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Home My WebLink About190-140T39892 PLUGG!N & LOCATION CLEA ~CE REPORT State cf Alaska 0iL & GAS CONSERVATION CCHHISS!ON -:er--' i::a_--raia - tops: .~eview the well file, and,' cerumen: on piuqgi:g, well head` sUaU-as, ~d !ccaUicn ~!~ar~e- :r:vi~. l°c. clear. ~.~ /~o~ ~; M ~ ~.~.~. - ' ~ , Well heac~ can off: .~'(.~ .. ALAS OIL AND GAS CONSERVATION COMM ~iON WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well O" [~ Gas O Suspended O Abandoned r~l service O 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 90-140 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-22096 4. Location of well at surface :~ ......... '"--~-"' 9. Unit or Lease Name 535' FNL, 1048' FWL, SEC.14, T12N, R14E, UM ~1 ,~.,>~,,~.:~,~:~... ' Point Mclntyre Unit At Top Producing Interval!'~ ...:, ~,~ '.~,~., 10. Well Number 2077' FNL, 3964' FWL, SEC. 02, T12N, R14E, UM P2-59 At Total Depth 11. Field and Pool 1690' FNL, 1061' FEL, SEC. 02, T12N, R14E, UM Point Mclntyre Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 41.5 feetI ADL 365548 Point Mclntyre Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions November 5, 1990 December 16, 1990 December 27, 1998 (P&A'd) I N/A feet USE 1 ! 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 14375' MD / 9577' TVD 13642' MD / 9007' TVD YES r~ No [~I 2096' MD. feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/GR/AMS, LDT/CNL/NGT/AMS/GMT, RFT, DLL/SONIC/GR/AMS 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 20" 133# K-55 Surface 114' 26" 180 cubic ft Coldset II 13-3/8" 68# NT80CYH E Surface 2990' 17-1/2" 2402 cubic it Coldset II 9-5/8" 47# NT80S Surface 13409' 12-1/4" 2850 cubic ft Class G 7" 29# L-80 13112' 13113' - 14348 8-1/2" 562 cubic ft Class G 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) 4-1/2" 13148' 13057' 4-1/2" 13848' * Plugged & Abandoned all open perforation intervals. 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED (See P&A Summary) 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A Plugged & Abandoned Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I N/A Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) Press. 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of o11, gas or water. Submit core chips. * This 10-407 is submitted as directed per the 10-403 form approved October 10, 1998 (Approv~i~#~i.'.9~2~ii') ! Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit In duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverecl and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ugnu / West Sak 7230' 5118' Colville Mudstone 10642' 7074' H RZ 13466' 8866' N/A Kalubik Ck 13621' 8991' Kuparuk River 13642' 9008' Milne Pt. MBR 14150' 9407' 31. LIST OF ATTACHMENTS Summary of P2-59 Pre Coil Tubing Sidetrack Plug & Abandonment Operations. 32. I hereby certify that the following is true and correct to the best of my knowledge. Signed (~~ ~1 ~',,, Title AAI Coil Tub n.q Drilllnq Supervisor Date ' ;;ute B Prepared by Paul Rauf 263-4990. 