. 34.7 0.0 96.5 2.64 SD FN-MED GRN 33 3671.5 1892. 34.3 0.0 98.0 2.64 SD FN-MED GRN 3671.6 TOO BROKEN FOR ANALYSIS 34 3671.7 3843. 35.1 0.0 97.7 2.62 SD FN-MED GRN 35 3672.5 2.4 6.0 0.0 88.7 3.04 CONG LMY GRT FSPR SID 36 3673.3 3202. 35.3 0.0 97.8 2.64 SD FN-MED GRN 37 3673.5 3592. 34.8 0.0 97.0 2.53 SD FN-MED GRN LIG 38 3674.5 3.3 5.8 0.0 82.6 2.69 CONG LMY GRT FSPR LIG 39 3675.5 56. 13.3 0.0 94.2 3.32 SH DOL SL/SDY V-CRACK 40 3676.5 1.7 4.2 0.0 93.3 3.26 SH DOL FOSS V-FRAC 41 3677.3 0.03 12.2 0.0 96.2 3.06 DOL FOSS V-FRAC 3678.5 TOO BROKEN FOR ANALYSIS These ana)yses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The imerpretations or opinions expressed represent the best judgment of Core Lo. boratories, Inc. (all errors and omi~om excepted); but Cor~ Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand in connection with which such report is used or relied upon. ~OCO PRODUCTION COMPANY ECHAROF NO. I WELL ~MPLE DEPTH PERM MD He JMBER FEET PLUG POR 42 3678.7 1 550. 34.0 43 3679.5 1413. 34.0 44 3679.6 2062 . 33.5 CORE LABORATORI'ES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE : 7-1 2-85 FORMATION : DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @400 PSI OVERBURDEN OILY, WTR% GRAIN PORE PORE DEN M DESCRIPTION 0.0 97.2 2.65 SD FN-MED GRN 0.0 98.8 2.63 SD FN-M~D GRN 0.0 84.8 2.64 SD FN-MED GRN PAGE 3 FILE NO. : 3408-850099 LABORATORY : TULSA, OKLAHOMA 3680.5 TOO BROKEN FOR ANALYSIS 45 3680.6 59. 26.3 0.0 95.7 2.67 SD FN GRN V/SLTY 3681.5 TOO BROKEN FOR ANALYSIS 46 47 48 49 50 51 52 3681.8 3437. 34.4 0.0 82.0 2.65 SD FN-MED GRN 3682.4 2941. 33.6 0.0' 83.9 2.63 SD FN-MED GRN 3682.5 2829. 34.0 0.0 92.9 2.64 SD FN-MED GRN 3683.4 221. 27.2 0.0 98.9 2.66 SD FN-MED GRN 3683.5 2741. 33.5 0.0 88.8 2.64 SD FN-MED GRN 3684.5 411 5. 35.0 0.0 93.3 2.66 SD FN-MED GRN 3684.6 3994. 35.5 0.0 92.9 .2.68 SD FN-MED GRN 3685.5 TOO BROKEN FOR ANALYSIS 53 54 55 56 57 3686.5 1611. 35.8 0.0 98.7 2.65 SD FN-MED GRN 3687.5 5327. 34.9 0.0 88.5 2.66 SD FN-MED GRN 3688.5 3915. 34.5 0.0 87.7 2.66 SD FN-MED GRN 3689.5 46. 25.2 0.0 98.3 2.67 SD FN-MED GRN 3689.6 2378. 33.9 0.0 89.5 2.68 SD FN-MED GRN 3690.4 TOO BROKEN FOR ANALYSIS 3690.5 TOO BROKEN FOR ANALYSIS 58 59 3691.5 3365. 34.1 0.0 90.8 2.66 SD FN-MED GRN 3692.5 2439. 33.1 0.0 94.0 2.66 SD FN-MED GRN These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whos~ exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, inc. (all errors and omissions excepted); but Core I. abor, tories, Inc. and its officers and employees, assume no responsibitity and make no warranty or representations, as to the productivity, proper operations, or profitableness of any off, gas or oth~ mh~r~l well or nnd in connection with which such report is used or relied upon. OCO PRODUCTION COMPANY iCHAROF NO. I WELL ,MPLE DEPTH PERM MD He IMBER FEET PLUG POR 60 3694.5 620. 29.5 61 3696.5 <0.01 2.8 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE DATE : 7-1 2-85 FORMATION : DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @400 PSI OVERBURDEN OIL% WTR% GRAIN PORE PORE DEN M DESCRIPTION 0.0 96.9 2_.66 SD FN-MED GRN 0.0 75.0 3.07 DOL FOSS W/LM INCL FILE NO. LABORATORY : 3408-850099 : TULSA, OKLAHOMA These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgment of Core l~.boratories, Inc. (all errors and omission~ excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or sand t- ¢-~nnection with which such report is used or relied upon. qOCO PRODUCTION -'CHAROF [LDCAT ~ASLIK, ALASKA COMPANY ~MPLE DEPTH PERM MD He JMBER FEET PLUG POR I 2725.5 2094. 33.3 2 2726.5 1181 . 42.6 3 2727.5 3438. 35.6 4 2728.9 I 875. 36.5 5 2729.4 1752. 35.5 6 2729.5 603. 33.3 7 2729.6 772. 34.1 2730.4 TOO BROKEN FOR ANALYSIS 8 2730.5 1626. 36.2 2730.7 TOO BROKEN FOR ANALYSIS 9 2731.5 2148. 34.3 1 0 2732.5 I 513. 33.7 11 2732.6 2792. 36.1 12 2733.5 1844. 35.6 13 2734.5 3304. 36.1 1 4 273 5.5 3333. 37.0 15 2736.5 3367. 40.3 2737.5 TOO BROKEN FOR ANALYSIS I 6 2737.7 295. 30.6 I 7 2738.5 456. 30.1 18 2738.6 1982. 34.7 19 2738.7 2024. 34.8 20 2739.4 1830. 34.5 21 2739.5 1494. 35.1 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS DATE : 7-1 2-85 FORMATION : DRLG. FLUID: LOCATION : DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @700 PSI OVERBURDEN PAGE 5 FILE NO. : 3408-850099 LABORATORY : TULSA, OKLAHOMA API WELL NO.: ELEVATION : , ~ These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgmeat of Core L~boratories, Inc. (all errors and omissions exoepted); but Core I~bor,qories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mine~l well or ~nd in eormectlon with which such report is used or relied upon. MOCO PRODUCTION ECHAROF CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 6 COMPANY DATE : 7-12-85 FILE NO. : 3408-850099 FORMATION : LABORATORY : TULSA, OKLAHOMA AMPLE DEPTH PERM MD He UMBER FEET PLUG POR 22 2740.4 2492 . 35.7 23 2740.5 1874. 35.7 24 2741 .5 992 . 35.7 25 2742.5 1043. 36.6 26 2743.5 91 5. 37.2 27 2744.5 908. 37.0 28 2745.5 1187. 35.1 DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @700 PSI OVERBURDEN 3667.0 TOO BROKEN FOR ANALYSIS Them analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgmeat of Core La. boratories, Inc. (all errors and omissions excepted); but Cor~ Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas ot oth~ mln~nal well ot ~and in connection with which such report is used or relied upon. COR E LABORATOR I'ES, INC, Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 7 IOCO PRODUCTION COMPANY !CHAROF NO. I WELL '.LDCAT ;ASLIK, ALASKA DATE : FORMATION : DRLG. FLUID: LOCATION : 7-12-85 FILE NO. : 3408-850099 LABORATORY : TULSA, OKLAHOMA API WELL NO.: ELEVATION : tMPLE DEPTH PERM MD He IMBER FEET PLUG POR 29 3668.5 4379. 34.3 30 3669.5 2765. 34.1 31 3669.7 4414. 36.3 DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @900 PSI OVERBURDEN 3670.5 TOO BROKEN FOR ANALYSIS 32 3670.7 3407. 34.1 33 3671 . 5 I 742. 33.6 3671.6 TOO BROKEN FOR ANALYSIS 34 3671 .7 3529. 35.0 35 3672.5 1.1 5.7 36 3673.3 2940. 34.2 37 3 673.5 3365. 32.4 .38 3 674.5 I . 4 5.3 39 3675.5 38. 12.9 40 3676.5 0.89 4.1 41 3677.3 0.01 12.1 3678.5 TOO BROKEN FOR ANALYSIS 42 3678.7 1451. 33.6 43 3679.5 1352. 33.0 44 3679.6 1930. 33.1 3680.5 TOO BROKEN FOR ANALYSIS 45 3680.6 35. 25.9 3681.5 TOO BROKEN FOR ANALYSIS The~ analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretat ions or opinions expressed represent the best judgment of Core 12. boratories, lnc. (all errors and omissions excepted); but Core Iai>oratories, Inc. and Its officers and employees, assume no responsibility and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mlnetm! well or s~nd in ennnection with which such report is used or relied upon. ~OCO PRODUCTION COMPANY ECHAROF NO. 1 WELL AMPLE DEPTH PERM MD He ~MBER FEET PLUG POR 46 3681 .8 3219. 33.8 47 3682.4 2730. 33.1 48 3682.5 2264. 33.2 49 3683.4 186. 26.4 50 3683.5 2529. 32.9 51 3684.5 3744. 34.5 52 3684.6 3900. 34.9 3685.5 TOO BROKEN FOR ANALYSIS 53 3686.5 1350. 35.0 54 3687.5 4990. 34.3 55 3688.5 3606. 33.6 56 3689.5 26. 24.8 57 3689.6 2145 . 33.4 3690.4 TOO BROKEN FOR ANALYSIS 3690.5 TOO BROKEN FOR ANALYSIS 58 3691 .5 3169. 33.3 59 3692.5 2103. 32.5 60 3694.5 526. 28.6 61 3696.5 <0.01 2.7 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS, TEXAS PAGE 8 DATE : 7-12-85 FILE NO. : 3408-850099 FORMATION : LABORATORY : TULSA, OKLAHOMA DEAN-STARK CORE ANALYSIS PERMEABILITY MEASURED @900 PSI OVERBURDEN These analyses, opinions or interpretations are based on observations and materials supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the best judgme,~t of Core Laboratories, Inc. (all errors and omissions exoepted); but Core lsbor,,torles, Inc. and its officers and employees, assume no responsibitily and make no warranty or representations, as to the productivity, proper operations, or profitableness of any oil, gas or other mineral well or ~nd !~ connection with which such report is used or relied upon. TO DISTRICT BILLING WORKSHEET FORMATION GEOGRAPHIC Loc ATTN: WORK REQUESTED BY CLIENT PO QUANTITY DE SCRI PT ION ~~ ! UNIT PRICE /ss'% · SALES TAX TOTAL AMOUNT S~LES CREDIT ~m " Nok~a ~ou~ ,. · _ , , _ . DISTRIBUTION OF FINAL REPORT - AMOCO PRODUCTION COMPANY Becharof No. I Well Ugaslik, Alaska CLI File 3408-850099 5 cc- AMOCO PRODUCTION COMPANY Attn: Mr. Bob Tucker 1670 Broadway, Box 800 Denver, Colorado 80201 2 cc- SHELL WESTERN EXPLORATION & PRODUCTION Attn: Mr. Paul R. Smith P. O. Box 527 Houston, Texas 77001 CORE 1: 2725-2746 2728: medium-fine grained, good sorting, horizontally-bedded sandstone; "poker chips" (tabular rock fragments, broken along bedding planes, lying at an angle in,core barrel) evident in x-radiograph, not apparent in core 2728.6-28.8: medium-fine grained, good-fair sorting, subhorizontally laminated sandstone; shows up very faintly on x-radiograph 2728.9-30.0: As above, ~ith moderately-dipping cross · laminations 2730.0: truncated cross laminations (this is at 2729.0 in slabbed core) . 2730.0-30.6: medium-fine grained, good-fair sorting, cross laminated sandstone 2731.7-32.1: coarse-grained, fair-poor sorting, cross laminated sandstone with steeply-dipping laminations 2733.1: fine-grained, well sorted, cross laminated sandstone; laminations show .up very faintly on x-radiograph, not evid~_e4~.~ in core 2733.8: as above 2734.7-35.3: as above 2735.6-35.8: fine-medium grained, good-fair sorting, horizontally laminated sandstone; laminations slightly siltier 2735.9-36.4: medium-coarse grained, fair sorting, cross laminated sandstone 2737.0-37.6: fine grained matrix with rare pebbles, poor sorting, cross laminated; pebbles not evident in x-radiograph, laminations not evident in slabbed core 2738.3-38.5: fine grained, good sorting, cross laminated sandstone; laminations not evident in slabbed core 2739.0-40.0: as above, with' obvious topsets 2740.5: fine-course grained, poor sorting cross laminated sandstone; laminations not evident in slabbed core 2740.7-41.5: fine grained matrix with 2 x 3 cm pebbles, poor sorting, sandstone/pebble conglomerate; pebbles only faintly visible in x-radiograph 2744.9-45.5: fine grained, good sorting, cross laminated sandstone; laminations not evident in slabbed core · CORE 2: 3666-3697 3667.2: fine grained, good sorting, cross laminated sandstone; laminations very faint, not evident in slabbed core 3670.6: as above 3672.4: as above 3673.2: change in density (x-radiograph image darker) due to cementation/diagenesis (both calcite and unknown pale tan-pink mineral with cleavaga,..does not effervesce in HCl); medium-'gr._aihed, good sorting, subangular sna~st~ne;'-thin flase~ laminations; well indurated (remainder of core. highly friable) 3675.5: structureless mudstone breccia in medium grained, structureless sandstone matrix; part of fault zone; breccia clasts up to 10 cm long 3677.5: abrupt base of fault zone; abundant brecciated mudstone in zone, massive structureless medium grained sandstone below fault 3678.0-78.9: medium grained, sub-angular, well sorted, cross laminated sandstone; laminations not evident in slabbed core 3684.5-85.0: as above 3686.1: as abpve 3687.0-87.4: as above; cross laminations very evident in x-radiograph, not evident in slabbed core 3687.5-88.0: as above 3689.0: as above 3691.7-92.4: medium grained, sub-angular, well sorted, cross laminated sandstone; laminations not evident in slabbed core; angle of dip increases upsection 3697.0: very fine grained, sub-rounded(?), well sorted, cross laminated sandstone; laminations not evident in x-radiographs RPT844 Geochemical Interpretation of Becharof State No. 1 Prepared for Amoco Production Company RECEIVED o c}~o .7 ]L~ Alaska Oil & GaS Cons. Commission Anchora~le Geochemical Services 1565 W. MC~"~!GBIRD. SUITE 500. DALLAS. TEXAS 75235, 2141631.8270 CORE LABORATORIES, INC. May 21, 1985 Geochemical Services Mr. Randall L. Billingsley Amoco Production Company 1670 Broadway Denver, CO 80202 Subject: Geochemical Interpretation Well: Amoco Becharof State No. 1 Our Job No.: 85032 Dear Mr. Billingsley- Enclosed is our interpretation of the previously reported geochemical data for the Becharof State No. 1 well. As we did not have formation tops or other geologic information, the lithology and geochemical data provided the framework for the interpretation. The well section analyzed was evaluated for its hydrocarbon source potential based on this data. Depositionai environments were inferred from the lithology and geochemical indicators. If geologic information, such as formation tops, BHT's and assigned ages, is available for future wells we would be able to provide a reconstructed burial history plot and a Lopatin calculated thermal history with our interpretation. We appreciate this opportunity to be of assistance in Amoco's hydrocarbon exploration program. Should you have any questions on the enclosed interpretation, please contact us. Very truly yours, · ~ ~ ~ ¥~-, ~ D. Kirk Cromer Project Geochemist Geochemical Services Paul J. Swetland Manager Geological Sciences DKC,PJS-ckp Enclosure Introduction A geochemical source rock evaluation was performed on 36 canned drill cuttings samples from the interval 240 to 8860 feet in the Becharof State No. 1 at the request of Amoco Production Company. The analytical program included determination of hydrocarbon composition and carbon isotope ratio value of the headspace gas, total organic carbon (TOC), Rock-Eval pyrolysis, extractable organic matter (EOM), bitumen composition, normal paraffin and isoprenoid distribution of the C10+ saturated hydrocarbon fraction, kerogen type, elemental analysis (C, H, N) of isolated kerogen, thermal alteration index (TAI) and vitrinite reflectance (Ro). As specified by Amoco Production Company, this entire analytical program was performed on each sample where sufficient material was available. A previous report (May 10, 1985) presented the results of this analytical program. This supplemental report presents our interpretation of the hydrocarbon source potential of the Becharof State No. 1 based on the geochemical results obtained from the above analytical program. This report consists of this introduction, a summary of our interpretation and a detailed discussion of the hydrocarbon source potential of this well. Summary The Amoco Becharof State No. 1 in the interval from 240 to 8860 feet, represented by 36 samples, was geochemically evaluated for its hydrocarbon source potential. The well was divided into two zones based of lithology and geochemical data. Zone A Consists of sands and gravels in the interval from 240 to 3100 feet. These sediments have no hydrocarbon source potential. Insignificant amounts of biogenic gas' were encountered in zone A. Zone B includes the remaining well section analyzed, from 3340 to 8860 feet. This interval consists of interbedded sequences of coal, shale and sand. Two intervals were identified as having excellent potential for generating large volumes of gas, at 4540 - 5500 feet and 7180 - 8620 feet. Narrow zones within these three intervals have some potential for generating minor amounts of liquid hydrocarbons. The two intervals at 4540 and 7180 feet may contain significant gas accumulations. Zone B is thermally immature at 3340 feet and gradually increases to a marginally mature level at 8860 feet. The interval from 7180 to 8860 feet is in the early phase of oil generation. Discussion of Results The Amoco Becharof State No. 1 well, located in the Bristol Bay area of southeast Alaska, was evaluated in the interval from 240 to 8860 feet by routine geochemical techniques to determine the hydrocarbon source potential of this sedimentary section. Formation tops and other geologic information on this well were not provided, therefore, the framework of this discussion is based solely~_o~n li~hnlnrj.y~ and the geochemical data. The section penetrated can be divided into two major zones with this framework. Zone A is characterized by sands and gravels with trace amounts of organic matter (TOC < 0.25 wt. %) in the interval from 240 to 3100 feet. These sands contain small to negligible amounts of hydrocarbon gases and liquids. Carbon isotope values of the headspace gases in this interval indicate a biogenic origin of this gas from 240 to 2620 feet. Thermogenic gas has apparently migrated into the intervals at 2860 and 3100 feet, mixing with the biogenic gas already in place, based on the isotope values. The minor amounts of organic matter in Zone A were characterized as consisting of woody macerais which are indicated to be very thermally immature by all maturation indicators. This interval of the Becharof State No. 1 well has no hydrocarbon source potential. Based on the available data no reservoirs of migrated hydrocarbon gases or liquids were encountered in this interval, however, logs of mud gas concentrations were not evaluated. A depositional environment change is suggested by the lithologies of samples in Zone B, from 3340 to 8860 feet. This interval consists of coals, shales, sands and minor amounts of limestones which suggests a coastal swamp/deltaic depositional environment. Significant amounts of igneous rock fragments were identified in drill cuttings samples in the interval from 8140 to 8860 feet. Concentrations of headspace gas indicate two zones that may contain significant gas accumulations, from 4540 to 5500 feet and from 7180 to 8620 feet. The shallow zone at 4540 feet probably contains a mixture of biogenic and thermogenic gas based on the intermediate carbon isotope values (-58.7 to -31.6 °/oo)-. The gas in the deeper zone is thermogenic in origin, with isotope values from -44.3 to -19.5 °/oo. These two gas rich zones correspond to intervals containing predominantly coal with secondary amounts of shale. Zone B has very good to excellent organic richness, with the predominantly coal intervals having 20-40 wt. % TOC and the predominantly shale intervals having 3-5 wt. % TOC. This organic matter consists almost exclusively of woody macerals, with minor amounts of herbaceous and amorphous material occurring in a few intervals. Pyrolysis Hydrogen Indices generally less than 200 and H/C ratios less than 1.0 indicate these source facies have potential for generating primarily gas, as would be expected from woody organic matter. A few intervals have minor potential for liquid hydrocarbons as indicated by slightly higher Hydrogen Indices and H/C ratios and as reflected in significant pyrolysis S1 values. The high organic content of these sediments provided excellent samples for determination of thermal maturity. The three major indicators of maturity, pyrolysis Tmax, TAI and vitrinite reflectance, are in good agreement and show the top of Zone B to be thermally immature (Tmax~ 420°C, TA! - 2, R° ~ 0.30 %). There is a gradual increase in thermal maturity of these source facies with depth, attaining marginal maturity at the bottom of the analyzed section (T - 432-435°C, TAi - 2+, R ~ 0.65 %). max o The sample at 7420 feet is at a distinctly higher maturity level than samples above or below it, with values of 1.18% Ro, 464°C Trnax and 3 TAI. The higher thermal maturity level of this interval is also indicated by a lower H/C ratio, relatively higher EOM and the bitumen composition. An interval within a well section that shows an anomolously high maturity could indicate the presence of an igneous intrusive very near the interval. The potential of these intervals for generating liquid hydrocarbons was further characterized through extraction of the soluble bitumen. High EOM concentrations (>1000 ppm) correspond to the organic rich coal and shale intervals in Zone B. When compared to the very high TOC's of these intervals, these EOM levels confirm the relatively minor liquid hydrocarbon source potential of these source facies, as indicated above. The anomolously high thermal maturity of the sample at 7420 feet provides a natural laboratory for evaluating the liquid hydrocarbon potential of this source facies. At a maturity level equivalent to the late oil generation phase of the oil window, this sample contains approximately twice the EOM concentration as the immature to marginally mature samples above and below it in Zone B. This further indicates the relatively minor potential of this source facies for generating liquid hydrocarbons. The bitumen composition of the samples in Zone B confirm the thermal maturity levels indicated above. The gas chromatograms (GC's) of the C10+ saturated hydrocarbon fraction shown in Figures 30-65 of the data report also provide a good picture of the gradual increase in maturity with depth in this well. The shallow samples in Zone B have the characteristic pattern of an immature, woody-derived bitumen. With increasing depth, a gradual transition from this pattern to a pattern more typical of a marginally mature, woody-derived bitumen can be observed. Conclusions Zone A (240 - 3100 feet) has no hydrocarbon source potential and contains insignificant amounts of gas and liquids. Zone B (3340 - 8860 feet) has excellent source potential for generating gas, with the highest potential in the intervals frOm 4540 to 5500 feet and from 7180 to 8620 feet. These two intervals may contain significant gas accumulations. A few narrow zones within these intervals may have some potential for generating minor amounts of liquid hydrocarbons. The beginning of the oil window occurs slightly below 7000 feet in the Amoco Becharof No. 1, therefore significant hydrocarbon generation has probably not yet occurred in this well. Laterally equivalent facies that have either been buried deeper or that have experienced higher geOthermal gradients may have generated significant volumes of gas. Migration of these hydrocarbons should be very efficient given the interbedded sequence of sands, shales and coals encountered in this well. Geochemical Characterization of Becharof State No. 1 Prepared for Amoco Production Company Geochemical Services 1565 W. MOCKII'~, SUITE 500, DALLAS. TEXAS 75235. 2141631-8270 CORE LABORATORIES, INC. May 10, 1985 Geochemical Services Mr. Randall L. Billingsley Amoco Production Company 1670 Broadway Denver, CC) 80202 Subject: Geochemical Characterization Well' Amoco Becharof State No. 1 Our Job No.- 85032 Dear Mr. Billingsley' The following report presents the geochemical data of 36' drill cuttings samples collected from the interval 240 to 8860 feet in the Amoco Becharof State No. 1 well. The analyses requested included composition and carbon isotope content of the headspace gas, total organic carbon (TOC), Rock-Eval pyrolysis, solvent extraction, liquid and gas chromatography, kerogen evaluation, vitrinite reflectance determination and elemental analysis of the isolated kerogen. These analyses were performed on all intervals where sufficient sample quantity allowed reliable determinations. The analytical data is presented in a series of tables and figures in a sequence matching the progression of a sample through the laboratory. In some cases there are multiple gas chromatograms for the same depth interval, with one chromatogram providing all peaks on scale and a second showing detail of the hydrocarbon compounds present in Iow concentrations. An appendix to the report provides a record of the individual vitrinite reflectance readings for each section analyzed. Core Laboratories appreciates the opportunity to be of service to Amoco Production Company. We look forward to the opportunity to provide assistance with your analytical needs in the future. Should you have any questions, please do not hesitate to call. Very truly yours, ,' . Robert Blake Laboratory Supervisor Geochemical Services Paul J. Swetland Manager Geological Sciences RB,PJS/ckp Enclosure TABLE OF CONTENTS Figure A Tab le 1 Table 2 Table 3 Tab le 4 Tab le 5 Table 6 Tab le 7 Table 8 Tab le 9 Table 1 0 Figures 1-29 Figures 30-65 Appendix A Geochemical Well Profile Geochemical Summary Table Headspace Gas Analysis Carbon Isotope Composition of Headspace Gas Lithology and Total Organic Carbon Rock-Eval Pyrolysis Extractable Organic Matter Kerogen Data Summary Visual Kerogen Observations Elemental Analysis Normalized Percent Distribution C 10+ Saturated Hydrocarbon Fraction Vitrinite Reflectance Histograms Chromatograms of C10+ Saturated Hydrocarbon Fraction Tabulation of Individual Vitrinite Reflectance Readings by Sample Depth Page 9 16 18 21 24 26 28 34 63 Fi gure A GEOCHEMICAL WELL PROFILE WELL: AMOCO NO. i BECHAROF STATE LOCATION: ALASKA T.D.: - DATE: 5-2-85 F L o I HYDROCARBON POTENTIAL TYPE MATURITY R T G A O T.O.C. (wt. %) S~ (mglg) S= (mglg) S~I(S~ +$~ HYDROGENiNDEX S,ISa I~ + 0!6' I 11.2 I'? ' Shale ~ Sandstone ~ Dolomite ~ Halite ~~~~: Siltstone ~ Limestone I Coal ~ Anhydrite 1983 CORE LABORATORIES, INC. -- 1- PRINTED IN U.S.A. 8,W715C Table 1 Geochemical Data Summary File 85032 TOC Kerogen Depth Lithology (wt%) Type H Index Tmax* R EOM 240 Sa nd 0.16 Woody 480 Sand 0.03 Woody 720 Sand 0.06 Woody 960 Sand 0.07 Woody 1200 Sand 0.02 Woody 1 440 Sand 0.04 Woody 1680 Sand 0.05 Woody 21 40 Sand 0.1 0 Woody 2380 Sand 0.18 Woody 2620 Sand 0.25 Woody 2860 Sand 0.14 Woody 3100 Sand 0.11 Woody 3340 Sand/Coal 3.12 Woody 3580 Coal/Shale 25.05 Woody 3820 Coal/Shale 36.11 Woody 4060 Sand / Coal 2.49 Woody 6.3 33.3 66.7 14.3 50.0 25.0 60.0 30.0 77.8 44.0 14.3 18.2 77.6 109.1 132.6 117.3 422 420 418 425 ND ND ND ND ND ND ND + 0.21 + 0.33 ND O.3O 0.29 0.31 0.29 5 20 23 18 17 20 20 57 52 35 4 307 4047 4838 528 S2 peak too small to allow reliable Tmax determination. No Determination. Insufficient material for accurate determination. -2- Table 1 (cont.) Geochemical Data Summary Fi le 85032 Depth Lithology TOC Kerogen (wt%) Type H Index Tmax* R EOM 4300 4540 4780 5020 5260 5500 5740 5980 6220 6460 6700 6940 7180 7420 7660 790O Sand Coal/Shale Coal/Shale Coal/C lay stone Coal Shale Shale Sand/Shale Shale Sand/Shale Sand/Shale Sand Coal/Shale Coal/Shale Shale/Coal Coal/Shale 0.90 Woody 41.29 Woody 22.16 Woody 24.50 Woody 42.99 Woody 2.48 Woody 3.29 Woody 4.51 Woody 2.50 Woody 4.77 Woody 3.75 Woody 0.45 Woody 21.84 Woody 33.55 Woody 3.50 Woody 29.17 Woody 67.8 197.7 151.0 164.0 210.9 179.8 126.1 170.7 113.2 116.4 143.2 44.4 253.8 129.5 359.1 221.2 428 418 422 423 420 425 429 423 '427 423 424 439 427 464 431 435 0.24 0.31 0.32 0.29 0.33 0.40 0.44 0.45 0.37 0.32 0.48 0.36 0.56 1.18 0.61 O.69 152 7136 4163 5226 5981 218 353 390 356 651 614 75 2305 12688 1207 7387 -3- Table 1 (cont.) Geochemical Data Summary File 85032 Depth Lithology TOC Kerogen (wt%) Type H Index Tmax* R EOM 8140 8380 8620 8860 Coal/Shale 11.07 Woody 1 25.6 Coal/Shale 5.63 Woody 88.8 Igneous/Coal 2.86 Woody 156.3 Igneous/Coal 0.62 Woody 1 30.6 433 442 432 432 0.66 0.65 0.60 0.80 1674 912 5O3 98 -4- Sample Number 240' 480' 720' 960' 1200' 1 440' 1680' 21 40' 2380' 2620' 2860' 3100' 3340' 3580' 3820' 4060' 4300' 4540' Methane Table 2 Headspace Gas Analysis Becharof State #1 (All values are expressed in parts per million by volume of sediment) Fi le 85032 Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes 16.0 1.6 0.9 0.1 0.2 0.1 0.1 0.0 0.0 9.7 0.7 0.3 0.1 0.1 0.0 0.0 0.0 0.0 19.7 0.8 0.5 0.0 0.1 0.0 0.0 0.0 0.0 478.2 4.2 1.4 0.2 0.4 0.1 0.0 0.0 0.0 164.3 2.1 0.5 0.1 0.1 0.0 0.0 0.0 0.0 68.8 1.8 1.1 0.2 0.2 0.0 0.0 0.0 0.0 119.2 1.8 0.9 0.1 0.2 0.1 0.1 0.0 0.0 198.5 2.3 1.1 0.2 0.4 0.2 0.2 0.0 0.0 473.5 7.8 3.0 0.3 0.4 0.2 0.1 0.0 0.0 8173.2 67.2 12.7 0.5 1.8 0.1 0.1 0.0 0.0 10146.7 69.1 11.2 0.4 0.7 0.1 0.0 0.0 0.0 1285.1 20.7 6.1 1.5 2.4 0.7 0.3 0.0 0.0 2462.3 31.8 3.9 0.6 0.8 0.3 0.4 0.0 0.0 19709.2 2019.2 273.9 109.8 85.2 29.1 23.6 0.0 0.0 1818.6 57.7 7.2 0.6 1.0 0.1 0.1 0.0 0.0 2279.5 65.1 11.5 3.1 2.7 1.1 0.5 1.0 0.0 1469.7 36.0 3.7 0.6 0.7 0.5 0.5 1.6 0.0 437723.5 7771.6 2013.4 413.7 256.3 53.6 75.0 238.3 0.0 -5- Table 2 (cont.) Headspace Gas Analysis Becharof State #1 (All values are expressed in parts per million by volume of sediment) File 85032 Sample Number 4780' 5020' 5260' 5500' 5740' 5980' 6220' 6460' 6700' 6940' 7180' 7420' 7660' 7900' 8140' 8380' 8620' 8860' Methane Ethane Propane i-Butane n-Butane i-Pentane n-Pentane Hexanes Heptanes 105697.7 261810.8 532507.0 66724.9 28561.3 28112.9 4789.O 26223.1 33941.7 10755.1 393139.1 410794.5 136717.3 95709.3 143036.0 151096.0 96323.6 21810.2 2472.0 790.1 120.5 65.2 29.5 19.7 2849.4 1218.2 223.3 163.6 31.1 38.3 11021.1 2664.8 440.0 344.6 116.1 132.9 1150.~4 398.4 75.8 63.3 31.2 17.2 1361.0 468.9 84.1 60.2 28.6 13.0 722.9 425.3 92.8 50.1 26.8 14.2 64.8 21.6 1.3 2.3 0.9 0.5 241 3.1 733.3 98.6 53.7 28.1 13.5 2984.4 1243.7 279.5 176.2 76.4 42.2 1101.2 587.5 139.7 88.6 39.2 22.4 14228.5 2596.5 501.6 259.5 92.8 54.4 19553.0 5026.7 759.1 554.5 173.1 307.4 7917.6 221 9.6 335.3 221.9 83.9 58.1 9263.8 2441.0 318.6 185.1 281.5 220.0 13408.8 3493.3 428.3 308.8 1027.4 337.1 5735.2 1884.6 181.8 106.9 85.4 72.8 5278.4 1387.3 274.9 145.7 68.0 46.5 1937.1 800.1 164.7 89.4 44.0 22.4 24.1 82.0 36.9 23.4 20.0 25.1 1.6 18.9 42.7 24.9 46.6 329.3 137.0 77.3 91.1 160.9 105.2 30...5 0.0 19.1 79.7 31.2 26.7 40.2 0.0 24.0 58.9 13.5 0.0 219.6 104,6 20,6 111.7 69.0 99.6 37.8 -6- Depth 240' 480' 720' 960' 1200' 1 440' 1680' 2140' 2380' 2620' 2860' 3100' 3340' 3580' 3820' 4060' 4300' 4540' 4780' 5020' 5260' 5500' 5740' 5980' 6220' 6460' 6700' 6940' 7180' Table 3 CARBON ISOTOPE RATIOS BECHAROF STATE #1 ~13C (PDB) NS NS NS -80.2 -7O. 3 NS -70.0 -71.6 -67.9 -58.5 -32.0 -44.4 -51.0 -65.4 -45.5 -49.0 -48.0 -58.5 -53.7 -49.3 -31.6 -58.7 -44.3 -28.8 -19.5 -36.1 -33.6 -34.5 -35.0 Fi le 85032 Depth 7420~ 7660~ 7900~ 8140~ 8380~ 8620~ 8860~ Table 3 (cont.) CARBON ISOTOPE RATIOS BECHAROF STATE #1 613C (PDB) -34.6 -35.3 -43.7 -32°8 -41.1 -43.9 -36.1 File 85032 -8- Table 4 Lithology and Total Organic Carbon (TOC) File 85032 Depth {ft) Sample Type Lithology TOC (wt%) 24O 480 720 960 1200 ctgs ctgs ctgs ctgs ctgs SAND AND GRAVEL-wh, It gry, rd, brn, yel, blk, gn, m-crs gr, abd pbl, uncons, sbrndd to rndd constituents; SANDSTONE-wh, It gry, m-f gr, mod hd, cly-sil mtrx, qtz, fspr, mica; FELDSPARS; IGNEOUS MATERIAL- reworked SAND AND GRAVEL-wh, clr, It gry, gn, rd, blk, yel, m-crs gr, occ pbl, uncons, rndd to sbrndd, qtz, abd fspr, mica, ig mat, pyr, mag, coal; Tr-SHALE SAND-wh, clr, It gry, gn, pk, blk, rd, m-crs gr, uncons, ang to sbrndd, abd qtz, fspr, mica, pyr, ig mat, pyr, vit Istr; Tr-COAL, MAGNETITE SAND-wh, clr, blk, It gry, gn, rd, m-crs gr, uncons, ang to sbrndd, abd qtz, fspr, coal, ig mat, pyr, vit Istr; Tr-MAGNETITE SAND-wh, clr, bik, It gry, gn, rd, m-crs gr, uncons, ang to sbrndd, abd qtz, fspr, coal, ig mat, pyr, vit Istr; sme SHELL FRAGMENTS-It bm, tan, calctc; Tr-MAGNETITE 0.17/0.15 0.03 0.06/0.06 0.07 0.02 Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC (wt%) 1440 1680 2140 2380 2620 2860 ctgs ctgs ctgs ctgs ctgs ctgs SAND-wh, clr, blk, brn, gn, m to crs gr, ang to sbrndd, uncons, abd fspr, qtz, ig mat, pyr, vit Istr; sme COAL; MAGNETITE SAND-wh, clr, blk, brn, gn, m to crs gr, ang to sbrndd, uncons, abd fspr, qtz, ig mat, pyr, vit Istr; COAL; sme MAGNETITE SAND-wh, gn, blk, gry, clr, crs g r, ang to sbang, uncons, abd fsprs, qtz, ig