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 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 cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 PRE COILED TUBING SIDETRACK PLUG & ABANDOMENT SUMMARY Date Event Summary 12/2611998: RU ELU. RIH & set Mechanical Whipstock @ 13643' MD. POOH & RD. 12/27/1998: A CTU Cement Plug was pumped to Plug & Abandon the lower wellbore prior to ST operations as follows: MIRU CTU & PT'd BOPE. RIH w/CT & killed well w/Slickwater. Tagged top of Whipstock @ 13643' MD. Pumped 8 bbls of 17 ppg Class G Cement to abandon the open perforation intervals located @: 13646'- 13686' MD (Zones UC4,UC3,UC2,UC1) Ref Log: DIFL/SFL/GR 12/17/1990 Bullheaded 5 bbl of Cement below the Mechanical Whipstock. Attained a max sqz press of 1500 psi for 30 min. Contaminated cement w/Biozan & jetted contaminated Cement f/the wellbore to the Whipstock tray @ 13642' MD. POOH w/CT. FP well & left 500 psi on wellhead. RD. Continued w/P2-59A Sidetracking Operations. ARCO (ALASKA) Survey No. 27614 P2-59 ~'o - IH o POINT MCINTYRE, AK Performed by: KINLEY December 10, 1998 Caliper Specialists Since 1953 5815 Royalton, Houston, Texas 770EI1-29Et3 U.S.A. Phone (71 3) 664-4501 Telefax (71 3) 664-1 037 SERVICE AVAILABLE WORLOWIOE WITH ALL KINLEY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power Jars · Measuring Line Cutters 'NLEY SURVEY INTERPRET - ON COMMON ABBREVIATIONS L.U. = Lower Upset Corr. = Corrosion U.U. -- Upper Upset Dep. - Deposits u.B. - upper Body Scatd. - Scattered m.B. = middle Body Shall. - Shallow I.B. - lower Body TABULATION SHEET JOINTS are numbered from the top down. Numbering starts with the first full length joint below the well head. PUP JOINTS are designated by decimal numbers. For example, Joint #32.1 represents the first pup Joint below Joint #32. SPECIAL TOOLS & NIPPLES GAS LIFT are designated by letters. For example, "B" is the second special tool or nipple from the top of the well. MANDRELS are numbered down from the top. For example: GLM(1), GLM(2), etc. TABULATION SYMBOLS We use a circle as the basic tabulation symbol. The Kinley Caliper records the simultaneous action of all fifteen or thirty feelers. Our survey, therefore, has either 15 or 30 recordings. These lines provide a view around the circumference of the inner surface of the pipe. A complete circle on the tabulation sheet indicates that at least 14 of 15 feelers or 28 of 30 feelers found tubing wall reductions at the same depth on the well. This would be described as a ring. The number of feelers that indicate tubing wall reductions at the same depth is also noted on the tabulation sheet. For a 15 Feeler Caliper ~ 3to5 ~'~ 6to9 ~ 10to13 ~ 14to15 For a 30 Feeler Caliper [~ 6toll ~ 12to19 D 20to27 ~ 28to30 A' PIT RING A PARTIAL RING NO COMMENT MEASUREMENT SYMBOLS A number alone represents the depth of penetration expressed in hundredths of an inch of the deepest pit. In this example 0.08". A groove around the pipe found by 14 of 15 feelers or 28 of 30 feelers. The number inside the circle represents the maximum depth of the ring expressed in hundredths of an inch. A groove around the pipe found by 3 to 13 of 15 feelers or 6 to 27 of 30 feelers. The number inside the partial circle represents the maximum depth of the ring expressed in hundredths of an inch. Indicates no damage was found in that joint. Arco Alaska, Inc. Point Mclntyre, AK P2-59 December 10, 1998 Survey No. 27614 Chart No. 2588 Feeler Ratio 2: 1 APl: 50-029-22096-00 This is the first survey of this well to be made with the Kinley Megadata Caliper. The condition of the internal surface of the 7" 29~ Buttress liner in the well, from approximately 13,148' to 13,685' 0NLM), is covered in this report. The deepest penetrations recorded in this survey measure 0.08" or 19% of the liner wall thickness and are recorded in twelve of the fifteen joints surveyed. As there are no penetrations recorded in excess of 20% of the liner wall thickness, the usual cross-sectional drawing and Pit Depth Rank Chart are not included in this report. The condition of