rock frags, pyr, vit Istr, coal; Tr-MAGNETITE SAND-wh, cir, gry, blk,.gn, f-m gr, uncons, ang to sbang, qtz, abd fspr, ig mat and rock frags, pyr, coal, tr mag; SANDSTONE-It gry, tan-gry, mod sft, m-f gr, cly-sil mtrx, qtz, fspr, mica, Ise consol SAND-wh, clr, gry, blk, gn, f-m gr, uncons, ang to sbang, qtz, abd fspr, ig mat and rock frags, pyr, coal, tr mag; sme SANDSTONE SAND-wh, It gry, blk, gn, m to crs gr, uncons, ang to sbang, qtz, fspr, coal, pyr, sme ig mat & rock frag; Tr-MAGNETITE 0.04 0.05 0.10 0.18 0.25 0.13/0.14 -10- Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC (wt%) 3100 3340 3580 3820 4O6O ctgs ctgs ctg s ctgs ctgs SAND-wh, It gry, blk, gn, m to crs gr, uncons, ang to sbang, qtz, fspr, coal, pyr, sme ig mat & rock frag; Tr-MAGNETITE SAND-wh, It gry, blk, gn, m to crs gr, uncons, ang to sbang, qtz, fspr, coal, pyr, sme ig mat & rock frag; SHALE-blk, dk brn, mod sft, flk, sli calctc, foss, carb; COAL; Fluor - wh/slight cut COAL; sme SHALE-blk, dk brn, mod sft, flk, sli calctc, foss, carb, intbd coal; sme SAND-wh, It gry, blk, gn, m to crs gr, uncons, ang to sbang, qtz, fspr, coal, pyr, sme ig mat & rock frag; Fluor - yel-gn/ Streaming Yel - Faint COAL; sme SHALE-blk, dk brn, mod sft, flk, sli calctc, foss, carb, intbd coal; sme SAND-wh, It gry, blk, gn, m to crs gr, uncons, ang to sbang, qtz, fspr, coal, pyr, sme ig mat & rock frag; Fluor - yel-gn/ Streaming Yel- Faint SAND-clr, wh, It gn, blk, tan, f-m gr, ang to sbang, qtz, fspr, pyr; COAL; Tr-SHALE 0.11 3.12 25.05 36.11 2.49 Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC (wt%) 4300 4540 4780 5020 526O 5500 5740 ctgs ctgs ctgs ctgs ctgs ctgs ctgs SAND-clr, wh, It gn, blk, tan, f-m gr, ang to sbang, qtz, fspr, pyr COAL-sub-bit; sme SHALE-blk, dk brn, mod sft, fik, sli calctc, foss, carb, intbd coal COAL-sub-bit; sme SHALE-blk, dk brn, mod sft, flk, sli calctc, foss, carb, intbd coal; Tr-SAND COAL-sub-bit; CLAYSTONE-It brn, gry, v sft, pwdy, occ coal incl; Tr-SAND COAL-sub-bit; Tr-SHALE SHALE-It brn, It gry, tan, mod sft, sdy, sli calctc, sli carb; SANDSTONE-wh, It gry, brn, mod sft, Ise consol, m-f gr, cly-calctc mtrx, qtz, fspr, dk cly, mica; sme PYRITE; COAL-sub-bit, occ intbd w/ shale; Tr-LIMESTONE SHALE-It bm, It gry, tan, mod sft, sdy, sli calctc, sli carb; LIMESTONE-It brn, tan, sdy to suc tex; sme COAL-sub-bit; Tr-SANDSTONE, CLAYSTONE 0.90 41.29 22.16 24.50 42.99/42.26 2.48 3.29 Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC (wt%) 5980 6220 646O 6700 6940 ctgs ctgs ctgs ctgs ctgs SHALE-It brn, It gry, tan, mod sft, sdy, sli calctc, sli carb; CLAYSTONE-It bm, gry., v sft, pwdy, occ coal incl; SANDSTONE-wh, It gry, brn, mod sft, Ise consol, m-f gr, cly-calctc mtrx, qtz, fspr, dk cly, mica; sme LIMESTONE-it brn, tan, sdy to suc tex; PYRITE; COAL-sub-bit SANDSTONE-wh, It gry, brn, mod sft, Ise consol, m-f gr, cly-calctc mtrx, qtz, fspr, dk cly, mica; SHALE-It brn, It gry, tan, mod sft, sdy, sli caictc, sli carb; PYRITE; COAL-sub-bit; LIMESTONE-It brn, tan, sdy to suc tex SHALE-It gry, brn, tan, mod sft, slty, sli caictc, sli carb; sme COAL-sub-bit; Tr-LIMESTONE SANDSTONE-wh, It gry, brn, mod sft, Ise consol, m-f gr, cly-calctc mtrx, qtz, fspr, dk cly, mica; SHALE-It gry, brn, tan, mod sft, slty, sli calctc, sli carb; CLAYSTONE-It brn, gry, v sft, pwdy, occ coal incl; COAL-sub-bit; LIMESTONE-It brn, tan, sdy to suc tex; PYRITE SAND-wh, It gry, m-crs gr, uncons, ang to sbang, qtz, fspr, pyr; COAL-sub-bit 4.51 2.50 4.77 3.75 0.45 -13- Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC '(wt%) 7180 7420 7660 7900 8140 ctgs ctgs ctgs ctgs ctgs COAL-sub-bit; sme SHALE-bik, dk brn, sft, v carb; SANDSTONE-wh, It gry, brn, mod sft, ise consol, m-f gr, cly-calctc mtrx, qtz, fspr, dk cly, mica; sme LIMESTONE-It brn, tan, sdy to suc tex COAL-sub-bit; SHALE-blk, dk brn, mod sft, flk, v carb; Tr-SANDSTONE SHALE-m-dk brn, mod sft, fik, slty, sli carb; COAL-sub-bit; Tr-SANDSTONE, CLAYSTONE COAL-sub-bit; SHALE-m-dk brn, mod sft, flk, slty, sli carb; sme IGNEOUS ROCK MATERIAL; Tr-LIMESTONE, CLAYSTONE, SANDSTONE; Fluor - dull gn/Cut-Flash Streaming Yel COAL-sub-bit; IGNEOUS ROCK FRAGMENTS AND MATERIAL-gn, wh, It gry, crs gr, ea to pwdy tex; SHALE-m-dk brn, mod sft, flk, slty, sli carb; sme LIMESTONE-It brn, tan, sdy to suc tex; Tr-SANDSTONE; Fluor - yei-gn/ Cut-Slow Streaming 21.84 33.55 3.50 29.17 11.07 -14- Table 4 (cont.) Lithology and Total Organic Carbon (TOC) File 85032 Depth (ft) Sample Type Lithology TOC (wt%) 8380 8620 8860 ctg s ctgs ctgs COAL-sub-bit; IGNEOUS FRAGMENTS AND MATERIAL-gn, wh, it gry, crs gr, ea tex; SHALE-lt-m brn, blk, mod sft, flk, v carb; PYRITE; LIMESTONE-tan, it brn, sm to suc tex; Tr-SANDSTONE IGNEOUS FRAGMENTS AND MATERIAL-gn, wh, It gry, crs gr, ea to pwdy tex; COAL-sub-bit; SHALE-lt-m brn, blk, mod sft, flk, v carb; PYRITE; Tr-LIMESTONE, SANDSTONE IGNEOUS FRAGMENTS AND MATERIAL-gn, wh, It gry, crs gr, ea to pwdy tex; COAL-sub-bit; SHALE-It-m brn, blk, mod sft, flk, v carb; PYRITE; Tr-LIMESTONE, SANDSTONE 5.63 2.86 0.62 -15- FILE NO. 85032 Depth Mg/Gm (Fl) 10C Sl S2 240 0.16 0.01 0.01 480 0.03 0.01 0.01 720 0.06 0.02 0.04 960 0.07 0.01 0.01 1200 0.02 0.03 0.01 1440 0.04 0.03 0.01 1680 0.05 0.03 0.03 2140 0.10 0.03 0.03 2380 0.18 0.05 0.14 2620 0.25 0.04 0.11 2860 0.14 0.02 0.02 3100 0.11 0.02 0.02 3340 3.12 0.07 2.42 3580 25.05 0.43 27.32 3820 36.11 0.85 47.89 4060 2.49 0.06 2.92 4300 0.90 0.05 0.61 4540 41.29 1.41 81.61 4780 22.16 0.53 33.46 5020 24.50 0.78 40.18 TOC = Total Organic Carbon Hydrogen Index = (S2/TOC)xlO0 Rock Table 5 ROCK-EVAL PYROLYSIS Hydrogen Oxygen S3 Index Index 0.09 6.3 56.3 0.03 33.3 100.0 0.10 66.7 166.7 0.17 14.3 242.9 0.13 50.0 650.0 0.01 25.0 25.0 0.05 60.0 100.0 0.30 30.0 300.0 0.19 77.8 105.6 0.78 44.0 312.0 0.08 14.3 57.1 0.22 18.2 200.0 3.21 77.6 102.9 9.52 109.1 38.0 2.78 132.6 35.4 1.22 117.3 49.0 0.62 67.8 68.9 3.23 197.7 32.0 6.12 151.0 27.6 5.94 164.0 24.2 Oxygen Index = (S3/TOC) x 100 Oil or Gas Shows = S1 Oi Shows or Gas Trans Potential Ratio 0.01 0.02'- 0.50 0.01 0.02 0.50 0.02 0.06 0.33 0.01 0.02 0.50 0.03 0.04 0.75 0.03 0.04 0.75 0,03 0.06 0.50 0.03 0.06 0.50 0.05 0.19 0.26 0.04 0.15 0.27 0.02 0.04 0.50 0.02 0.04 0.50 0.07 2.49 0.03 0.43 27.75 0.02 0.85 48.'74 0.02 0.06 2.98 0.02 0.05 0.66 0.08 1.41 83.02 0.02 0.53 33.99 0.02 0.78 40.96 0.02 Oil or Gas Potential = Transformation Ratio = TMAX (Deg C) 422 420 418 425 428 418 422 423 S1+S2 Sl/(S1+S2) Note: Tmax values for interval 240 to 3100 low S2 values and are not reported, feet considered -16- unreliable due to extremely Depth Mg/Gm Rock (Fl) TOC Si S2 S3 5260 42.99 1.11 90.66 7.66 5500 2.48 0.17 4.46 1.53 5740 3.29 0.05 4.15 1.24 5980 4.51 0.14 7.70 1.82 6220 2.50 0.05 2.83 0.62 6460 4.77 0.08 5.55 1.47 6700 3.75 0.10 5.37 1.02 6940 0.45 0.03 0.20 0.21 7180 21.84 1.14 55.42 2.38 7420 33.55 8.68 43.45 2.72 7660 3.50 0.35 12.57 0.51 7900 29.17 3.79 64.51 3.66 8140 11.07 0.95 13.90 0.75 8380 5.63 0.43 5.00 0.34 8620 2.86 0.26 4.47 0.22 8860 0.62 0.04 0.81 0.03 Table 5 (cont.) ROCK-EVAL PYROLYSIS Hydrogen Oxygen Oi 1 Index Index Shows 210.9 17.8 1.11 179.8 61.7 0.17 126.1 37.7 0.05 170.7 40.4 0.14 113.2 24.8 0.05 116.4 30.8 0.08 143.2 27.2 0.10 44.4 46.7 0.03 253.8 10.9 1.14 129.5 8.1 8.68 359.1 14.6 0.35 221.2 12.'5 3.79 125.6 6.8 0.95 88.8 6.0 0.43 156.3 7.7 0.26 130.6 4.8 0.04 or FILE NO. 85032 Gas Trans TMAX Potential Ratio (Deg C) 91.77 0.01 420 4.63 0.04 425 4.20 0.01 429 7.84 0.02 423 2.88 0.02 427 5.63 0.01 423 5.47 0.02 424 0.23 0.13 439 56.56 0.02 427 52.13 0.17 464* 12.92 0.03 431 68.30 0.06 435 14.85 0.06 433 5.43 0.'08 442 4.73 0.05 432 0.85 0.05 432 * Anomolous Tmax. Verified by repeat analysis. TOC = Total Organic Carbon Oxygen Hydrogen Index = (S2/TOC)xlO0 Oil or Index = (S3/TOC) Gas Shows = S1 x 100 Oil or Gas Potential Transformation R,ati o : S1+S2 = S1/(S1+S2) Results of C15 Table 6 Extractable Organic Matter (EOM) Analysis File 85032 Depth TOC EOM HC (ft) (wt%) (ppm) (ppm) Composition of C15+ Extractable Organic Matter (Normalized Percent) 'Sat Aro NSO Asph Percent I~OM/TOC HC/TOC HC/EOM Sat/Aro 240 0.16 5 insufficient material 0.3 480 0.03 20 insufficient material 6.7 720 0.06 23 insufficient material 3.8 960 0.07 18 insufficient material 2.6 1200 0.02 17 insufficient material 8.5 1440 0.04 20 insufficient material 5.0 1680 0.05 20 insufficient material 4.0 2140 0.10 34 insufficient material 3.4 2380 0.18 57 insufficient material 3.2 2620 0.25 52 insufficient material 2.1 2860 0.14 35 insufficient material 2.5 3100 0.11 4 insufficient material 0.4 3340 3.12 307 112 15.2 21.2 61.6 2.0 1.0 3580 25.05 4047 1643 13.6 27.0 56.4 3.0 1.6 3820 36.11 4838 1761 8.4 28.0 58.0 5.6 1.3 0.4 36.4 0.72 O.7 40.6 O.5O 0.5 36.4 0.30 TOC = Total Organic Carbon; EOM = Extractable Organic Matter (C15+); HC - C15+ Hydrocarbons (saturates + aromatics); Sat = Saturates; Aro = Aromatics; NSO - Resins; Asph = Asphaltenes -18- Results of C15 Table 6 (cont.) Extractable Organic Matter (EOM) Analysis File 85032 Composition of C15+ Extractable Organic Matter Depth TOC EOM HC (Normalized Percent) (ft) (wt%) (ppm) (ppm) Sat Aro NSO Asph EOM/TOC Percent HC/TOC HC~EOM Sat/Aro 4060 2.49 528 180 8.2 25.8 52.7 3.3 2.1 4300 0.90 152 insufficient material 1.7 4540 41.29 7136 2911 11.8 29.0 54.8 4.4 1.7 4780 22.16 4163 1503 9.6 26.5 56.5 7.4 1.9 50'20 24.50 5226 1678 7.5 24.6 59.4 8.5 2.1 5260 42.99 5981 2195 9.3 27.4 53.5 9.8 1.4 5500 2.48 218 118 20.4 33.7 43.9 2.0 0.9 5740 3.29 353 196 19.2 36.3 42.4 2.1 1.1 5980 4.51 390 183 14.5 32.4 47.7 5.4 0.9 6220 2.50 356 219 17.9 43.7 35.2 3.2 1.4 6460 4.77 651 336 15.2 36.4 45.4 3.0 1.4 6700 3.75 614 354 16.1 41.6 39.2 3.1 1.6 6940 0.45 75 insufficient materi'al 1.7 7180 21.84 2305 1459 20.5 42.8 31.9 4.8 1.1 7420 33.55 12688 8374 29.0 37.0 30.6 3.4 3.8 0.7 34.0 0.32 0.7 40.8 0.41 0.7 36.1 0.36 O.7 32.1 O.30 O.5 36.7 0.34 0.5 54.1 0.61 0.6 55.5 0.53 0.4 46.9 0.45 O.9 61.6 0.41 0.7 51.6 0.42 0.9 57.7 0.39 0.7 63.3 0.48 2.5 66.0 0.78 TOC = Total Organic Carbon; EOM = Extractable Organic Matter (C15+); HC - C15+ aromatics); Sat = Saturates; Aro = Aromatics; NSO = Resins; Asph = Asphaltenes Hydrocarbons (saturates + -19- Results of C 15 Table 6 (cont.) Extractable Organic Matter (EOM) Analysis File 85032 Composition of C15+ Extractable Organic Matter Depth TOC EOM HC (Normalized Percent) (ft) (wt%) (ppm) (ppm) 'Sat Aro NSO Asph EOM/TOC Percent HC/TOC HC/E'OM Sat/Aro 7660 3.50 1207 814 18.1 49.3 29.0 3.6 3.4 7900 29.17 7387 4329 18.3 40.3 34.6 6.8 2.5 8140 11.07 1674 1158 21.9 47.3 22.1 8.7 1.5 8380 5.63 912 544 21.8 37.8 27.6 12.8 1.6 8620 2.86 503 376 23.1 41.7 26.9 8.3 1.8 8860 0.62 98 insufficient material 1.6 2.3 67.4 0.37 1.4 58.6 0.45 1.1 69.2 0.46 1.0 59.6 0.58 1.3 74.8 0.45 TOC = Total Organic Carbon; EOM = Extractable Organic Matter (C15+); HC - C15+ aromatics); Sat = Saturates; Aro = Aromatics; NSO - Resins; Asph = Asphaltenes Hydrocarbons (saturates+ -20- Table 7 Kerogen Data Summary File 85032 Thermal Depth Alteration (ft) %Amorphous %Herbaceous %Woody %Coaly Hydrogen/Carbon Index Vitrinite Reflectance 240 100 ND 2? 480 100 ND 2? 720 100 ND 2? 960 100 ND 2? 1200 T T 100 ND 2 1440 T . 100 ND 2+ 1680 T 100 ND 2 2140 T 100 1.14 2 2380 T 100 1.09 2 2620 T 100 1.11 2 2860 T 100 0.95 2 3100 10 10 80 1.12 2 3340 10 T 90 1.09 2 3580 T 5 95 1.04 2 3820 T 5 95 0.99 2 4060 5 25 70 0.99 '2 ND ND ND ND ND ND ND 0.22* 0.21 0.20* 0.33 ND 0.30 0.29 0.31 0.29 Amorphous - algal, debris + amorphous sapropels; Herbaceous = waxy and resinous materials generally having a characteristic form; i.e., plant cuticle, pollen, spores, resins, etc. *Insufficient vitrinite for an accurate R determination. ND = No Data o Table 7 (cont.) Kerogen Data Summary File 85032 Thermal Depth Alteration (ft) %Amorphous %Herbaceous %Woody %Coaly Hydrogen/Carbon Index Vitrinite Reflectance q300 25 5 70 1.01 2 4540 5 95 0.97 2 4780 T 10 90 1.05 2 5020 10 T 90 0.97 2 5260 T T 100 0.96 2 5500 5 T 95 1.01 2 5740 20 20 60 1.11 2 5980 15 T 85 1.03 2 6220 5 10 85 0.95 2 6460 5 10 85 0.95 2 6700 5 10 85 0.93 2 6940 T 5 95 0.97 2 7180 T 5 95 0.99 2+ .,. 7420 5 T 95 0.80 3 7660 5 25 70 1.00 2+ 0.24 0.31 0.32 .0.29 0.33 0.40 0.44 0.45 0.37 0.32 0.48 0.36 0.56 1.18 0.61 Amorphous -- algal debris + amorphous sapropels; Herbaceous = waxy and resinous materials generally' having a characteristic form; i.e., plant cuticle, pollen, spores, resins, etc. *Insufficient vitrinite'for an accurate R determination. o Table 7 (cont.) Kerogen Data Summary File 85032 Thermal Depth Alteration (ft) %Amorphous %Herbaceous %Woody %Coaly Hydrogen/Carbon Index Vitrinite Reflectance 7900 5 5 90 0.87 2+ 8140 T 10 90 0.89 2+ 8380 T 10 90 0.86 2+ 8620 5 T 95 0.85 2+ 8860 T T 100 0.80 2+ 0.69 0.66 0.65 0.60 0.80 Amorphous = algal debris + amorphous sapropels; Herbaceous = waxy and resinous materials generally having a characteristic form; i.e., plant cuticle, pollen, spores, resins, etc. *Insufficient vitrinite for an accurate R determination. O ...... VISUAL KEROGEN OBSERVATIONS Table 8 THERMAL SPORINITE x. >50% ALTER ATION COLOR KEROGEN FLUORESCENCE PRES / = ZO-5O% I N O E X TYPE COLOR . : 5-20 % WELL Becharof ~ ~ ~ ~ ~ - , ~ ~ N ~ ~ - o ,. AMOCO Fe~ ~ . DEPTH REMARKS I 2 3 4 5 6 7 8 g ~0 ~t ~2 ~3 ~4 15 ~6 17 18 ~ 20 2t 22 23 ~4 25 2e 27 28 ~ 30 3t 5~ 33 ~4 Ss 3s 3~ 50 5~ 40 41 42 43 44 2 4 0 ? ? X X No sporinite fluorescence. 4 8 0 ? ? X X No sporinite fluorescence. 7~2 0 ? ? X X No sporinite fluorescence. 9]6 0 ? ? X X No sporinite fluorescence. i 2 0 0 x x ~ T T X X No sporinite fluorescence. I 4 4 0 X / X 1 X X No sporinite fluorescence. ~ 6~8.0 X X / 1 X X No sporinite fluorescence. 2 I 4 0 X X / T X X' No sporinite fluorescence. 2380 X 'X TX T X 2620 X X/ IX T X I ~ ~ 4 ~ S 7 ~ 9 ~0 ~ t2 ~ ~4 tB ~ ~7 la ~! ~0 ~ 2~ ~ 24 25 2~ 2~ 2~ 2~ ~0 SI ~2 ~ 54 ~ ~ ~ ~ ~940 4~ 42 4~ 44 2~6~0 X X/ TX 1 X 3 I 0 0 X X * * ~ 1 X ~axodium sp.. bisaccates. 3 3 4 0 X X * T X 1 X Porates, bisaccates, amor- phous kerogen may actuall be degradea woody material. '3 5 8 0 X X / T * X T X Bisaccates 3 8 2 O X~ X ~ * X T T X Bisaccates, fungal hyphae. ~ 2 5 4 5 6 7 ~ 9 tO ~ ~2 ~ 14 ~5 t6 ~7 ta ~9 ~0 ti lI 2~ ~4 25 26 27 2a 19 50 ~ ~2 S~ ~4 ~ ~6 ~7 ~ ~l 40 4t 4~ 4~ 44 4 0 6 ~ XI X *l * /~X T X Numero~s Al nus. 4 3 0 0 X X / T / * X T X Bisaccates, Taxodium sp. 4 b4U X X~/ *X T X I -24- VISUAL KEROGEN OBSERVATIONS Table 8 (cont.) xz >50% THE R M AL SPORINITE /: zO -50% ALTERATION COLOR KEROGEN FLUORESCENCE PRES WELL Becharof INDEX TYPE COLOR T= 0-5% JOB NO. 85032 ~ ~ ~ ~ ~ - ~ , g o - ~ o ~ AMOCO DE PT H R EM ARKS 4 7 R ~ X~ X / T * X~ TI X D~g~ad~d woad. A~nus sp. 5 0 2 0 X X / * T X T T X Ab~ndan[ deq~ded wood, amorphous:d~rad~d wood 5 2 6 0 X X / T T X T X Some deq~aded wood. 5 5 ~ 0 X X / * T X T X R~latiwlv small keroaen nmrtirlpq whpn cnmn~rmd tn bDh61e m~t6~l. ' 5 7 4[0 X X * / /~X * X. Abundant bisaccates. ~ 2 ~ 4 B ~ ~ ~ ~ ~0 ~ ~ ~ ~4 ~ ~ ~ ~ ~ 20 ~ 22 2~ 24 25 2S 2T 2~ 29 ~0 ~1 ~2 ~ ~4 55 ~S ~ ~a ~9 40 4~ 4~ 4~ 44 5 9 8 0 X X / * TjX T T X Relativelv small kero~en ~articl~ when compared to bDhole material. ' 6 2 .20 X X * * * X * X~ Nbmerous bisaccates. 6 4 6 0 X X * * * X * X Abundant bisaccates. Alnus 6 7 0 0 X X * * * X * X Abundant bisaccates, Alnus 6 ~q~ [n X X / T * X * X ..... I 2 ~ 4 5 6 7 ~ ~ ~0 ~ ~2 ~ 44 ~ ~ IT ~ ~ 20 ~ 22 2~ 24 25 2e ~ 2a 2~ ~0 SI 52 ~ S4 55 SS ST ~l ~ 40 4~ 4~ 4~ 44 7 I 8 O X * X / T * X * X S'ome.bisaccates. 7 4 2 0 X / X * T X T X Sliqht darker color from sample above. 7 6 6 0 X X * * / X T * X Abundant bisaccates, Al nus Tsugopol lenites, sp. 79~]0 X X/ **X T X , ~ 2 5 4 5 6 7 a 9 ~0 ~1~ ~ I~ ~4 ~5 ~s ~7 ~a ~9 ~0 ~ ~2 2~ 24 25 26 27 ~ ~9 50 ~ 52 ~ ~4 ~5 ~6 ~7 ~ S~ 40 4~ 4~ 4~ 44 8 3 8 0 X IX / T TiT * ~ T T X 8620 X X/ *TX T X 8860 X X / [1 X T X -25- Sample Depth 240 480 720 960 1200 1440 1680 2140 2380 2620 2860 3100 3340 3580 3820 4060 4300 4540 4780 5020 5260 5500 5740 5980 6220 6460 6700 6940 7180 7420 Table 9 Elemental Analysis Weight Percent C H N nsufficient sample nsufficient sample nsufficient sample nsufficient sample nsufficient sample nsufficient sample nsufficient sample 66.43 6.36 1.04 64.26 5.89 0.84 65.62 6.09 1.42 69.30 5.51 1.26 66.66 6.26 1.70 64.57 5.93 1.46 67.53 5.90 1.32 66.37 5.53 1.61 66.00 5.46 1.35 65.82 5.57 1.37 68.79 5.62 1.52 68.25 6.04 1.76 70.45 5.76 1.76 71.15 5.71 1.81 67.94 5.75 1.93 61.04 5.70 1.74 65.74 5.68 1.99 70.30 5.58 1.97 73.32 5.82 2.34 71.18 5.57 1.86 72.85 5.94 1.90 74.24 6.17 2.31 80.79 5.40 2.59 File 85032 H/C 1.14 1.09 1.11 0.95 1.12 1.09 1.04 0.99 0.99 1.01 0.97 1.05 0.97 O.96 1.01 1.11 1.03 0.95 0.95 0.93 0.97 0.99 0.80 -26- Sample Depth 7660 7900 8140 8380 8620 8860 Table 9 Elemental Analysis (cont.) Weight Percent C H N 76.14 6.42 1.90 76.98 5.65 1.50 74.53 5.56 1.29 77.52 5.59 1.11 76.44 5,48 0.92 77.19 5.21 1.04 File 85032 H/C 1.00 0.87 0.89 0.86 0.85 0.80 -27- File No. 85032 Table 10 Normalized Percent Normal Paraffins & Distribution Isoprenoids Depth (FT) 240 480 720 960 1200 1440 nC15 3.0 4.6 3.2 4.4 7.6 5.2 nC16 3.9 6.8 5.0 4.7 10.7 9.3 nC17 5.0 8.4 6.2 4.9 10.2 9.7 Pristane 3.2 6.0 5.4 5.6 7.7 7.1 nC18 5.4 8.6 5.3 4.3 8.1 7.4 Phytane 2.5 4.4 3.1 1.9 4.1 3.7 nC19 5.8 7.4 5.1 4.8 5.4 6.5 nC20 4.5 5.9 4.8 4.4 4.2 6.4 nC21 6.3 6.0 5.4 5.4 3.6 6.6 nC22 4.7 5.7 5.7 5.1 4.4 13.4' nC23 10.8' 5.8 6.8 6.8 4.6 5.0 nC24 4.1 4.2 4.3 5.4 3.7 3.4 nC25 6.2 4.2 6.7 6.5 4.2 2.9 nC26 2.2 2.5 3.7 4.3 2.8 2.1 nC27 2.3 4.4 8.1 7.3 4.3 2.2 nC28 12.1' 1.8 2.7 3.9 2.2 1.6 nC29 1.0 4.1 7.0 6.7 3.9 1.8 nC30 6.5 1.7 2.0 2.9 1.8 1.5 nC31 2.3 4.5 4.7 5.2 2.9 1.6 nC32 5.6 0.9 1.8 1.7 1.3 1.0 nC33 0.7 1.5 2.3 2.9 1.7 1.0 nC34 1.9 0.6 0.7 0.9 0.6 0.6 CPI 2.09 2.31 1.8 1.70 1.19 Isoprenoids Ip13 Ip14 Ip15 Ip16 Ip18 Pristane Phytane 17.0 14.9 38.3 29.8 3.8 3.1 5.4 11.7 13.4 36.1 26.5 Pris/Phy 1.29 1 nC17/Pris 1.57 1 nC18/Phy 2.14 I .36 .41 .97 11.6 19.3 43.9 25.2 1.74 1.14 1.70 4 6 6 15 13 40 13 .6 .0 .8 .2 .5 .1 .7 .9 .8 .2 2.3 2.5 4.2 11.9 19.4 38.7 20.9 1.85 1.33 i .95 2.7 2.5 4.6 9.2 21.7 39.1 20.2 1.93 1.36 2.02 Table 10 (cont.) Normalized Percent Distribution Normal Paraffins & Isoprenoids File No, 85032 Depth (Fl) 1680 2140 2380 2620 2860 3100 nC15 i .7 1.9 1.6 nC16 3.1 3.2 1.8 nC17 7.2 9.5 2.2 Pristane 7.4 9.2 1.1 nC18 9.7 15.7 2.6 Phytane 6.8 10.7 1.0 nC19 7.8 12.2 2.5 nC20 5.3 7.4 1.7 nC21 3.3 4.0 2.7 ~nC22 2.8 3.0 2.6 nC23 2.2 2.3 5.0 nC24 1.7 1.8 2.9 nC25 1.7 2.2 7.4 nC26 1.5 1.5 2.6 nC27 2.0 3.0 13.1 nC28 1.9 1.4 2.8 nC29 3.8 3.4 21.9 nC30 3.9 1.6 2.3 nC31 7.7 2.2 13.1 nC32 5.6 1.5 3.6 nC33 8.2 1.4 5.0 nC34 4.7 0.9 0.5 CPI 1.47 2.3 3.4 6.2 2.7 4.5 7.0 3,4 6.2 7.2 1.6 5.9 3.8 2.8 7.1 6.2 1.5 2.8 2°4 2.7 6.9 5.6 2.2 5.1 4°8 3.0 6.6 4.6 2.6 6.4 4.9 6.1 8.0 6°5 2.6 8.4 4ol 8.4 9.4 6°6 2.1 5.9 3.5 4.5 5.2 8.8 2.3 1.8 2.2 5.8 2.6 8.1 4.7 1.2 2.3 1.4 1.6 3.5 2.7 0.4 1.1 4.1 0.5 0.5 0.5 0.1 0.1 1.67 4.69 4.09 1. 57 2.54 Isoprenoids Ipl3 Ipl4 Ipl5 Ipl6 Ip18 Pristane Phytane Pris/Phy nC17/Pris nC18/Phy 0.7 1.0 2.4 4.2 14.7 40.2 36.8 1.09 0.99 1.44 2 3 1.2 8.4 6 2.5 11.5 10 11.6 17.8 16 39.1 32.9 30 45.5 29.4 29 0.86 1.12 1 I .04 2.00 2 1.46 2.56 I .8 3.6 .7 3.4 .5 5.8 .8 10.1 .3 13.5 .5 43.3 .4 20.4 .04 2.12 .12 I .04 .82 2.55 8.0 6.6 10.6 15.9 15.4 26.5 16.9 1.57 I .91 2.57 Table 10 (cont.) Normalized Percent Distribution Normal Paraffins & Isoprenoids File No. 85032 Depth (Fl) 3340 3580 3820 4060 4300 4540 ~ nC15 0.4 nC16 0.4 nC17 0.4 ~ Pristane 0.3 nC18 0.4 Phytane 0.2 nC19 1.0 nC20 0.5 nC21 0.7 nC22 0.8 ~- nC23 3.1 nC24 1.8 nC25 7.4 nC26 2.7 nC27 12.5 nC28 3.6 nC29 25.5 ~ nC30 7.4 nC31 19.4 nC32 6.6 ~ nC33 4.5 nC34 0.4 CPI 3.24 0.7 0,2 0.3 3.9 0.5 0.7 0.2 0.4 5.9 0.5 0.8 0.6 0.9 5.0 0.8 0.6 0.4 0.6 4.5 1.2 0.6 0.4 0,6 4.2 0.7 0.3 0.2 0.3 4.4 0.2 2.6 1.2 7.0 4.7 5,2 9.3* 14.4' 0.8 3.1 17.9' 1.6 0.7 2,8 3.8 3.5 1.1 0.8 1.4 2.7 1.8 4.6 4.0 4.6 8.4 14.0' 2.1 1.4 1.7 3.0 2.1 8.3 4.8 7.1 8.4 8.0 2.0 1.6 1,7 2.9 1.8 10.1 6.9 8o% 10.1 5.7 1.9 1.6 1.9 2.4 1.8 22.3 14.8 22.8 11.0 11.4 12.8 8.6 10.1 2.3 2.0 10.7 22.8 16.0 4.0 10.6 6.3 7.7 5.1 4.5 5.1 0.2 6.1 4.6 0.3 4.7 0.4 0.6 0.4 0.5 0.5 2.13 2.70 3.00 2.46 3.38 Isoprenoids Ip13 6.2 Ip14 Ip15 19.7 Ip16 31.9 Ip18 12.1 Pristane 18.3 Phytane 11.8 Pris/Phy 1.55 nC17/Pris 1.34 nC18/Phy 2.06 Peak identifications 4 16 40 11 16 9 1 1 1 tenta 3.1 .9 4.8 .7 16.4 20.1 .0 44.1 36.0 .6 9.9 10.9 .9 14.9 22.1 .8 6.8 10.6 .73 .35 .81 tive. 6.7 12.3 15.1 33.5 32.4 4.1 4.4 18.6 33.2 8.4 26.9 4.5 2.20 2.09 1.03 5.92 1.30 1.51 1.11 0.69 1.95 2.28 0.97 3.21 File No. 85032 Table 10 (cont.) Normalized Percent Distribution Normal Paraffins & Isoprenoids Depth (Fl) 4780 5020 5260 5500 5740 5980 nC15 0.7 nC16 0.7 nC17 1.1 Pristane 2.1 '~ nC18 1.2 Phytane 0.6 nC19 3.2 nC20 1.7 nC21 2.1 nC22 2.0 nC23 10.3 nC24 2.7 nC25 7.4 nC26 2.6 ~ nC27 7.9 nC28 3.4 nC29 12.9 ~ nC30 3.9 nC31 18.9 nC32 6.6 nC33 7.3 ~ nC34 0.7 CPI 3.00 0.9 5°3 2.3 1.7 3.2 0.8 1.8 2.1 1.5 3.6 0.9 1.8 2.3 1.7 3.9 2.2 4.6 6.2 3°9 8.3 0.9 1.6 2.1 1.7 4.3 0.4 0.9 1.9 1.0 1.4 2.1 3.9 3.6 3.1 5.7 19.7' 2.9 10.2' 2.2 6.0 2.3 2.5 3.5 4.6 6.3 2.1 2.7 2.8 3.8 6.1 7.9 5.8 6.5 13.5' 7.3 2.1 3.4 3.1 3.9 5.7 6.3 6.0 6.4 9.5 5.6 2.3 3.1 3.2 3.4 3°7 6.1 7.0 7.3 9.9 5.5 2.0 2.8 2.7 2.8 2.3 12.4 12.1 10.1 12.2 6°4 6.8 4.3 3.7 2.8 1.9 11.2 13.1 12.3 9.5 6.9 6.1 7.3 3.4 4.7 2.9 4.2 6.3 3.9 2.4 2.7 0.3 0.8 0.4 0.2 0.3 2.19 2.28 2.73 2.80 2.04 Isoprenoids Ip13 3.0 Ip14 3.6 Ip15 12.2 Ip16 31.3 Ip18 9.9 Pristane 31.4 Phytane 8.6 Pris/Phy 3.66 5 nC17/Pris 0.55 0 nC18/Phy 2.13 2 4.2 5.0 4.4 4.3 4.8 5.2 6.2 5.3 5.3 5.6 8.6 12.5 10.4 13.0 8.5 6.2 33.6 26.4 29.5 20.0 7.1 7.5 7.1 6.5 9.3 4.2 29.7 35.6 33.0 44.2 4.5 5.5 10.8 8.3 7.6 .40 5.38 3.28 3.96 5.81 .41 0.39 0.37 0.44 0.47 .22 1.91 1.12 1.76 3.01 -- * Peak identifications tentative. -31- File No. 85032 Table 10 (cont.) Normalized Percent Distribution Normal Paraffins & Isoprenoids Depth (FT) 6220 6460 6700 6940 7180 7420 nC15 2.7 3.4 3.8 2,8 2.6 2.9 nC16 2.4 3.2 3.8 2.8 2.3 3,1 nC17 2.6 3.9 4.2 3.9 1.3 3.4 Pri stane 8.4 7.5 12.0 8.0 11.4 4.8 nC18 2.8 4.0 4.5 4.9 2.9 4.0 Phytane 1.1 1.2 2.0 2.7 2.0 1,1 nC19 3.8 5.4 5.3 5.9 3.6 4.7 nC20 3.5 5.5 4.8 5.8 3.7 5.4 nC21 4.7 6.7 5.6 6.3 4.8 6.0 nC22 4.6 6.3 4.9 5.8 5.2 6.6 nC23 7.8 8.8 7.5 7.1 6.6 7.6 nC24 4.7 5.3 4.0 5.7 5.3 7.7 nC25 7.6 6.7 6.2 6.9 7.7 7,4 nC26 3.6 3.4 3.0 5.7 5.3 6.8 nC27 8.2 5.6 5.8 6.5 7.8 7.1 nC28 2.7 2.0 2.2 3.8 4.5 4.7 nC29 10.5 6.5 7.5 5.7 8.0 5.1 nC30 2.9 2.0 1.5 2.4 3.4 3.5 nC31 8.6 6.2 5.9 3.7 5.7 3.2 nC32 3.8 3.5 3.3 1.4 2.7 2.1 nC33 2.7 2.6 1.9 1.7 2.5 1.8 nC34 0.3 0.3 0.3 0.5 0.7 1.0 CPI 2.48 2.08 2.30 1.53 1.70 1.18 Isoprenoids Ip13 4.6 5.6 5.6 7.1 5.0 11.4 Ip14 6.5 6.7 7.9 9.9 7.8 16.7 Ip15 8.7 9.2 8.0' 9.3 9.6 13.8 Ip16 21.3 21.0 21.0 17.5 21.5 17.8 Ip18 6.4 7.9 6.1 7.1 7.3 8.5 Pr i stane 46.5 42.9 44.1 36.6 41 .'4 25.9 Phytane 6.0 6.7 7.3 12.5 7.3 6.0 Pris/Phy nC17/Pris nC18/Phy 7.77 6.36 6.05 2.92 0.31 0.52 0.35 0.50 2.58 3.39 2.29 1.80 -32- 5.66 0.12 I .44 4.35 0.72 3.61 File No. 85032 Table 10 (cont.) Normalized Percent Distribution Normal Paraffins & Isoprenoids Depth (Fl) _ 7660 7900 8140 8380 8620 8860 nC15 nC16 nC17 Pristane nC18 Phytane nC19 nC20 nC21 nC22 nC23 nC24 nC25 nC26 nC27 nC28 nC29 nC30 nC31 nC32 nC33 nC34 CPI 3.3 2.9 2.7 10.4 3.4 1.9 4.4 4.0 5.1 5.7 6.2 5.7 7.0 5.2 6.9 4.7 6.9 4.5 5.0 1.5 2.0 0.6 1.49 .8 .7 .7 .0 .5 .2 .0 .1 .1 .6 .8 .5 .3 .1 .9 .8 .0 .2 .1 .6 .3 .7 .29 3.9 3.7 3.8 7.7 4.3 1.1 4.8 4.8 5.2 5.1 6.9 5.9 7.1 5.2 6.3 4.9 6.3 3.3 4.7 2.0 2.3 0.7 1.46 4.5 4.2 3.6 7.9 4.6 1.2 4.7 4.7 5.3 5.4 6.5 6.3 6.4 5.5 6.5 4.4 5.6 3.6 4.4 2.2 2.4 0.1 1.38 4.9 5.0 4.8 9.0 5.2 1.3 5.7 6.5 6.4 6.7 6.9 6.5 5.8 4.6 4.9 3.8 4.2 2.0 2.8 1.3 1.3 0.4 1.31 3.3 3.3 3.8 8.5 4.3 0.9 4.9 5.3 6.1 6°8 7.6 7.0 8.1 5.3 6.4 4.0 5.6 2.2 3.5 1.3 1.4 0,4 1.58 Isoprenoids Ip13 Ip14 Ip15 Ip16 Ip18 Pristane Phytane Pris/Phy nC17/Pris nC18/Phy 6.9 9.6 9.7 18.2 8.9 39.4 7.3 5.43 0.26 1.75 9.3 2.7 0.2 8.5 9.3 4.7 5.3 6.50 0.96 3.66 9.1 12.7 9.8 18.0 7.6 37.4 5.3 .01 .50 .95 6 13 10 17 9 37 5 .7 .2 .1 .7 .5 .2 .6 .62 .45 .84 7.5 10.5 9.5 18.1 9.2 39.3 5.7 6.85 0.53 3.93 6.9 10.7 7.3 17.2 7.3 45.8 4.8 9.49 0.44 4.80 Figure z 35 3O 25 lO VITRINITE REFLECTANCE HISTOGRAM INSUFFICIENT VITRINITE FOR AN ACCURATE REFLECTANCE DETERMINATION 0.00 0.40 0.80 t.20 1.60 2.00 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 2~40 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INOIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 5 STANDARD DEVIATION 0.22 % MEDIAN O.&8 % MODE 0.3! % SKEWNESS 0.03 0.23 0.~6 -0.67 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 83.3 RECYCLED - OXIDIZED ~6.7 6 TOTAL iO0.O % -34- '35 3O 25 1.0 Figure V.ITRTN.ITE REFLEC__,TANOE H.ISTOGRAM AMOCO #~ BECHAROF STATE JOB # · 85032 DEPTH ' 23B0 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS · . . · O. O0 O. 40 O. 80 1.. 20 1.. 60 2. O0 2.40 2.80 3.20 VTTR.INTTE REFLECTANCE STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. ~8 STANDARD DEVIATION 0.2& % MEDIAN 0.~6 % MODE 0.33 % SKEWNESS 0.06 O. 22 O. 22 -0.35 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 ~8 3 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 85,7 RECYCLED - OXIDIZED ~4.3 2& TOTAL ~00.0 -35- ~--- F~gure 3 -~ 3O 25 03 Z ~o VITRINITE REFLECTANCE HISTOSRA 4 INSUFFICIENT VITRINITE FOR AN ACCURATE REFLECTANCE DETERMINATION 5 o o. OD o. 40 o. 8o ~. 2o t. 60 ~. OD ;::,. 402.8o 3.20 VITRINITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 2620 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGE____~NOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. ~4 STANDARD DEVIATION 0.20 % MEDIAN 0.~2 % MODE 0.28 % SKEWNESS 0.05 0.2~ O. 22 -0.29 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INOIGENOUS RECYCLED - OXIDIZED 0 &4 2 TOTAL ~6 PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 87.5 RECYCLED - OXIDIZED ~2.5 TOTAL ~00.0 % -36- F~gure 4 35 30 25 ..~ z io V_TTR]'NITE REFLECTANCE H]'STOGRAM O. O0 O. 40 O. BO VTTRINTTE REFLECTANCE AMOCO #& BECHAROF STATE JOB # ' 85032 DEPTH ' 2860 FEET SAHPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 35 STANDARD DEVIATION 0.33 % MEDIAN O. 24 % MODE O. 45 % SKEWNESS 0.08 0.34 0.28 -0.23 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIOIZED 0 35 8 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 81.4 RECYCLED - OXIDIZED ~8.6 43 TOTAL lO0.O % -37- ---- Figure 5 35 3O 25 U~ Z lo VZTRZNZTE REFLECTANCE HISTOGRAM INSUFFICIENT VITRINITE FOR AN ACCURATE REFLECTANCE DETERMINATION 0.00 0.40 O.BO 1.20 1.60 2.00 2.40 2. BO 3. PO VITRINITE REFLECTANCE AMOCO #1 BECHAROF STATE JOB # · 85032 DEPTH · 3100 FEET SAMPLE: CUTTINGS' CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 0 STANDARD DEVIATION N/A MEDIAN N/A MODE N/A SKEWNESS N/A N/A N/A N/A STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 0 10 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 0.0 RECYCLED - OXIDIZED 100.0 TOTAL 100.0 -38- Figure 6 35 3O to VITRTN 'TE REFLECTANCE H'['STOSRAM O. O0 O. 40 O. 80 I. 20 I. 60 2. O0 2.40 2. BO 3.20 VITR'['NTTE REFLECTANCE AMOCO #! BECHAROF STATE JOB # ' 85032 DEPTH ' 3340 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 56 STANDARD DEVIATION 0.30 % MEDIAN 0.22 % MODE 0.4! % SKEWNESS 0.07 0.30 0.25 -0.i5 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 56 44 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 56.0 RECYCLED - OXIDIZED 44.0 ~00 TOTAL ~00.0 ~ -39- F~gure 7 35 3O 25 z i-4 ,,, Z ~0 VITRINITE REFLECTANCE HISTOGRAM O. O0 O. 40 O. BO t. ~0 t. 60 ~. O0 2.40 2. BO 3.20 VITRINITE REFLECTANCE AMOCO #! BECHAROF STATE JOB # ' 85032 DEPTH ' 35B0 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 26 STANDARD DEVIATION 0.29 % MEDIAN 0.~7 % MODE 0.40 % SKEWNESS 0.06 0.29 0.24 -0.2! STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 26 5 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 83.9 RECYCLED - OXIDIZED 16.! 3~ TOTAL iO0.O -40- F~gure 8 35 3O 25 z io VITRINITE REFLECTANCE HISTOGRAM VITRINITE REFLECTANCE AMOCO #t BECHAROF STATE JOB # ' 85032 DEPTH ' 3820 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 36 STANDARD DEVIATION 0.31% MEDIAN O. 17 ~; MODE 0.47 % SKEWNESS 0.08 0.31 0.29 -0.15 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 36 0 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 100.0 RECYCLED - OXIDIZED 0.0 36 TOTAL 100.0 -41- --"-~ Figure 35 3O 25 O] Z 03 Z lo V 'TR'rNITE REFLECTANCE H'rSTOGRAM 0.00 O. 40 O. 80 1.20 t. 80 2. O0 2.40 2. BO 3.20 VITRINITE REFLECTANCE AMOCO #1 BECHAROF STATE JOB # ' 85032 DEPTH ' 4060 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 95 STANDARD DEVIATION 0.29 % MEDIAN 0.16 % MODE 0.47 % SKEWNESS 0.06 0.29 0.23 -0.22 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 95 5 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 95.0 RECYCLED - OXIDIZED 5.0 100 TOTAL iO0.O % -42- '~-~ F~gure ~0 ~ 35 VITRZNTTE REFLECTANCE HISTOGRAM 3O Z ~ 20 ~0 § 0 0.00 0.40 0.80 1.20 1.60 2.00 2.40 2.80 3.20 VZTRZNITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 4300 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 40 STANDARD DEVIATION 0.24 % MEDIAN O.&6 % MODE 0.36 % SKEWNESS 0.05 0.24 0.2~- -0. ~.8 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 40 ~2 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 76.9 RECYCLED - OXIDIZED 23.! 52 TOTAL lO0.O % -43- Figure 35 3O 25 ~D Z to VZTRZNZTE REFLECTANCE HTSTOGRAM O. O0 O. 40 O. 80 t. 20 1.60 2. O0 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #1 BECHAROF STATE JOB # · 85032 DEPTH · 4540 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 105 STANDARD DEVIATION 0.31% MEDIAN 0.17 % MODE 0.44 % SKEWNESS O. 07 0 °32 0.34 -0.23 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 105 3 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 97.2 RECYCLED - OXIDIZED 2.8 108 TOTAL 100.0 % -44- 35 30 25 U] f.~ Z ,,, tO V'rTRINZTE REFLECTANCE HTSTOGRAM O. O0 O. 40 O. 80 :~. 20 ~.. 60 :>. O0 2.40 ~. 80 3. ~0 V]'TR'rN'rTE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 4780 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 1~2 STANDARD DEVIATION 0.32 % MEDIAN 0.22 % MODE 0.42 % SKEWNESS 0.08 O. 33 0.30 -0.22 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 ~2 0 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS lO0.O RECYCLED - OXIDIZED 0.0 TOTAL lO0.O -45- Figure ~3 35 3O 25 V_TTRTNI'TE REFLECTANCE HISTOGRAM O. O0 O. 40 O. 80 :t. 20 :t. 60 2. O0 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #! BECHAROF STATE JOB # ' 85032 DEPTH ' 5020 FEET SAMPLE: CUTTIN6S .: CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 46 STANDARD DEVIATION 0.29 % MEDIAN 0.~8 % MODE 0.43 % SKEWNESS 0.08 0.30 0.28 -0.38 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 46 5 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 90.2.% RECYCLED - OXIDIZED 9.8 5~ TOTAL ~00.0 -46- 35 3O 25 (:3 lo Figure t4 V]'TR_TN]'TE REFLECTANCE H'rSTOGRAM 0.00 0.40 O. 80 $. 20 1.60 2. O0 2.40 2. BO 3.20 VITRINITE REFLECTANCE AMOCO #1 BECHAROF STATE JOB # ' 85032 DEPTH ' 5260 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 100 STANDARD DEVIATION 0.33 % MEDIAN 0.20 % MODE 0.56 % SKEWNESS 0,07 0.33 0.32 -0.19 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 100 0 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 100.0 RECYCLED - OXIDIZED 0,0 100 TOTAL t00.0 COMMENTS: LARGE PITTED WOODY MATERIAL. -47- ~-~ Figure ~5 ~ 35 3O 25 lO VZTRZNZTE REFLEOTANOE HZSTOSRAM O. O0 O. 40 O. 80 &. 