the liner surveyed and analyzed appears good with respect to corrosive damage. However, indications of minor damage are recorded in all of the joints in the forms of shallow corrosion, lines of shallow corrosion, lines of shallow pits, scattered shallow pits, and isolated pits. CALIPER TECHNICIAN Kenneth Bulloch rls Distribution: SURVEY ANALYST Randall L. Smith ARCO (ALASKA) INC., ATTENTION: Central Files, ATO 370, P.O. Box 100360, Anchorage, AK 99510-0360 (1R) ARCO (ALASKA) INC., ATTENTION: Ms. Laura S. Lahrson, GMPA Files & Drill Site Engineer, ATO 492, P.O. Box 100360, Anchorage, AK 99510-0360 (1 R) ARCO (ALASKA) INC., ATTENTION: Ms. Lori Taylor, AOGCC, P.O. Box 100360, Anchorage, AK 99510-0360 (1R) B.P. EXPLORATION (ALASKA), INC., ATTENTION: Ms. Sharmaine Copland, Petrotechnical Data Center, MB 3-3, P.O. Box 196612, Anchorage, AK 99519-6612 (1R) Chart received: 12-12-98 Report faxed: 12-12-98 Report mailed: 12-14-98 KINLE Y CALIPER TALL Y SHEET (Composite) :C' Copyright KinlO. Corporation 1995 P2-59 P©INT MCINTYRE, AK Survey # 27614 December 10, 1998 Run: 1 Section: 1/1 Chart #: 2588 Pipe: 7" 29.# BUTTRESS Feeler Ratio: 2:1 Body (In.): 0.408 Upset (In.): 0.408 Penetrations Over 85%(Possible Hole) # of Jts Penetrations 41 - 85% (Poor) Penetrations 21 - 40% (Fair) Penetrations 11 - 20% (Good) 14 Penetrations 1 - 10% (Very Good) No Penetrations Recorded TOTAL JOINTS SURVEYED: 15 KINLE Y CORROSION PR OFILE ~) Copyr~,,ht KhtlO, Corporatio:t 1998 P2-59 POINT MCINTYRE, AK Survey # 27614 December 10, 1998 Run: 1 Chart #: 2588 Feeler Ratio: 2:1 Section: 1/1 Pipe: 7" 29.# BUTTRESS Body (In.): 0.408 Upset (In.): 0.408 BODY PENETRATIONS CORROSIVE DAMA GE FREQUENCY DIS TRIB UTIONS MAXIMUM PENETRATION NUMBER OF JOINTS Cb Cb Cb ~ ~" ~, ~, ~ ~'- ~ % WAL& LOSS CONFIGURA TfON :~:.%,:~ ~:~::.:.'::,'::.4::::i! ::~:~:..~:.~:~::, ~.~:.,..:: .,.,..,: ,~: ,~,~,,: ~:?~::~ ~.,~ ~..'.~..'~:.~. '~'~:'~"%~¥*~::""8:""~:'~: ,,..,, ..... ~, .,",..,.,., ,v,. ,..,. ,',v,., NUMBER OF dOINTS 0 0 0 o o o o o ~ ,~. .=.. ~ DESCRIPTION MARKER JOINT EOS IN JT. #'I4 @ 13,685' (WLM) % WALL LOSS 20 40 60 80 ~00 KINLE Y CALIPER JOINT TAB ULA TION SHEET Copyright Kinley Corporation 1998 P2-59 Run: 1 Section: POINT MCINTYRE, AK Chart #: 2588 Pipe: Survey # 27614 Feeler Ratio: 2:1 Body (In.): December 10, 1998 Upset (In.): 1/1 7" 29.# BUTTRESS 0.408 0.408 MAXIMUM MAXIMUM UPSET/MAKEUP BODY NO % IINCHES % INCHES COMMENTS ;i::ii:i;!:'!?! BODY ---UPSET 0.1 t 12 0.05 IShallow corr. 1 t 19 0.08 Shallow corr.; 1st full-length Jt. below Tub ng Tail 2 ' 19 I 0.08 Shallow corr. 3 19 0.08 Lines of shallow corr. 4 ! 19 0.08 [Lines of shallow pits 5 19 0.08 Shallow pits u.B. 6 I 9 0.04 Scatd. shallow pits 7 14 0.06 Scatd. shallow pits 8 J 19 0.08 Shallow corr. 9 I 19 0.08 IShallowcorr. , 10 / 19 0.08 IShallow corr. u.B.; Line of shallow corr. (0.06') 11 / 19 0.08 JLine of shallow corr. 12 19 0.08 /Shallow corr.; Marker Jt. 13 , 19 0.08 /Shallow corr. 14 19 0.08 IShallow corr.; Perforated interval' Survey ends in Jt. #14 @ 13,685' (WLM) DAMAGE o PROFILE j (% WALL} .... ::.::.: :: Arco (Alaska) 7" 29# Buttress P2-59 Point Uclntyre, AK { Kinley Survey No. 27614 Chart No. 2588 mi -- i · I .. ., · ?. SHALLOW CORROSION JOINT 0.1 ....... : -- _ ~ i ~ i ! ~ - - _ i_, 1111 i ~ i ·-- -- L ...... ' '_ -- -- :~ il ' .... ._ 't ~_ ~- J, ~ . : ---- ! [~_ - , _ _il Il -- I I -- I J Ill ~ I -- -- · , SHALLOW CORROSION 1ST FULL-LENGTH JOINT BELOW TUBING TAIL JOINT ~ JOINT f * ~ Arco (Alaska) P2-59 7" 29# Buttress i Point Mclntyre, AK ( Kinley Survey No. 27614 