20 &. 60 ~. O0 2.40 ~. 80 3.20 VZTRZNZTE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 5500 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 100 STANDARD DEVIATION 0.40 % MEDIAN 0.2! % MODE 0.69 % SKEWNESS 0.08 0,40 0.44 -0. O0 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 lO0 0 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS lO0.O RECYCLED - OXIDIZED 0.0 ~00 TOTAL iO0.O -48- 35 3O 25 z ,,, Z 1o VZTRZNZTE REFLECTANCE HTSTOSRAM 0.00 0.40 O. 80 1.20 1.80 2. O0 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 5740 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 95 STANDARD DEVIATION 0.44 % MEDIAN 0.26 % MODE 0.57 % SKEWNESS 0.'1_2 0.45 0.48 -0.21 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 95 14 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT Q.O INDIGENOUS 87.2 RECYCLED - OXIDIZED 12.8 ~09 TOTAL 100.0 % -49- Figure t7 35 3O 25 10 VZTRZNITE REFLECTANCE HISTOGRAm4 O. O0 O. 40 O. 80 1.20 $. 60 P. O0 2.40 2.80 3.20 VZTRZNZTE REFLECTANCE AMOCO #l BECHAROF STATE JOB # ' 85032 DEPTH ' 5980 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 99 STANDARD DEVIATION 0.45 % MEDIAN 0.28 % MODE 0.65 % SKEWNESS 0 °09 O. 45 0.42 -0.0! STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 99 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 99.0 RECYCLED - OXIDIZED ~.0 lO0 TOTAL lO0.O -50- -~ '~-'~ Ftgur'e 'J.B ~ 35 3O 25 lO VITRINITE REFLECTANCE HISTOGRAH 0.00 O. 40 O. 80 t. PO t. 60 2. O0 2.40 2. BO 3.20 V];TR'rNITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 8220 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 84 STANDARD DEVIATION 0.37 $ MEDIAN 0.20 % MODE 0.83 % SKEWNESS 0.07 0.37 0.33 -0.0! STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 84 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 84.0 RECYCLED - OXIDIZED ~6.0 lO0 TOTAL ~00.0 % -51- 35 30 25 lO VITRINITE REFLECTANCE HISTOGRAM 0.00 O. 40 0.80 1.20 ~.60 2.00 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 6460 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 34 STANDARD DEVIATION 0.32 % MEDIAN 0.~9 % MODE 0.4~ % SKEWNESS O.OB 0.32 0.31 -0. lO STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 34 8 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS B~.O RECYCLED - OXIDIZED 19.0 42 TOTAL lO0.O % -52- Figure 20 ~ 35 VZTRZNZTE REFLECTANCE HZSTOGRAM 3O ~ 20 ~ ~5 lo 5 0.00 0.40 0.80 ~.20 t.60 2.00 2.40 2.80 3.20 VZTRZNZTE REFLECTANCE AMOCO #1 BECHAROF STATE JOB # · 85032 DEPTH · 6?00 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. B1 STANDARD DEVIATION 0.48 % MEDIAN 0.30 % MODE 0.74 % SKEWNESS 0.08 0.49 0.45 -0.25 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 8~ 19 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 % INDIGENOUS 8~.0 % RECYCLED - OXIDIZED i9.0 % ~00 TOTAL lO0.O % -53- Figure 35 3O 25 n~ Z lo VZTRZNZTE REFLECTANCE HISTOGRAM 0.00 O. 40 0.80 1.20 i.80 2.00 2.40 2.80 3.20 VTTRZNZTE REFLEGTANGE AMOCO. #~ BECHAROF STATE dOB # ' 85032 DEPTH ' 6940 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 23 STANDARD DEVIATION 0.36 % MEDIAN 0.23 % MODE 0.57 % SKEWNESS 0.07 0.37 0.27 -0.41 STATISTICS-FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 23 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 % INDIGENOUS 67.6 % RECYCLED - OXIDIZED 32.4 % 34 TOTAL ~00.0 % -54- Figure 22 35 3O 25 ~ 15 lO 5 0 V'rTRINZTE REFLECTANCE H]'STOGRAM 0.00 0.40 0.80 1.20 t.60 2.00 2.40 2.BO 3.20 AMOCO #1 BECHAROF STATE JOB # ' 85032 DEPTH ' 7180 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED VITRINITE REFLECTANCE STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 99 STANDARD DEVIATION 0.56 % MEDIAN 0.39 % MODE 0.78 % SKEWNESS O,'ii 0.56 0.53 -0. '1_3 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 99 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 99.0 RECYCLED - OXIDIZED i.O lO0 TOTAL iO0.O % -55- Figure 23 L~. 35 3O 25 V]'TR]'NITE REFLECTANCE H]'STOGRAM lo 5 0 0.00 0.40 0.80 i.20 1.60 2.00 2.40 2. BO 3.20 VITRTNITE REFLECTANCE AMOCO #1BECHAROF STATE JOB # ' 85032 DEPTH ' 7420 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 87 STANDARD DEVIATION 1.18 % MEDIAN 0.88 % MODE 1.51% SKEHNESS 0.17 1.19 1.16 -0.17 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 3 87 10 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 3.0 % INDIGENOUS 87.0 % RECYCLED - OXIDIZED 10.0 % 100 TOTAL 100.0 -56- Figure 24 35 3O 25 r,.D Z uJ lO VZTRTNZTE REFLECTANCE HZSTOGRAM 0.00 0.40 0.80 .: ~.20 i.80 2.00 2.40 2.80 'A 3.20 VITRINITE REFLECTANCE AMOCO #1BECHAROF STATE JOB # ' 85032 DEPTH ' 7660 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 81 STANDARD DEVIATION 0.61% MEDIAN 0.45 % MODE 0.76 % SKEWNESS 0.13 0.61 0.57 -0. l! STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 8& &9 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 81.0 RECYCLED - OXIDIZED 19.0 ~00 TOTAL t00.0 -57- Figure 25 ~-~ 35 3O 25 ~o VZTRZNZTE REFLECTANCE HZSTOGRAM o,oo O. 40 O. 80 1.20 ~.. 60 2. O0 2.40 2.80 3.20 VITRINITE REFLECTANCE AMOCO #~ BECHAROF STATE JOB # ' 85032 DEPTH ' 7900 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 59 STANDARD DEVIATION 0.69 % MEDIAN 0.50 % MODE 0.84 % SKEWNESS O.:t5 0.70 0.67 -O.:ti STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT 0 INDIGENOUS 59 RECYCLED - OXIDIZED 4& PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 59.0 RECYCLED - OXIDIZED 41.0 TOTAL &O0 TOTAL &O0.O COMMENTS: THE HIGHER REFLECTING IS GENERALLY PITTED. -58- -~ ~" Figure 35 3O 25 z io VZTRINZTE REFLECTANCE HISTOGRAm4 0.00 0.40 O.BO .20 1.60 2.00 2.40 2.BO 3.20 VZTRTNZTE REFLECTANOE AMOCO #~ BECHAROF STATE JOB # · 85032 DEPTH · 8&40 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLEO - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 65 STANDARD DEVIATION 0.66 % MEDIAN 0.48 % MODE 0.86 % SKEWNESS 0.13 0.66 0.63 -0.04 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 65 35 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 65.0 RECYCLED - OXIDIZED 35.0 &O0 TOTAL &O0.O % -59- 35 3O 25 tO z ,,, 20 Z ~o VTTRIN'rTE REFLECTANCE H'rSTOGRAM 0.00 0.40 0.80 1.20 t. 60 2. O0 2.40 2. [ilo 3. EO VTTRTNZTE REFLECTANCE AMOCO #& BECHAROF STATE JOB # ' 85032 DEPTH ' 8380 FEET SAMPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN, REF. MAX. REF. 37 STANDARD DEVIATION 0.65 % MEDIAN 0.52 % MODE 0.78 % SKEWNESS 0.12 0.85 0.80 -0.04 STATISTICS FOR-THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 37 63 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 37,0 RECYCLED - OXIDIZED 63.0 ~00 TOTAL 100.0 % -60- ~ ~-~ F~gure 28 35 30 25 lO VITRINITE REFLECTANCE HISTOGRAm4 o.oo o.~o o.ao ~.~o :.eD ~.oo ~.~o : ~.ao' ~o~o VITRINITE REFLECTANCE ANOCO #1 BECHAROF STATE JOB # ' 85032 DEPTH ' 8620 FEET SANPLE: CUTTINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 30 STANDARD DEVIATION 0.60 % MEDIAN 0.46 % MODE 0.79 % SKEWNESS 0.60 0.56 -0.03 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 0 3O 70 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 0.0 INDIGENOUS 30.0 RECYCLED - OXIDIZED 70.0 lO0 TOTAL lO0.O % -61- Figure 29 '-~ 35 3O 25 03 Z lO VITRIN'['TE REFLECTANCE HTSTOGRAM 0.00 0.40 0.80 ~. 20 ~. 60 2, O0 2.40 2, BO 3.20 VTTRTN]'TE REFLECTANCE AMOCO #! BECHAROF STATE JOB # ' 85032 DEPTH ' BBCO FEET SAMPLE: CUTTINGS, CAVE OR CONTAMINANT INDIGENOUS RECYCLED -OXIDIZEO STATISTICS FOR THE INDIGENOUS POPULATION NUMBER OF READINGS MEAN REF. MIN. REF. MAX. REF. 36 STANDARD DEVIATION 0.80 % MEDIAN 0.58 % MODE 0.94 % SKEWNESS 0o'14 0.8'1.[ O. 87 -0. '14 STATISTICS FOR THE TOTAL POPULATION READINGS CAVE OR CONTAMINANT INDIGENOUS RECYCLED - OXIDIZED 24 36 40 TOTAL PERCENT OF POPULATION CAVE OR CONTAMINANT 24.0 INDIGENOUS 36.0 RECYCLED - OXIDIZED 40.0 ~00 TOTAL ~00.0 % -62- C10+ SATURATED HYDROCARBON FRACTI-ON BECHAROF STATE #]. - 240 FT. 3. 3.02 2.96 2.90 2.84 u.I Z 2.78 0.00 ! 3.75 I 7.50 I , I li.25 :t5oO0 I 18.75 I 22.50 26.25 30. O0 FIGURE 30 -63- C I0+ SATUBATED BECHAROF STATE HYDROCARBON FRACT]'ON #~. - 48O FT. 5. 251 4.73 4.21 3.69 3.'18 2.66 0.00 I 3.75 I 7.50 Z I '1'1.25 I ~, I ~ I ~, 18.75 22°50 26.25 30.00 15.00 FI GURE 31 -64- C ~.0+ SATURATED BECHAROF S T ATE HYDROCARBON FRACT~'ON #1 - 720 FT. 3.001 2.95 2.9~ 2.87 2.83 2.78I 0.00 I 3.75 I , I 7.50 ]. J. 25 I , I '!5.00 ]8.76 I i I J 22.5~ 26.26 30.0:t FIGURE 32 -65- C10+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #1 - 960 FT. 4.40 4.06 3.72 3.38 3.04 2.7t 0.00 I 3.75 I , I 7.50 1 1 o 25 , I 15.00 FIGURE 33 , I ~8o75 22.50 26.25 30.00 -66- C~O+ SATURATED HYDROCARBON BECHAROF STATE #~ - ~200 FRACTION FT. 3. 401 3.27 3.i4 3.02 2.8g 2.76 0.00 I , 3.75 I , 7.50 I !1.25 I 15.00 I J8.75 I 22.50 I 26.25 30 ..00 FIGURE 34 -67- CIO+ SATURATED HYDROCARBON FRACTION BECHAROF STATE #] - ]440 FT. i LJ C. I i ,, , I ~ I , I ] I , I t I ~ I t 6 5O 571 4 93 4 ~,5 3 37 2 59 0.00 3.75 7.50 ~.25 ~5.00 ~8.75 22.50 26.25 30.00 FIGURE 35 -68- C10+ SATURATED HYDROCARBON FRACTI'ON BECHAROF STATE #~. - ~.680 FT. LLI Z ~ LJ -- I-- -,. rJ) .,I: i-i I _ i J I . i -- c,. I ~ I I I 2" , Z ~ I ~ I ] I ] I , I [ I , I , 5.20 4.69 4.'18 3.68 3.17 2.66 0.00 3.75 7.50 `1`1.25 '15.00 '18.75' 22.50 26.25 30.00 FIGURE 36 -69- CI0+ SATURATED HYDROCARBON FRACTI-ON BECHAROF STATE #1_ - 2140 FT. 4.00 3.74 3.49 3.24 2.98 2.73 0.00 3.75 7.50 Z I-- I ~.25 I '15.00 i ~ I ~8.75 22.50 , I , 26,25 30.00 FIGURE 37 -70- CI0+ SATURATED HYDROCARBON BECHAROF STATE #~ - 2380 FRACTION FT. 4. 201 3.90 3.60 3.31 3.0'1 2.72 0.00 3.75 7.50 , .25 , 15.00 18.75 22.50 I , , , 26.25 30.00 FIGURE 38 -71- CiO+ SATURATED HYDROCARBON FRACTION BECHAROF STATE #]. - 2620 FT. 5.20 4.69 4.~8 3.68 3.17 2.66 0.00 I 3.75 , I , 7.5O z tL] Z I 11.25 , I 15.00 I 18.76 ! 22.51 26.26 30.0:l FIGURE 39 -72- C'IO+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #~. - 2860 FT. 10.30 8.7! 7.1-3 5.55 3.96 2.3 0.00 3.75 7.50 t_ 1_. 25 15.00 18.75 22.50 26.25 30.00 FIGURE 40 -73- C10+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #1 - 3100 FT. 3. 3.54 3.34 3.'14 2.94 2.74 0.00 I , I , I 3.75 7.50 ~,1.25 15.00 18.75 FIGURE 41 I 22.50 26° 25 30. O0 -74- C~.O+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #:!. - 3340 FT. ~ I , I i ,I , I ,, ! , I ~ I I 7.30 6.35 5.40 4.45 3.50 2.55 0.00 3.75 7.50 11.25 15.00 ~8.75 22.50 26.25 30.00 FIGURE 42 -75- C '1 O+ SATUBATED BECHAROF STATE HYDROCARBON #~ - 3340 FRACTION FT. (DETAIL) 3. 601 3.43 3.26 3.09 2.92 ('r) Z 2.75 0.00 3.75 ! 7.50 I 11.25 t5.00 '18.75 i 22.50 26.25 30.00 FIGURE 42A -76- C].O+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #1 - 3580 FT. ] I I I I I [ I , l, ] I , ,I ,, 2]..70 ].7.66 ].3.63 9.60 5.57 .53 0.00 3.75 7.50 ~ ].. 25 15. O0 :~8.75 22.50 26.25 30. O0 FIGURE 43 -77- C10+ SATURATED HYDROCARBON BECHAROF STATE #1 - 3580 FRACTION FT. {DETATL) 3 35 3 20 3 O5 2 90 2 76 0.00 I 3.75 ,I , 7.50 I :15.00 I , I :18.75' 22,50 I 26.25 30. O0 FIGURE 43A -78- C10+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #~. - 3820 FT. 25. 20.37 :t5.64 ~0.9! 6.'18 :1.. 45 0.00 3.75 7.50 t t. 25 :!.5. O0 '18.75 22.50 26.25 30. O0 FIGURE 44 -79- CiO+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #! - 3820 FT. 4. 301 3.96 3.62 3.28 2.94 2.61 0.00 , I 3.75 7.50 li.25 I 15.00 I , I i8.75 I 22.5O , I 26.25 30. O0 FIGURE 44A -80- CiO+ SATURATED HYDROCARBON BECHAROF STATE #i - 4060 FRACTTON FT. 5.60:_ 5.00 4.4'1 3.82 3.23 2.64,, 0.00 , I , , I , I 3.75 7.50 1 '1.25 I , I '15.00 `18.75 , 22.50 I 26.25 30. O0 FIGURE 45 -81- C~O+ SATURATED HYDROCARBON BECHAROF STATE #] - 4060 FRACTION FT. (DETAIL) 3.05J 2.99 2.94 2.89 2.83 Z ILl Z I 2.78[ 0.00 I I I 3.75 7.50 I :[5.00 I :[8.75 22.50 26.25 30.00 FIGURE 45A -82- C10+ SATURATED HYDROCARBON BECHAROF STATE #1 - 4300 FRACTTON FT. 3. 851 3.58 3.32 3.05 2.79 W LIJ Z Z I-- I--- f.~ ~_ 2.53 0.00 I , I 3.75 7.50 , I ~1.25 i I t5.00 I , I 18.75 22.50 I 26.25 30.00 FIGURE 46 -83- CiO+ SATURATED HYDROCARBON FRACTION BECHAROF STATE #i - 4540 FT. 20.30 ~-6.54 12.78 9.02 5.26 .51 0.00 3.75 7.50 11.25 15.00 18.75 22.50 26.25 30.00 FIGURE 47 -84- C~O+ SATURATED B~ CHABOF ST AT~ HYDROCARBON FRACT I ON #]. - 4780 FT. 23. 901 ~9.40 14.90 lO .4~ 5.9'1 '1.4'1 0.00 I , I , I 3.75 7.50 '1 '1.25 15. O0 , '18.75 I 22.50 , I , i 26.25 30.00 FI GURE 48 -85- C].O+ SATURATED HYDROCARBON FFIACTTON BECHAROF STATE #t - 5020 FT. 16.t. 0 .22 10.35 7.48 4.6'1 t.74 0.00 3.75 7.50 '1 '1.25 '15. O0 '18.75 22.50 26.25 30° O0 FIGURE 49 -86- CiO+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #1 - 5260 FT. 13. l~.17 8.85 6.53 4.2~ .88 0.00 3.75 7.50 ll.25 ~5.00 18.75 22.50 26.25 30.00 FIGURE 50 -87- C10+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #1 - 5500 FT. L~ Z -- .cE _ O. '-' I ' uJ I ~ ,, I , I , I , , I , I, , I , I , 19.00 15.58 12. ~.6 8.74 5.:22 1 .go 0.00 :2.75 7.50 ~. ~.. 25 t5. O0 t8.75 22.50 26.25 30. O0 FIGURE 51 -88- CIO+ SATURATED HYDROCARBON BECHAROF STATE #1 - 5740 FRACTZON FT. 8.20 7.01 5.83 4.65 3.47 2.28 , I ~ .. I , I ,. 0.00 3.75 7.50 ll.25 15.00 I 18.75 I 22.50 ,I , 26.25 30. O0 FIGURE 52 -89- C:~O+ SATURATED HYDROCARBON FRACT-[ON BECHAROF STATE #1 - 5980 FT. 23.00_ !B. 73,_ , ~4.47 ~0.20 5.94 .67 0.00 3.75 7.50 ~1.25 ~5.00 18.75 22.50 26.25 30.00 FI GURE 53 -90- C J.O+ SATURATED HYDROCARBON FRACTI'ON BECHAROF STATE #1 - 6220 FT. 4.70 4.25 3..8J 3.37 2.92 2.48 0.00 3.75 7.50 :~ :~. 25 :~5. O0 :~8.75 22.50 26.25, 30. O0 FIGURE 54 -91- CI0+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #I - 6460 FT. 10.65 8.95 7.25 U . 3.85 2.15 0.00 I 3.75 I 7.50 I 1t.25 I 15.00 I 18.75 I 22.50 I 26.25 30. O0 FIGURE 55 -92- C10+ SATURATED HYDROCARBON BECHAROF STATE #~ - 6700 FRACTION FT. 6.25 5.47 4.70 3.93 3.16 2.39 0.00 I , I , 3.75 7.50 .25 I , I I 15.00 18.75. I 22.50 I 26.25 30.00 FIGURE 56 -93- CiO+ SATURATED HYDROCARBON FRACT'rON BECHAROF STATE #1 - 6940 FT. ii.go 9.97 8.05 6. "13 4.2! I 2.29 0.00 I 3.75 I 7.5O I I `15.00 i , , '18.75 ,I 22.50 I 26.25 30,00 FIGURE 57 -94- C~.O+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #]. - 7~.80 FT. 48.30 38.63 28.96 '19.2cJ 9.62 -.04 0.00 3.75 7.50 `1 `1.25 '15. O0 '!8.75 22.50 26.25 30. O0 FIGURE 58 -95- CiO+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #]. - 7420 FT. 40.70 32.6g 24.69 LIJ Z I-- ~6.69 8.69 .69 0.00 I i I , I 3.75 7.50 '1 ].. 25 i5. O0 , ~8.75 , I 22.50 I 26.25 30.00 FIGURE 59 -96- C1_0+ SATURATED HYDROCARBON FRACTTON BECHAROF STATE #I - 7660 FT. 25.501 20.70 15.91 11.12 6.33 1.53 0.00 I 3.75 I , I 7.50 ~ ~. 25 ,I ~.5. O0 , I, :t8.75 I 22.50 I , 26.25 3O.00 FIGURE 60 -97- C~O+ SATURATED HYDROCARBON BECHAROF STATE #~ - 7900 FRACTION FT. 28.50 23.03 .56 12.09 6.62 i.'16 , I 0.00 3.75 I 7.50 I ~ .25 I I I I - ~-5. O0 ~.8.75 I , I i 22.50 26.25 30.00 FIGURE 61 -98- C~.O+ SATURATED HYDROCARBON FRACT'fON BECHAROF STATE #~. - 8140 FT. 1`7. 801 1`4.63 1. t.46 8.30 5.`13 i .96 0.00 I I I 3.75 7.50 I I 15.00 I I '18.75 I I I 22.50 26.25 I , I 30.00 FIGURE 62 -99- C].O+ SATURATED HYDROCARBON BECHAROF STATE #I - 8380 FRACTION FT. 19. 301 :1.5.77 12.24 8.72 5.'19 1.67 0.00 3.75 7.50 I , I .25 15.00 I 18.75 I 22.5O [ I , 26.25 30.00 FIGURE 63 -100- ~HOCO ~1 BECHAROF gTATE DEPTH RANGE 5020 SAMPLE TYPE CUTTINGS RO UALUE COUNT .18 1 · ~.. .,'1 2 2,3 ,3 2 L. 25 1 26 4 '1 ? 28 RO VALUE .29 .30 .3! 32 ,33 34 35 40 COUNT RO UALUE .41 .43 .62 .80 .9'7 4.54 COUNT DEPTH RANGE 5260 SAMPLE TYPE CUTTINGS RO VALUE COUNT .20 1 .q .,:1 1 .23 1 .25 .26 4 .27 .28 7 .29 .30 7 RO VALUE ,31 .34 .SE; .'~7 .38 .40 COUNT RO VALUE I41 .42 .43 i44 .46 .47 .48 .50 COUNT DEPTH RANGE 5550 SAMPLE TYPE CUTTINGS RO VALUE COUNT .21 1 .,'4 1 ,-!, .,:7 1 29 2 30 1 31 ]. 32 '~ ,~5 7 ,74 1 3S '~ RO VALUE 3,'7 '38 40 41 42 43 44 45 COUNT RO VALUE ,4B .47 .48 .49 .50 .51 .53 .55 COUNT AMOCO ~1 BECHAROF STATE DEPTH RANGE 5740 SAMPLE TYPE CUTTINGS RO VALUE COUNT .Z5 .27 1 .30 1 .-33 1 3S -3 .3E 37 4 38 I 39 3 41 S 42 3 43 44 3 RO VRLUE 45 46 4,'7, 48 49 S0 S1 S3 S4 S7 79 COUNT 11 4 9 12 8 1 1 2 1 1 i 1 RO V~LUE 8i 97 1 05 1 07 I 11 1 58 1 49 1 80 1 8? 1 68 · / 4.11 COUNT DEPTH RANGE S980 S~MPLE TYPE CUTTINGS RO VALUE COUNT .28 1 .30 1 .-31 4 .'33 2 34 3 3S 2 37 6 38 1 39 4 40 S RO VALUE 41 42 44 45 46 47 48 49 S0 S1 COUNT RO VALUE .S2 .S4 .SS .SS .58 .S9 .6S 8~ · ,-- COUNT AMOCO ~1 8ECHBROF STBTE DEPTH RANGE 6a~0 SAMPLE TYPE CUTTINGS RO VALUE COUNT 20 1 25 2 26 t °7 3 ,. °8 l °9 1 30 2 31 5 32 6 33 4 DEPTH RANGE SAMPLE TYPE RO VALUE .19 .22 .24 .25 .26 .~0 .31 .,32 6460 CUTTINGS COUNT RO VALUE .40 .41 .42 .43 .44 .45 .46 .48 .52 .54 .58 .70 RO VALUE .34 .'55 .'56 .'58 .40 .41 .SS COUNT COUNT RO VALUE '7'3. .79 .81 .82 1.01 1.11 1.45 1.48 i 1.84 2.05 ~ .78 2.81 .~.94 4.45 RO VALUE .58 .68 .78 1.02 1.94 1.97 3.79 COUNT COUNT ~MOCO ~i ~ECHAROF ST~T£ DEPTH RANGE 6700 SAMPLE TYPE CUTTINGS RO VALUE COUNT ,33 2 34 2 37 1 '39 3 40 '3 41 3 42 3 4,3 4 44 45 8 46 S 4? '3 48 49 2 RO VALUE .50 .51 .52 .55 54 5G 58 59 81 82 70 7-3 74 82 88 87 COUNT RO VALUE 1 00 1 05 1 07 1 .31 1 .35 1 47 1.58 i .91 2.07 .14 2 ..31 ..- · 2.40 · ' .57 · .-.83 3.2B COUNT DEPTH RANGE 8940 SAMPLE TYPE CUTTINGS RO VALUE COUNT ,..3 27 ,,8 30 .32 -33 .38 '37 RO VALUE .38 .45 .48 .49 .50 .57 .78 .89 COUNT RO VALUE 1.11 1.18 lilg 1.24 1.27 1.28 1 1.40 COUNT AMOCO ¢1. 8ECHAROF STATE DEPTH RANGE 7180 SAMPLE TYPE CUTTINGS RO VALUE COUNT 39 1 40 1 41 1 4,3 ~ 44 1 45 1 46 5 .47 2 .48 4 .49 2 .50 4 .51 1 RO VALUE S2 55 54 55 56 57 58 .59 .60 .62 COUNT 4 8 '1 8 5 S 2 4 7 4 4 RO VALUE .64 .55 .67 .69 .70 .71 .73 .74 .78 .90 COUNT DEPTH RANGE 7428 SAMPLE TYPE CUTTINGS RO VALUE COUNT 52 SS 74 88 92 9-5 97 98 99 00 ,01 .04 .05 06 07 08 09 10 111 12 RO VALUE 1.13 1.14 1.16 1.17 1.18 1.19 1 * I .21 02 1.23 1.24 1.25; 1.26 i .27 1.28 i .29 1 ..50 1 1 -5~ , 1 ..55 COUNT RO VALUE .'58 .40 .42 .46 .47 .49 .S1 G"" · .57 .G8 ,70 .72 .73 .77 .8S COUNT ~HOCO ¢1 8ECHAROF STRT£ DEPTH RGNGE 7660 SAMPLE TYPE CUTTINGS RO VALUE COUNT 45 1 48 2 S1 52 6 54 ,. SS S S? 58 4 60 S .61 6 .62 1 .63 3 .64 S RO VGLUE 65 66 68 69 70 71 72' 73 74 76 81 83 88 COUNT RO VALUE .88 .89 ,91 .94 .96 .97 .99 1 1.03 1.06 1.11 1 COUNT DEPTH RANGE SAMPLE TYPE RO VALUE S0 S3 58 60 6~ 6.5 64 6S 66 67 68 69 ?0 71 ?2 ?4 ?S 76 77 7900 CUTTINGS COUNT RO V~LUE 80 82 84 92 98 1 07 1.11 1.1S 1 1.27 1 42 1 54 1 S6 1 60 1 64 1 66 1 67 1 68 1 69 COUNT RO VALUE 1.71 1.72 1 1.74 1 1.82 1.83 1.84 1.8S 1.88 1.87 1.90 1.91 1.96 2.00 '~ 02 ,.-. 2.04 2.61 '~ 68 COUNT AMOCO ~.l B.ECH~ROF _-STATE BEPTH RANGE 8148 SBMPLE TYPE CUTTINGS RO VALUE COUNT RO VALUE 48 1 .79 533 1 .80 S4 2 .833 56 2 .84 57 1 .85 58 33 .SC 60 4 .99 61 4 1.02 62 5 1.25 63 7 1.334 65 4 1.39 68 2 1.41 67 5 1.43 88 2 1.44 69 4 1.46 70 4 1.533 71 33 1.58 74 1 1.83 .75 1 1.84 .?? 1 COUNT · 2 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 RO VALUE 1.88 1.70 1,71 1.78 1.77 1.82 1,87 1.88 1.91 1.93 1.04 1.97 2.01 2.03 2.09 ~.10 ~.12 2.28 8? · COUNT 1 1 1 1 1 1 1 1 1 2 1 1 1 1 1 1 1 1 1 DEPTH RANGE SAMPLE TYPE RO VAL .52 54 57 58 68 61 62 833 84 85 87 68 69 .70 .71 .72 .73 .74 .7,5 833380 CUTTINGS UE COUNT RO VALUE .80 .82 .83 .84 .85 .86 .87 .88 .89 .90 .91 .92 .933 .94 93 96 g? 98 99 1 00 COUNT RO VALUE 1.01 1.03 1 05 1 07 1 18 1 11 1 133 1 25 1 26 1 ~ ,'B 1.40 1 S2 i 82 1 79 1 83 1 88 ,..) ,- 01 2 04 2 12 COUNT ~MOCO ¢! BECHAROF STATE DEPTH RANGE 8620 SAMPLE TYPE CUTTINGS RO UALUE COUNT 46 1 S0 1 S2 "" S3 1 S4 S6 3 S7 3 S@ 2 ,S9 -3 GO ! 61 1 62 1 GS 2 B7 2 69 70 1 72 73 79 1 @0 4 .83 2 .86 2 RO V~LUE .88 .90 .92 .93 .99 1 1 0° 1.05 1 1.08 1.09 1.11 1 1 °4 1.26 1.31 1,3-3 1.38 1 i .41 COUNT RO VALUE 1.43 1,44 1.4S 1.49 1 1. SS 1 .S8 1 .S9 1.61 1 1.64 1 1.67 1.70 I .78 1.82 1.87 1.90 1,95 2.00 2 COUNT AMOCO ~1 BECHAROF STATE DEPTH RANGE 8860 SAMPLE TYPE CUTTINGS RO VALUE COUNT 2'3 41 1 42 2 45 2 44 45 4? 1 49 1 50 2 51 52 1 5'3 2 54 ,. 56 61 1 64 1 66 2 I ,' ?,3 ?4 1 RO UALUE "76 ?8' '79 88 8.[ 8,5 84 8S 86 8'7 88 .89 90 cj,'"., 9-5 94 95 96 98 COUNT. RO UALUE 99 1 00 I 01 1 02 1 03 i 05 1 06 i .07 1,09 1,10 1,11 1,1G 1,21 1,24 i ,25 1.30 1,53 1,48 1.82 COUNT C1_0+ SATURATED HYDROCARBON FRACTION BECHAROF STATE #1 - 8620 FT. 16.30 13.38 10.47 7.56 4.64 1.73 0.00 3.75 I 7.50 I tl.25 15. O0 I 18.75 I 22.50 I 26.25 30.00 FIGURE 64 -101- C10+ SATURATED HYDROCARBON BECHAROF STATE :ff-J. - 8860 FRACTION FT. 5.201 4.65 4.10 . c~ . 2.45 0.00 3.75 7.50 .25 I i5.00 I 18.75 J i J ~ 22.50 26,25 30.00 FIGURE 65 -102- Appendix A Individual Vitrinite Reflectance Readings APIOCO ~1 BECHAROF STATE DEPTH RRNGE 2140 SAMPLE TYPE CUTTINGS RO UALUE COUNT RO VALUE .16 1 °1 1 ,3t COUNT RO UALUE 5.08 5.10 COUNT DEPTH RANGE~ o380 SAMPLE TYPE CUTTINGS RO VALUE COUNT .16 2 17 o · ,' .18 I .19 2 .20 I RO VALUE .21 .24 .26 .S2 COUNT RO VALUE 1.70 2.69 ,-' . 84 COUNT DEPTH RANGE 2620 SAMPLE TYPE CUTTINGS RO VALUE COUNT .12 1 .16 1 .18 2 .19 ~ ~ .20 1 .21 1 RO VALUE 2o · · ~ .27 .28 I °S COUNT 1 1 1 1 RO VALUE 3.16 3.26 3.55 4.55 COUNT 1 1 1 1 DEPTH RANGE 2860 SAMPLE TYPE CUTTINGS RO VALUE COUNT 24 26 28 51 54 35 RO VALUE .36 38 39 48 44 45 60 COUNT RO VALUE .77 .86 1.27 1.56 1.78 ,-'.45 3.24 5.11 COUNT AMOCO ~I BECHAROF ST4TE DEPTH RANGE 3100 SAMPLE TYPE CUTTINGS RO VALUE COUNT .98 1 1.00 1 1.23 1 1.97 1 ? 1~ 1 ~.IS 1 ~.18 1 2.19 1 2.84 1 ~.94 1 Z,4S 1 3.S? 1 AMOCO ~1 8ECHAROF STATE RO VALUE .SL?I .5.95 4,19 4,29 4,35 4,38 4,45 4.50 4.51 4,54 4,58 COUNT RO VALUE 4.94 5.01 5.37 5,39 5,45 5.54 S.G9 5,70 5,82 6.09 COUNT DEPTH RANGE 3340 S~MPLE TYPE CUTTINGS RO V~LUE COUNT .,,g 1 .24 .25 6 26 2 27 4 28 S · ,9 1 30 S -51 G · -5.5 4 .54 3 55 3 37 2 58 39 1 40 2 41 1 4? 1 48 1 RO VALUE ,51 .52 ,54 ,55 .56 .57 .58 ,65 .66 ,67 68 76 77 84 86 97 1 04 1 08 1 28 1 ~ ,--9 COUNT 1 1 2 1 1 1 1 1 3 1 1. 1 1 1 1 1 1 1 1 RO V~LUE 1 1.38 1.43 1.51 1.52 1.54 1 2.30 2.34 ~- 60 2.81 2.99 .5.14 4.01 4.18 4.41 4.44 4.59 5.42 6.01 COUNT AMOCO ~! BECHP, ROF STATE DEPTH RANGE 3580 SAMPLE TYPE CUTTINGS RO VALUE COUNT 17 1 22 2 24 4 25 1 26 3 29 1 30 2 31 1 RO VALUE .32 .34 .3S .37 .38 .39 .40 COUNT RO VALUE 67 1 09 2 06 4 81 S 78 COUNT DEPTH RANGE SAMPLE TYPE RO VAL 3820 CUTTINGS UE COUNT RO VALUE .17 1 .31 .20 1 .32 .24 2 .34 27 ~ 35 .28 1 .29 COUNT 2 2 3 S RO VhLUE .4S .47 4.03 4.10 COUNT DEPTH RANGE SAMPLE TYPE RO VAL 16 17 19 20 <1 23 24 .-5 26 27 28 4060 CUTTINGS UE COUNT RO VALUE .29 30 31 32 35 37 38 39 40 COUNT RO VALUE .41 .43 .45 .47 .82 .93 .97 2.04 3.32 4.00 4 '~ .,-'1 COUNT AMOCO ~1 8ECHAROF STATE DEPTH RANGE 4300 SAMPLE TYPE CUTTINGS RO VALUE COUNT 16 18 20 21 4 ,'am 4 24 4 25 "" 26 2 2? 2 29 DEPTH RANGE 4540 SAMPLE TYPE CUTTINGS RO VALUE COUNT .17 1 ,19 1 o0 1 · ,- .,-'1 1 .22 2 ..'3 2 °4 4 ..'5 4 .26 2 .27 4 DEPTH RANGE 4780 SAMPLE TYPE CUTTINGS RO VALUE COUNT 22 1 25 1 24 1 25 2 27 7 28 10 ..-9 6 RO VALUE I ~0 45 S2 1 05 1 21 1 42 2 iS RO VALUE .28 .29 .30 ,S1 · ,.' .'54 ,'55 ,'57 RO VALUE .30 .'51 .'52 .'54 .36 COUNT COUNT 5 7 7 10 8 7 11 7 2 6 COUNT 9 10 ? RO VALUE ~.17 2,55 2,84 3,13 3..56 .5.87 5.04 5,52 S,82 RO VALUE .59 .40 .41 .42 .44 ,55 .98 ,51 RO VALUE .'57 .58 .'59 .40 .41 .42 COUNT COUNT COUNT 2 5 6 2 4 Date 11-12-84 11-13 to 11-15 11-16 to 11-20 11-21 11-22 to 11-24 11-23 to 11-25 11-26 11-27 11-28 to 12-05 12-06 12-06 to 12-08 12-09 to 12-11 12-12 to 12-15 12-16 12-17 12-18 to 12-20 12-21 to 12-22 Chronological Well History Becharof State Well No. 1 Bristol Bay, Alaska RECEIVED Event Drive 13 3/8-inch casing to 82' KB Rig up a nipple up diverter system Spud and drill to 1,900' Run DIL-SP-GR; ran 9 5/8-inch casing and set at 1,888 feet - cemented with 800 sx Class 'G'. Had 87% returns. Ran 1" pipe to 105' KB and did top job with 22 sx Class 'G' to surface. Pressure tested 9 5/8-inch casing to 1,500 psi for 30 minutes. Nipple up BOPs and test. Drill to 2,725'. Core #1:2,725 to 2,750' and drill to 3,663'. Core #2:3,663 - 3,716' Drill to 7,895' Core #3:7,895 - 7,943' and drill to 8,055'. Log: Reaming Drill to 9,013' Fish for cone and shank off bi t-recovered. Core #4:9,013 - 9,023'. Log Run 7" casing to 8,606' and cement with 1100 sx Class 'G'. ~ ~. 1,~ ~ Run cased-hole logs. 12-23 to 12-25 F~ 25 ~(~5 01 18 to Ji & G~s Oons. OommJssJonPlug and abandon. Anchorage 22. Type Electric or other Logs Run 11-19-84 DIL-SP-GR 12-07-84 12-18-84 DI-SFL-GR LDT-CNL-NGT LSS SHDT Dual Dipmeter DI-SFL-GR LDT-CNL-NGT LSS SHDT Dual Dipmeter CST 12-19-84 12-23-84 RFT - 55 points from Borehole Gravimeter Vertical Seismic Profile 1,900 - 1,982 feet 8,055 - 1,888 feet I! II I! II II I! 9,023 - 8,045 feet II !! II II II il " 1,900 feet 8,326 to 2,840 feet 8,533 to 0 feet II II RECEIVED 'qlaska O# & ~as Con- AnCflorag~' Commi~lo~ Depth (Feet) 45O 900 1,235 1,490 1,900 2,275 2,705 3,210 3,645 4,050 4,473 4,864 5,280 5,460 5,82O 6,329 6,767 7,073 7,440 7,864 8,207 8,530 9,001 9,013 BECHAROF STATE NO. 1 Inclinometer Record Inclination (Degrees) .25 0.0 0.0 0.0 0.0 0.25 .25 .25 1.25 .25 .25 1.25 2.0 2.0 4.0 5.0 5.5 5.75 5.75 4.0 2.75 3.0 1.50 1.25 Oil &~Gas Cor~s. Comrllissiort '~nChorage Cc. pletion Report Well llistory _Samples Mud~Log Core Chips Requt[ed Incltnakton Survey Dizectional Survey Test Reports · Date Receive~d . Remarks . Amoco Production Compa'.~-'t' ENGINEERING CHART SHEET NO. FILE OF APPN W. G. Smith District Manager February 8, 1985 Amoco Production Company Post Office Box 100779 Anchorage. Alaska 99510 907-:272-8471 File' TJZ-O51-WF PERSONAL AND CONFIDENTIAL Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Subsequent Report for Plugging and Abandonment Becharof State Well No. 1 Bristol Bay, Alaska Attached in duplicate is a State of Alaska Form 10-403, Sundry Notice and Reports on Wells, for the subject well. Verbal approval to plug and abandon this well was granted from Harold Hedlund of your office on January 18, 1985. Additionally, a state representative was on site to witness the work. ! No commercial quantities of hydrocarbons were found. We plan to move all equipment off location and reclaim the area for final inspection by September 1985. A wellbore diagram is attached with the location of tested zones, bridge plugs, and cement plugs. A Well Completion or Recompletion Report and Log (Form 10-407) will be sent with the complete well record as soon as possible. Please contact Kevin Smith in our Anchorage office if you require and- additional information. Very truly yours, W. G. Smith District Manager Attachments KLS/dds RECEIVED F 1 ! 1985 AlasKa 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA'~-~L AND GAS CONSERVATION C~_~'MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER Name of.Operator Amoco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well 500' FNL, 1,000' FEL Section 10, T28S, R48W, S.~1. 7. Permit No. 84-157 8. APl Number 5o- 285 -20001 9. Unit or Lease Name Becharof 10. Well Number 11. Field and Pool Wildcat 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. 201.7' KB ADL 304952 ~ 12. Check Appropriate Box To Indicate Nature of Notice, Report,, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) (Submit in Triplicate) _ Perforate [] Alter Casing [] Perforations [] Altering Casing I-1 Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). 1. A state representative arrived on location January 18, 1985. 2. Spot five sacks (25 feet) of Class "G" cement from 4,214 to 4,189 feet over perforated interval 4,201 to 4,211 feet. 3. Set bridge plug at 4,150 feet. 4. Spot ten sacks Class "G" cement on top of bridge plug from 4,100 to 4,150 feet. 5. Set final bridge plug at 120 feet. 6. Test casing and bridge plug to 1,000 psi. 7.' Cement to surface with 15 sacks Class 'G' cement. 8. Weld on well abandonment marker and steel plate to top of 7-inch casing. RECEIVED Alaska 0~t & Gas Cons. Commission Anchorage 14. I hereby certdy that the foregoing is true and correct to the best of my knowledge. ...... /, ~-~,_)~ District Manager Signed i~,j' I,L'I _~ I ~'[, L (~v. Title The space below for Commission use · Conditions of Approval, if any Da~2/08/85 Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10403 Rev. 7-1430 and "Subsequent Reports" in Duplicate ./ il SHEET NO. Amoco Production ~ompa~-/ F,LE ENGINEERING CHART SUBJECT J~...CVIA~OF' ,,~"T'I~T~r._ J,k,l~.l...l_- ~k/O.J DAT" I--~- ~'- J~--~"' W. G. Smith Dislrict Manager January 15, 1985 File' TJZ-O26-WF Personal and Confidential Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Commission Anchorage, Alaska 99501 Dear Sir' Monthly Report of Operations Becharof State No. I Attached in duplicate is the State of Alaska of Drilling and Workover Operations, for the reporting December 1984 activities. Very truly yours, Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 Form 10-404, Monthly Report above referenced well, W. G. Smith District Manager Attachment JCB/pmg cc: Shell Western E&P, Inc. RECEIVED JAN 1 8 1985 Alaska Oil & Gas Cons. Commission Anchorage ,. - STATE OF ALASKA ALASKA ~- AND GAS CONSERVATION CC...~VllSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS [1, Drilling well Workover operation [] 2. Name of operator Amoco Production Company 3. Address P. 0. Box 100779 4. Location of Well at surface 500' FNL, 1000' 5. Elevation in feet (indicate KB, DF, etc.) 201.1 KB 7. Permit No. 84-157 Anchorage, Alaska 99510 FEL, Section 10, TZ8S, R48W, S.M, 8. APl Number 5o-285-20001 9. Unit or Lease Name Becharof 6. Lease Designation and Serial No. ADL 304952 10. Well No. 1 11. Field and Pool Wildcat For the Month of DeCember ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month, 9023' Footage drilled, 3,133' Spud date, 11/16/84 Fishing job, 12/16/84, recovered cone, shank, and inserts with magnet at 9013'. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 7" 29# casing and set at 8606' KB on 12/21/84. Cemented with 1,100 sx Class "G". Pressure tested to 1,500 psi for 30 minutes. 14. Coring resume and brief description Core #3 on 12/06/84 from 7895'-7943', recovered 47' of sandstone, siltstone. Core #4 on 12/17/84. from 9013'-9023', recovered 10' of green schist Metamorphics Sidewall cores on 12/09/84 from 8055'-1,888', recovered 14 of 16 shots, ss, claystone, shale. Sidewall cores on 12/19/84 from 9023'-1,888', recovered 91 of 150 shots, ss, claystone, shale. 15. Logs run and depth where run 12/07/84, DI-SFL-GR, LDT-CNL-NGT, LSS, SHDT Dual Dipmeter, 8,055'-1,888'. 12/18/84, DI-SFL-GR, LDT-CNL-NGT, LSS, SHDT Dual Dipmeter, CST, 9,023'-8,045'. 12/19/84, RFT, 55 points from 8326' to 2840'. 12/23/84, Borehole Gravimeter, VSP, 8,533'-0'. 6. DST data, perforating data, shows of H2S, miscellaneous data See Attachment 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. RECEIVED j AN I 8 1985 AlasKa Oil & Ga.s Cons, Commission Annho.~r, q9 hNOTE--Report on this forq;~4~ required for eac calendar month, regardless of the status of operations, and must be f~led ltv'duplicate with the Alaska Oii and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate ATTACHMENT BECHAROF STATE NO. 1 DST DATA DST NUMBER DATE 12/26/84 12/27/84 12/28/84 12/30/84 12/31/84 INTERVAL 8300'-8332' 8300'-8332' 7780'-7880' 7470'-7550' 7470'-7550' PERFORATION and RECOVERY DATA Perforated 4 SPF, 0.5" holes. DST tool failure, no recovery. No recovery Perforated 4 SPF, 0.5" holes. Total recovery 2392 feet (15.7 bbl) drilling mud, water. No shows. Perforated 4 SPF, 0.5" holes. DST tool plugged, 0.9 bbl recovery, drilling mud. Flowed gas to surface, 30 MCFD @ 30 psig. 87.5% Methane, 4.7% Ethane, 2.3% Propane, 0.8% Butane, 1.0% Hydrogen, 3.7% other. MEMORANOUM TO: THRU: State- of Alaska FROM: ALASKA OIL AND GAS CONSERVATION CO~IISSION C. V.~~er~ton Chai~a~¢~ Lonnie C. Smith //,?~-~: .... ¢ .3 Commissioner DATE: December 21, 1984 F,LENO: D.41.50 TELEPHONE NO: Doug Amos .... Petroleum Inspector SUBJECT: Witness BOP Test at Amoco's Becharof No. 1 Well. Sec. 10, T28S,R48W,SM, Permit No. 84-157 on Parker Rig 122. Friday, November 23, 1984: I traveled this date from Anchorage to King Salmon t° wit~ess ~e BOP test at Amoco's Becharof No. 1 well. Saturday, November 24, 1984: The BOP test commenced at 8:00 pm and was' concluded a'6 2:00 am, November 25, 1984. There was one failure during this test. The rear shaft seal on the choke H.C.R valve was replaced and valve retested. I filled out an AOGCC BOPE Inspection Report which is attached. In summary, I witnessed the successful BOP test at Amoco's Becharof No. 1 Well. Attachment 02-001AfRev. 10179) C-&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O. P. E. InspectiOn Report Date Inspector ~ O~6~ ~O~ Well Operator ~4~9~- ~ , __ Location: Sec lO Drilling contracto~ ~~~ Rig ~ ~ Representative Permit # ~_ ~/~ %asing Set · Representativ~ Location, General Well Sign General Housekeeping Reserve pit Rig 'HOPE Stack Annular Preventer pipe Rams U~f ~ ~ Blind-Rams ~ ./ Choke Line Valves ~'H.C.R. Valve ~ · '~0Kill Line Valves Check Valve Test Pressure .. _ACCUMULA____TOR SYST___~ Full Charge Pressure Pressure After Closure ps ig psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: ~ N2 ~~ ~~ .7_66~9. ~) '~/~ psig min ~ sec min ~seC Controls: Master / Remote ~)~ Blinds switch cove / Kell~ and Floor Safety Valves Upper K~lly } ~Test Pressure Lower Kelly ~-~'Test Pressure Ball Type { ~CTest Pressure Inside BOP ~Test Pressure Choke Manifold ~ ~/Test Pressure I! No. Valves ~ / I NO. flanges ~ 2-~ Adjustable Chokes / Hydrauically operated choke Test Results: Failures Test Time Q~ hrs. Repair or Replacement of failed equipment to be made within Inspector/Commission office notified. Remarks: ~- ~~.+ -~_~ I~ O~ ~ C,~ ~-' ~-~'~J~'_,-~ ~ ~,'~ . days and -_ :1i il) Distribution orig. - AO&GCC' cc - Operator cc - Supervisor Inspector W. G. Smith District Manager December 10, 1984 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 File' DJP-722-WF PERSONAL AND CONFIDENTIAL Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen' Monthly Report of Operations Becharof State Well No. I Attached in duplicate is the State of Alaska Form 10-404, Monthly Report of Drilling and Workover Operations, for the above referenced well, reporting November 1984 activities. Very truly yours, .~ W. G. Smith District Manager Attachment MNM/dds RECEIVED Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA ALASKA O.~-AND GAS CONSERVATION COl%~ilSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well~[ Workover operation [] 2. Name 9f operatoA 7. Per~p~_l~57 Amoco vroduction Company 3. Addre~. 0 BOX 100779, Anchorage, Alaska 99510 8. APl N~3~r20001 · 50-- 9. Unit or I.ease, Name ~ ~ecnaroT 4. Location of Well at surface 500' FNL, 1,000' R48W, S.M. FEL, Section 10, T28S, 5. Elevati~)j~n.f~et (indicate KB, DF, etc.) I 6. LeaAbtesi~a4i¢~nd Serial No. 10. Well No. 1 11,. F. iCd and, Pool V~I / ecat For the Month of. November ,1984 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spud date - 1~1/16/84~. Depth at end of month - 5,890' Footage Drilled - 5,890' 13. Casing or liner ru.n and quantities of cement, results of pressure tests Drove 13 3/8" conductor to 82 feet KB on 11-12-84 Ran 9 5/8" casing set at 1,888 feet KB on 11-21-84 Cemented with 800 sx Class 'G' Had 87% returns. Ran 1" pipe to 105' KB and did top job with 2~ bx Class 'G' to surface. Pressure tested 9 5/8-inch surface casing to 1,500 psi for 30 minutes. -~. Coring resume and brief description Core #1 on 11-26-84 from 2,725' ground sandstone and s iltstone. Core #2 on 11-28-84 from 3,666' shale. - 2,750' - 3,716' - recovered 25 feet of fine - recovered 31 feet of sand 15. Logs run and depth where run None 6. DST data, perforating data, shows of H2S, miscellaneous data None Anchor~!e 17. I hereby certify that t~he foregqing is true and c, orrect to the best of my knowledge. /- SiGNE .~.~~' o TITLE Di stri ct Manager DATE 12/1.3/84 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 Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate W. G. Smith District Manager December 6, 1984 Amoco Production Company Post Office Box 100779 Anchorage, Alaska 99510 907-272-8471 File' TJZ-199-WF PERSONAL AND CONFIDENTIAL Mr. C. V. Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Sundry Notice Deepening Becharof State No. 1 Permit No. 84-157 Attached in triplicate is a State of Alaska Form 10-403, Sundry Notices and Reports on Wells, to confirm the verbal approval received for deepening the subject well. Verbal approval was received on December 4, 1984, from Harold Hedlund of your office to drill to a total depth of 10,000 feet. We are currently logging from 1,888 feet (base of 9 5/8-inch surface casing) to 8,055 feet, and will resume drilling in approximately three days. Any questions concerning this well may be directed to Kevin Smith in our Anchorage office. Very truly yours, W. G. Smith District Manager Attachments KLS/dds RECEIVED O£O i alaska Oil & ~as Cons ,~nC~r;~je' Commission STATE OF ALASKA ALASKA i~)'[L AND GAS CONSERVATION cOOl'MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL J~' COMPLETED WELL [] OTHER [] 2. Name of. Operator Amoco Production Company 3. Address P. 0. Box 100779, Anchorage, Alaska 99510 4. Location of Well 500' FNL, 1,000' 5. Elevation in feet (indicate KB, DF, etc.) 201.7 KB 12. FEL Section 10, T28S, R48W, S.M. 7. Permit No. 84-157 8. APl Number 50- 285-20001 9. Unit or Lease Name Becharof 10. Well Number 11. Field and Pool Wildcat I6. Lease Designation and Serial No. ADL 304952 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans ]~ Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Amoco proposes to drill an additional 2,000 feet to a total depth of 10,000 feet to explore for hydrocarbons and confirm the geologic age of the formations al ready drilled. If 7-inch casing is run, 29# N-80 butt will be run from 0 -~8,000 feet, and 35# S-95 butt will be run from 8,000 - 10,000 feet. Class G cement will be used to cover 500 feet above all hydrocarbon zones. (Verbal approval was received from Harold Hedlund on December 4, 1984) . Subsequent Work Reported on Form No .... -,~ Dated .__/__~.~ -~. OEC N~chora[le 14. I hereby cer~t, ify that t,,~/~oreg~n~ is true and co~r~ect to the best of my knowledge. District Manager Signed ~///~/ .'~(~ J~~~ Title The space below for Commission use Dj~2/06/84 Conditions of Approval, if any: i. -~ ~ --,'' '~;; "-;' Approved by COMMISSIONER ~prov~d B~Order ~t the Commission Date Submit "Intentions" in Triplicate Form 10403 Rev. 7-1-80 r~ and "Subsequent Reports" in Duplicate September 17, 1984 W. G. Smith District Mansger Amoco Production Company P. O. Box 100779 Anchorage, Alaska 99510-0779 Re: Becharof No. 1 Amoco Production Company Permit b~o. 84-157 ~.~w SM. Sur. Loc. 500'F~tL, 1000'FEL, Sec. 10, T28S, .~..~-~ , Btmhole Loc. S A M E Dear Mr. Smith: Enclosed ts the approved application for peri. it to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings, .a minimum of four tablespoons, and a mud log are required. An inclination survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many riverm in Alaska and their drainage systems have been classified as important for the spa~ing or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, am amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office hours prior to commencing installation of the blowout prevention ~fr. U. G. Smith Becharof ~,~o. 1 -2- - September !7, 1984 equipment so that a representative of the Corm~ission may be present to witness testing of the equipment before the ~urface casing shoe is drilled. I'~ere a diverter system is reauired, please also notify this office 24 hours pri~r to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. - Very truly yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION b~ Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department of Environmental Conservation w/o'enc!. W. G. Smith District Manager Amoco Production Company Post office Box 100779 Anchorage, Alaska 99510 907-272-8471 August 24, 1984 TJZ-112-WF PERSONAL AND CONFIDENTIAL Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Application for Permit to Drill Becharof State Well No. 1 ADL 304952 Attached in triplicate is a State of Alaska Form 10-401, application for a Permit to Drill for the subject exploratory well. Becharof State Well No. I is to be an 8,000 foot straight hole located 450' FNL, 1000' FEL, Section 10, T28S, R48W. Attachment A is a general location map. A surveyor's plat of the proposed location is included as Attachment B. In addition, a cementing and BOP program is included as Attachment C. Our company draft #271481, dated August 24, 1984, in the amount of $100 is enclosed to cover the filing fee. As this is an exploratory well, we request that all reports and information filed with the Commission regarding it be kept CONFIDENTIAL. Very truly yours, W. G. Smith District Manager Attachments RECEIVED KLS/dds AUG 2 919l]4 Alaska 0il & Gas Cons. C0mmissJ0n Anchorage STATE OF ALASKA ALASKA .._~- AND GAS CONSERVATION Gen.,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] 2. Name of operator Amoco Production Company 3. Address P.O. Box 100779, Anchorage, Alaska 99510 . 4. Location of well at surface 500' FNL, 1,000' FEL, Section 10, T28S, R48Wj At top of proposed producing interval Same At total depth Same SERVICE [] gTRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] O. Unit or lease narr~¢¢-~, "~-~ ~"~. Becharof %~ ¢ ~ 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. be determined after rig up. I ADL 304952 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Surety - 599481 13. Distance and direction from nearest town 23 miles NE of Pilot Poi'n~d~es 16. Proposed depth (MD & TVD) .. 8,000 19. If deviated (see 20 AAC 25.050) , KICK OFF POINT N/A feet. i 21 SIZE Hole Casing Weight 13.375 54.5 !17 14~ ~ ~D' [~ ce 5/~ ~ tpropertyor, lease line 590'.. sout~ o~ ~moco Lease feet 17. Number of acres in lease feet 2,550 20. Anticipated pressures MAXIMUM HOLE ANGLE 1 Ol(see2OAAC25.035(c) (2) 9.625 40 8.5 7 29 22. Describe proposed program: Proposed Casing, Liner and Cementing Program CASING AND LINER SEYTING DEPTH Grade Coupling l Length M.D ' TOP TVD K-55 . Butt I80 0 I 0 K-55 Butt /1900 0 ,' 0 N-80 Butt 8000 0 I I i 11. Field and pool Wildcat Amount $500,000 15. Distance to nearest drilling or completed we',- Not' Appl icabl e f,et 18. Approximate spud date October 1, 1984 ~¢) . psig@ ~ Surface 3578 ..ps,g@ 8000 ft. TD (TVD) MD BoTToM TVD 80 .'! rS0 1900 -i1900 B000' 18000 I- QUANTITY OF CEMENT (include stage data) 100 sacks Class G 800 sackS Class G Class G to cover 500 feet above all hydrocarbon zones Amoco proposes the drilling of Becharof State Well No i to explore for hydrocarbons. All formations are anticipated to be-normally pressured. However, the casing was- designed using a 12 ppg mud weight as a safety factor. Casing.desiqn factors of 1.125, 1.0 and 1.8 were also used for collapse, burst and tensile Strengths, respectively. For additional information, please r'efer to Attachment A, a general location map; Attachment B, a surveyor's plat of the Proposed location and Attachment C, a Cementing. and BOP program. 23. I hereby certify that the fo.~.-egoin ,,~ true and,,~er'rect to the best of my knowledge SIGNED :~/ .__~//~._ ~J~.~ ~,. ~. ~1 '~- ~ TITLE District Manager The space below for Commission use DAT~;eptember 6, 1! Samples required ~YES []NO Permit number 84- 157..-'"U APPROVED BY _ ~//~~/__ Form 10-401 Mud log required ~YES []NO Approval date CONDITIONS OF APPROVAL Directional Survey required I APl number I-lYES I~NO 50--285_ 20 0 0] SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE Sep~-,-,m~,-,~_~__ _1 '7, ~ ~1 clct/,..~, by Order of the- Commission Submit in triplicate Rev, 7-1-80 Material Requisition Ship to: Amoco Production Company Requisition No. Mr. Address_-,,' , v~,-' Ke~X.O~.; (Enter b~th addresses if m~e of shipment n~t c[~ain.) Date Material Required r-'! ParCel [--I Motor Ship Via: I IPost I I - -~ Freight [,'-']Other ~ ~ ~.-~--i,~/~7 (Specify) Commodity Description of Material For Purchasing Location Use Group No. Show Sizes, Make, Type, etc. Sub. I Terms Price and I Amount Quantity Unit (For parts, show part number and serial number of machine.) No, Trade Discount . . . . . ~uchorago ..... ~hnr~n tn' ~ ~~ ~C;]~ l~ ~ Investment ~ ExPose Total be used for I" . __. h , ~' ~ a j~JOo ~ r'-'] Executive11246 AppliesOrder Location ~~0 ~"~.'. /v]T'$Approved,/2;~/,~ ~~~ ~,/ Date For Purchasing Location Use [ Buyer: Sl~ob..J Order J Write Vendor's Name, Address and Person Contacted Shipping Instructions Confirming F.O.B. Date · Date Order? or Open Promised · . .. Form 2.97 Nov-78 3O T. 27 S. T. 28 S. 6 2O 23 24 SCALE: I"= I MILE CERTIFICATE OF SURVEYOR I hereby certify thor I(]m properly registered (]nd licensed to practice I(]nd surveying in the State of Al(]ska (]nd that this plot represents o Iocotion survey m(]de by me or under my direct supervision (]nd th(]t (]11 details (]re correct. Dole Surveyor NOTE: Coordinates are A.S.P. - S~? 1 o 9 -6-84 REVISED SURFACE WELL LOCAT'~a Oil & Oas Cons. - ,-5-o4 REVISED ~RFACE WELL LOCATION REVISED SURFACE WELL LOCATION ~n~h~_ ~8S~n5-84 BECHAROF STATE No. I LOCATE D IN NE I/4 Sec. I0~ T:>SS.~R.48W.~$.M.~ Aloska AMOCO FOr PRODUCTION COMPANY BY BESSE,EPPS & POTTS ANCHORAGE ~ ALASKA 349-6452 29 C:3 28 <3 _ o- 26 25- - o ~-~° % 3O Attachment A General Location ' Map 10' ~UGA.SHIK C-4J SCALE !.63360 2 3 - 4 MILES _ ]8000 - 21(XX:) FEET 120(X) I/5~:7J0 I I I t I I I I ! I ~ I I I 2 3 4 5KILOMETERS z i i I CONTOUR INTERVAL 50 FEET HED L~NES I~EP~ESENT ~ rOOT CONTOUI~ -.ONAL GEOOET~C vERTiCAL DA[UM GF 1929 ALE BY U.S. GEOLOGICAL SURVEY DENVER. COLORADO 80225. OR RESTON.VIRGINIA 22092 2, GI~.APHIC MAPS AND SYMBOLS IS AVAILABLE ON REQUEST , . QUAEXO~NG LE LOC~TION ROAD CLASSIFICATION unim~o,,~l diA . . .. . _ . _ -. . · _ ... . .. uCASHIK (D-4).' ALASKA: :_ N5745--W15700 15X20 - -: EC'E l:V.E D : . Alaska, 0i!: &' 'GaS Cons. Commission '~.,,.k~,,.~,.4~ - .. . .. · . - . I · ATTACHMENT C CEMENTING AND BOP PROGRAM BECHAROF STATE WELL NO. 1 Cementin9 Program: A· Conductor Pipe - Approximately 80 feet of 13 3/8-inch, 54.5#, K-55 buttress casing will be run. Cement volume estimates are based on gauge hole plus 100% excess. This conductor pipe may be pile driven depending on equipment availability, and therefore cement would not be used. Be Surface Casing - Approximately 1,900 feet of 9 5/8-inch, 40#, K-55 buttress casing will be run. Cement volume estimates are based on gauge hole plus 50% excess. This string will be cemented to surface. Ce Production Casing - Approximately 8,000 feet of 7-inch, 29#, N-80 buttress casing will be run. Class G cement will be run a minimum of 500 feet above all potential hydrocarbon zones. If a large interval exists, a two-stage job and/or light weight bubble cement may be used to avoid a loss of circulation. The bubble cement would consist of Type SSX glass bubbles mixed with Class A cement. II. Blowout Prevention Program' A. Use of the following BOP EquiPment is planned' A 13 5/8-inch 5,000 psi Hydril is to be used as a BOP unit until the 9 5/8-inch casing is set. A 13 5/8-inch 5,000 psi WP, 10,000 psi test single gate BOP with pipe rams, mud cross, 13 5/8-inch 5,000 psi WP, 10,000 psi test double gate BOP with blind and pipe rams, plus 5,000 psi Hydril to be used below the 9 5/8-inch casing point. Attached are drawings of the diverter system and BOP stack design. The Hydril type BOP will be tested to its rated working pressure after initial installation and to at least 50 percent of rated working pressure once each week thereafter. In addition, the Hydril will be actuated against drill collars at least once per week to assure proper functioning. All manifold valves shall be operated weekly and lubricated as necessary. A drill pipe safety valve and inside BOP will be on the floor at all times and will be readily accessible. The rig supervisor will schedule BOP drills to familiarize crews with operation of BOP equipment and with emergency procedures. ~ ~IV~D AUG 2 9 1984. Alaska Oil & Gas Cons. Commission ~13Phnr~n~, ~,..,,oco~ Amoco Production Company ENGINEERING CHART SUBJECT ,~,~1,-/,,~?/'2~.~ ~'7-,,9 7-~ ~ / Sheet No. File Of Appn Date ,, ~'--//~--c~ i t i i /(laSk~ Oil! & ~as ~ons.! CommisSion RECEIVED '-~ Amoco Production Company IAMOCOI ENGINEERING CHART SUBJECT ~".~t-]~- ~t~: ~[ ...... ! .... ~ -- ~ ........ ~ ..... S ~ .... ,, t ~ ~ I , .............. .- ' -~ -~ ~----~ ........... ~ j* ...... ~--- I ......... ~ -I--.---~- : J - I --4 ~--- ~ .......t r- , '-t ---t--~:--~ ' - ; i l ~' i J.--' , ' '- , t- f Sheet No. File Of Date J J i lVaSka 0il & Gas Cons. ~0mm!sslo~ i i i ALASKA f 'L AND GAS CONSERVATION CC' 4MISSION 20 AAC 25.005 la. Type ct work. DRILL RED[tILL DEEPEN lb. Type of well EXPLORATORY J~] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [] MULTIPLE ZONE [] 2. Name el operator Amoco Production Company 3. Address P.0, Box 100779, Anchorage, Alaska 4. Location of well at surface 450' FNL, 1,000' FEL, Section 10, T282, R48W At IOP of proposed producing interval Same At total depth Same 99510 5. Elevation in feet (indicate KB, DF etc.) to be determined after rig uo. 6. Lease designation and serial no. ADL 3O4952 t9. Unit or lease name Becharof 10. Well number 11. Field and pool Wildcat AmountS500,000 23 miles NE of Pilot P'oi~bs 450' soutE-of-Amoco Lease feet well Not Applicable feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8000 feet 2560 October 1, 1984 J 20. Anticipated pressures j~/~-- · 7,~-0 _ psig@ 0 Surface MAXIMUM HOLE ANGLE 1 °I (see 20 AAC 25.035 (c)(2)~;Z~/~3578 .sig@ 8000 ft. TD(TVD) 21 "!""!" ' Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole 1 Casing Weight Grade I Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) 17.5 i13.375 54.5 K-55 JButt 80 0 I 0 80 ~. 80 100 sacks Class G 40 K-55 IButt 1900 0 ~l 0 1900 'l 1900 800 Sacks Class G 8 5 17 29 N-80 JButt 8000 0 ' 0 8000 I 8000 Class G to cover · ' I ~ I 500 feet above all ' I ~ i hydrocarbon zones 22. Describe proposed program: Amoco proposes the drilling of. Becharof State Well No. I to explore .for hydrocarbons. All formations are anticipated to be normally pressured. However, the casing was designed using a 12 ppg mud weight as a safety factor. Casing design factors of 1.125, 1.0 and 1.8 were also used for collapse, burst and tensile strengths, resn. ectively. For additional information, please refer to Attachment A, a general location map; Attachment B, a surveyor's plat of the proposed location and Attachment C, a cementing and BOP program. R E'C E IV E D 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or numberSurety - 599481 19. If deviated (see 20 AAC 25.050) KICK OFF POINT N/A feet. 12.25 i9.625 AUG 2 9 1984 23. I hereby cer~=i;,,'i-AT~-(-ii~-e' [orego,ng is true and correct to the best of my knowledge Alaska 0ii & Gas Cons. Commission SIGNED ~¢. ~ ..~~ TITLE District Manager OATE~Uqust 24, 196 Samples required Mud log required ~i~Y E S _-:NO ~'YES (_~' N O ---P~r-r~i'? ~u'm~ie-r ............ -Approval date __- CONDITIONS OF APPROVAL Directional Survey required - " ' '~ I APl number .r-lYES :~.[~10 ; ; '~ 50--~-~-~' ~Lo~ ~ i SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER by order of the Commission DATE Form 10~101 Rev. 7-1-80 Submit in triplicate W. G. Smith District Manager Amoco Production Company Post Office Box 10077g Anchorage, Alaska 99510 907-272-8471 September 6, 1984 TJZ-118-WF PERSONAL AND CONFIDENTIAL Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Si r: Revised Surface Location Becharof State Well No. 1 ADL 304952 Amoco Production Company wishes to amend the surface location on the Permit to Drill submitted to your office by our letter dated August 24, 1984, File: TJZ-112-WF. Attached in triplicate is a revised Permit to Drill, Form 10-401, for the subject well. Per telephone conversation on September 5, 1984, between John Levorsen of your office and Kevin Smith of our office, we are changing the surface location to 500' FNL, 1000' FEL, Section 10, T28S, R48W in accordance with Sec.55 of the State of Alaska oil and gas regulations. Also attached is a new surveyor's plat of the proposed location. Very truly yours, W. G. Smith District Manager Attachments KLS/dds RECEIVED ~/asXa 0il & Gas Cons. Cornrnissior~ Anchorage CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. IT EM APPROVE DATE (2) Loc ~~g__ $--'{~.~'J thru S) (3) Adm'n(k~ ~ 2_~t.~.i~ (~ thru 11) (10 and 11) ( 4 ) C a s g :~/~ ~-/~ .~? (12 thru 20) (5> (21 thru 24) (6) Add: 1. Is the permit fee attached ........................................ 2. Is well to be-located in a defined pool ........................... 3. Is well located proper distance from property line ...... !.~.!..i ! i 4. Is well located proper distance from other wells .......... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is well bore plat included ... 7. Is operator the only affected party ..................... 8. Can permit be approved before ten-day wait,. ............. 9, 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. YES NO Does operator have a bond in force ................................ Is a conservation order needed ..... Is administrative approval needed ......... Is conductor string provided .................. Is enough cement used to circulate on go~dugto~ an~ ~u~ce ....... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ........ Will surface casing protect fresh water zones .... ' iiiiii'aii iiii Will ali casing give adequate safety in collapse, t t.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed . ................... Is a diverter system required ................................ H~/~ Are necessary diagrams of divertar and'BOP equipmen; ~ac~e~ ... '~//.. Does BOPE have sufficient pressure rating - Test to +~-~ psmg ..~ Does the choke manifold comply w/AP1 RP-53 (Feb. 78) .................. Additional requirements ............................................. Geology: Engin~e~n~: WVA JKT i~HJH ~ JAL MTM ~ ., rev: 12/08/83 6. CKLT INITIAL dE0. ' UNIT ON/OFF POOL :CLASS STATUS AREA NO. SHORE , ,, CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) ~ee_ (2) (3) Admin k~ (~ thru 11) (10 and 11) (4) Casg (I2 thru 20) (21 thru 2/-,,) e 10. 11. YES NO 1. Is the permit fee attached ......................................... ~z/~-._ 2. Is well to be-located in a defined pool . ~.,., ~_.. 3. Is well located proper distance from property line .................. /~. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool . 6. Is well to be deviated and is well bore plat included .. 7. Is operator the only affected party .................... 8. Can permit be approved before ten-day wait ............. Does operator have a bond in force .................................. Is a conservation order needed ................ Is administrative approval needed . 12. 13. 14. 15. 16. 17. 18. 19. 20. REMARKS 21. 22. 23. 24. I.s conductor string provided ................................... ~ Is enough cement used to circulate o; ~du;tor and surface ~n. _ Will cement tie in surface and intermediate or production strings ... ~z~_~ Will cement cover all known productive horizons ..................... ~ Will surface casing protect fresh water zones ... ' ............. ~ Will all casing give adequate safety in collapse, t;nsl;; ;n~ burst~._. IS'this well to be kicked off from an existing wellbore ............. ~ ,, . Is .old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed .............. ............ Is a diverter system required ....................................... Are, necessary diagrams of diverter and BOP equipment attached ..... ~ , Does BOPE have sufficient pressure rating - Test to 05/~ p;ig Does the choke manifold comply w/API RP-53 (Feb.78) ................... .WP ?- .gU/g,,"'/' / 7-7"£~0 25. Additional requirements ............................................. Additional Remarks:/}$ ~_~-zr'o p_r I t9'iV L) p..s ! t~,o-_vE' ro ~, /v Geology: HWK LCS WVA JKT JAL ~MTM rev: 12/08/83 6. CKLT Engineering BEW HaH INITIAL GEO. UNIT ON/OFF . POOL CLASS STATUS' AREA NO. SHORE ....... c,'%r 0¢ y- _---.. u,u ,, Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO SEll~ PARTIAL LISTING COMMENTS ** ************************************ NOTE: ** COMMENTS ** THIS DATA IS A MERGED PRODUCT OF RUNS ONE, TWO, AND THREE. ALL TOOLS HAVE ** COMMENTS BEEN DEPTH CORRECTED TO THE DUAL INDUCTION TOOL. COMMENTS COMMENTS COMMENTS COMMENTS SCHLUMBERGER COMMENTS ALASKA COMPUTING CENTER ** COMMENTS COMPANY = AMOCO PRODUCTION COMPANY ** COMMENTS WELL = BECHAROF STATE ** COMMENTS ** FIELD = WILDCAT ** COMMENTS COUNTY : BRISTOL BAY ** COMMENTS ** STATE = ALASKA COMMENTS ** COMMENTS ** JOB NUMBER AT ACC: 7~328 ** COMMENTS e. RUN ~ONE, DA'FE LOGGED: 19 NV 84 COMMENTS LDP: RICK KRUWELL COMMENTS ** L.I.S. TAPE VERIFICATION ** 5-AUG-85 14:29 PAGE: 1 ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8fllf PARTIAL LISTING ** L,I.S. TAPE VERIFICATION ** 5-AUG-85 l&:2g PAGE: 2 ** COMMENTS CASING : 13.375" ~ 82' - BIT SIZE : 12.25" TO 82' *~ COHMENTS ~* TYPE FLUID : LSND ** COMMENTS ** DENSITY = 9.~ LB/G RM : 1~.9 ~ 74 DF ** COMMENTS ** VISCOSITY : 45 S RMF : 7.2 @ 74 DF ,w COMMENTS *~ PFI : 9.~ RMC = 5.3 @ 74 DF ~* COMMENTS FLUID LOSS : 14.4 C3 RM AT BHT = ll.4G ~ 7~ D:F ~ COMMENTS ** MATRIX SANDSTONE COMMENTS ******************************************************************************** COMMENTS ** COMMENTS COMMENTS w, * SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: COMMENTS COMMENTS w* w D'UAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) COMMENTS DATA AVAILABLE: 73.5' TO 19~'8,5' COMMENTS ~ w BOREHOLE COMPENSATED LOG (BHC) COMMENTS DATA AVAILABLE: 73.5' TO 19~8.5' ~ COMMENTS ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3GG9 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11~ PARTIAL LISTING ** L.I.S. TAPE VERIFICATION ** 5-AUG-85 14:29 PAGE: 3 w* COMMENTS ** ** COMMENTS COMMENTS SCHLUMBERGER COMMENTS ALASKA COMPUTING CENTER COMMENTS ** COMMENTS COMPANY = AMOCO PRODUCTION COMPANY ** COMMENTS WELL = BECHAROF STATE ** COMMENTS FIELD : WILDCAT ** COMMENTS COUNTY = BRISTOL BAY '** COMMENTS ** STATE = ALASKA COMMENTS ** COMMENTS ** JOB NUMBER AT ACC: 7~359 ** COMMENTS ,w RUN #2, DATE LOGGED: 7 DEC 84 COMMENTS ** LD.P: RICK KRUWELL COMMENTS ** COMMENTS CASING = 9.625" 8 1888' - BIT SIZE : 8.5" TO 1888' ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11~ PARTIAL LISTING ** COMMENTS TYPE FLUID : LOW SOLIDS NON DISPERSED w, COMMENTS DENSITY : 9.5 LB/G RM : 2.1 @ 65 DF ** COMMENTS ** VISCOSITY = 44 S RMF = 3.9 @ 65 DF ** COMMENTS PH : 9.5 RMC : 2.8 @ 67 DF ** COMMENTS ** FLUID LOSS : 8.8 C3 RM AT BHT = .826 ~ 176 DF ** COMMENTS ** MATRIX SANDSTONE ** COMMENTS COMMENTS COMMENTS ****************************** COMMENTS COMMENTS ** * SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: COMMENTS **~COMMENTS * DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) COMMENTS DATA AVAI:LABLE: 187~.5' TO 8~62.~' COMMENTS ** * LONG SPACED SONIC LOG (LSS) COMMENTS DATA AVAILABLE: 187~.5' TO 8~62.~' * COMMENTS ** * LITHO DENSITY COMPENSATED LOG (LDT) ** COMMENTS ** * COMPENSATED NEUTRON LOG (LDT) COMMENTS ** L.I.S. TAPE VERIFICATION 5-AUG-85 I4:29 PAGE: ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11~ PARTIAL LISTING DATA AVAILABLE: 187Z.5' TO 8f62.Z' * COMMENTS ,w * NATURAL GAMMA TOOL (NGT) COMMENTS DATA AVAILABLE: 187~.5' TO 8~62.~' * COMMENTS COMMENTS COMMENTS *~ COMMENTS ************************************************************************************ COMMENTS SCHLUMBERGER * COMMENTS ALASKA COMPUTING CENTER COMMENTS ************************************************************************************** ** COMMENTS COMPANY = AMOCO PRODUCTION COMPANY ** COMMENTS WELL = BECHAROF STATE ** COMMENTS ** FIELD = WILDCAT ** COMMENTS COUNTY BRISTOL BAY ** COMMENTS ** STATE = ALASKA COMMENTS ** COMMENTS '~* JOB NUMBER AT ACC: 7f329 ** COMMENTS RUN #3, DATE LOGGED': 1~ DEC 84 ** L.I.S. TAPE VERIFICATION ** 5-AUG-85 14:29 PAGE: 5 ENERGY SYSTENS TECHNOLOGY, INC. AMOCO DENVER 3GG9 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11~ PARTIAL LISTING ** L.I.S. TAPE VERIFICATION ** 5-AUG-85 14:29 PAGE: G COMMENTS ** LDP: RICK KRUWELL COMMENTS ** COMMENTS ** CASING ** COMMENTS TYPE FLUID : 9.625" @ 189I' - BIT SIZE = 8.5" TO 1891' : LOW SOLIDS NON DISPERSED ** COMMENTS DENSITY = 9.4 LB/G RM ** COMMENTS VISCOSITY : 43 S RMF ** COMMENTS ~* PH : 9.6 RMC ** COMMENTS ** FLUID LOSS = 7.6 C3 ** COMMENTS ** MATRIX SANDSTONE : 3.68 @ 61 DF : 3.42¢ @ 61 DF : 3.45~ @ 61 DF RM AT BHT = 1.238 @ 195 DF COMMENTS ******************************************************************************* COMMENTS COMMENTS COMMENTS COMMENTS ,COMMENTS COMMENTS ****************************** COMMENTS COMMENTS ,w * SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11~ PARTIAL LISTING COMMENTS ** COMMENTS * DUAL INDUCTION SPHERICALLY FOCUSED LOG (DIL) COMMENTS ** DATA AVAILABLE: 7787.5' TO 9~23.5' * COMMENTS w* * LONG SPACED SONIC LOG (LSS) COMMENTS DATA AVAILABLE: 7787.5' TO 9~23.5' * COMMENTS ** * LITHO DENSITY COMPENSATED LOG (LDT) COMMENTS '~ COMPENSATED NEUTRON LOG (LDT) COMMENTS DATA AVAILABLE: 7783.5' TO 9~r26.~' * COMMENTS * NATURAL GAMMA TOOL (NGT> COMMENTS DATA AVAILABLE: 7783.5' TO 9~26.~' w COMMENTS COMMENTS COMMENTS COMMENTS ** L.I.S. TAPE VERIFICATION ** 5-AUG-85 14:29 PAGE: 7 ~* DATUM SPECIFICATION BLOCK NUMBER 1 DIRECTION LOGGED : LIP FRAM'E SPACING : 6~.~ .lIN MNEM ID UNIT PROCESS DEPTH FT SFLU DIL OHMM ILD DIL OHMM ENERGY SYSTEMS TECHNOLOGY, INC. AMOCO DENVER 3669 S. HURON ST. SUITE 2~2 ENGLEWOOD, CO 8~11B PARTIAL LISTING ILM DIL OHMM SP DIL MV GR DIL GAPI DT BHC US/F GR BHC GAPI CALI BFIC IN SGR LDT GAPI CGR LDT GAPI CALI LDT IN RHOB LDT G/C3 DRHO LDT G/C2 NRAT LDT RNRA LDT NPHI LDT PU PEF LDT NCNL LDT CPS FCNL LDT CPS SGR NGT GAPI CGR NGT GAPI POTA NGT PU POTA VOL PU THOR NGT PPM URAN NGT PPM GR LSS GAPI DT LSS US/F DTL LSS US/F CALI LSS IN DEPTHS FOR DATUM SPECIFICATION BLOCK 1 STARTING DEPTH : 9~26.~ ENDING DEPTH : 73.5~ ** L.I.S. TAPE VERIFICATION 5-AUG-85 14:29 PAGE: ..'<- 0(- -.'~::..?;- -::(..)(. ::~(- .Z~Z. -.':(- -.'<- ¥, .:<. ¥: .'.<- -:: ~': -.'!'..~...':.::..Z<..'.<. % ..'<- .:.-'(. -.'<...'~(. -.':.--.'..X. 9::. 'X- -.'~(..::i;...'<. 0i.'. -.'<- i",! (Z[! ']" iii[ ', ..'~.,': ..'i,..'. .:, :. ..'~!:. .:,:. ..': :. ..'<. ..'l z. ..' (- -.'~z. -:(...' (- .>:- -:,:..:~::..:.-':. -'.:¢: .z~:...'!:..:~(- .: :. -: z-.:::-.:~:..;,:..z:~:...' 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