Chart No. 2588 ii · I I -- _ · . . . . .' . .................................. . .. .. . ]11 ! _ J~ ii ii i i i ! i i___111 - i i i .................................. LINE OF SHALLOW CORROSION ..... SHALLOW CORRO'SION SHALILO'W CORRO~ON JOINT 11 MARKER JOINT JOINT 13 '- ~ JOINT 12 ~ ~ ~ STATE OF ALASKA ALASKa" 'L AND GAS CONSERVATION COMMI~ N APPLIC,-, ~'ION FOR SUNDRY APPRO%,.,LS · Type of Request: Abandon --Z- Suspended __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well __ Plugging X Time extension __ Stimulate __ Change approved program _ Pull tubing __ Vadance _ Perforate _ Other_ 2. Name of Operator ARCO Alaska, Inc. 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKBE -- 41.5' 7. Unit or Property name Point Mclntyre 8. Well number P2-59 9. Permit number 90-140 10. APl number 500292209600 11. Field/Pool Point Mclntyre feet 3. Address P.O. Box 100360, Anchorage, AK 99510 ¢. Location of well at surface 535' FNL, 1048' FWL, Sec. 14, T12N, R14E At top of production interval 2077 FNL, 3964' FWL, Sec. 02, T12N, R14E At effective depth 1691' FNL, 4218' FWL, Sec. 02, T12N, R14E At total depth 1690' FNL, 1061' FEL, Sec. 02, T12N, R14E Plugs (measured) Junk(measured) None. FISH -2.5' on top of filI/PKR CCTU Fishing neck / washout nozzle Measured depth True vertical depth 114' 114' 2990' 2680 12. Present well condition summary Total Depth: measured: 14375 feet true vertical: 9577 feet Effective Depth: measured: 13678 feet true vertical: 9037 feet Casing Length Size Cemented Conductor 114' 20" 180 ft3 Coldset II Surface 2990' 13-3/8" 2402 ft3 Coldset II 134O9' 882o 13113-14348 8588-9555 Intermediate ~q si ,, 13409' v- ,8 2850 f¢ Class G Liner 1235' 7" 562 f¢ Class G RECEIVED SEP ,..SO 1998 Alaska 0il & Gas Cons. C0mmissior Anchorage Perforation depth: measured 9010-9053'13646'13686'true vertical' Ot [S/iVA L Tubing (size, grade, and measured depth) 4V" , ,4 1/" ' '2 12.6# LB0 @ 13148" _- '2 12.6# LB0 @ 13833-13848' Packers and SSSV (type and measured depth) 4-1/2" x 9-5/8" Otis Pkr @ 13057'MD; WRSV SSSV profile at 2096' MD i3. Attachments Description summary of proposal __x Detailed operation program _ BOP sketch _ 5. Status of well classification as: Oil X~ Gas Suspended 14. Estimated date for commencing operation Oct, 1998 16. If proposal was verbally approved Name of approver Date approved 17. I hereby certify that the foregoing i~ true and correct to the best of my knowledge. Signed Stephen Ward ~d:~~'~ ~5 &"~'i~tl'e Sr. Engineer I-OH COMMISSION USb ONLY Date September 30, 1998 Service Date JApprova, Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP test Location clearance Mechanical Integrity Test_ -- Subsequent for requi~ed1.(}r t./-O 7 uriginat ,b~gn~,d ~y 0avid W. Johnston Approved by order of the Commission Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE FROM: QRCO ~LRSKR FA× NO.: 9072634894 I1-I~5-97 0~:08P P.07 STATE Of ALASKA j ALASKA-[.~. AND GAS CONSERVATION CO *,~SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Stat'us of Well ................... Classification' of Service Well ~ Oil ~ Gas [] Suspended ~] Abandoned ~ Service ~- i~lame of Operat~'~ ....... 7~ "P~'~;mit Number ..... '"' ' ...... ARCO Ala. ska Inc. .., 90-140 3. Address .... 8. APl I~'umber '-- P.O. Box 100360, Anchorage, Alaska 99510 50-029-22096 ,,, 4. Locatior~ of well at surface..... ~'~..?,i'.. ":~' ~ 9, Unit or [ease Name 535' FNL, 1048' FWL, SEC. 14, T12N, R14E ~ "" Point Mclntyre At top of productive interval i '~'~3, Well Number 2077' FNL. 3364' FWL, SEC. 2, T1 .?,N, R14E i V~i['}6~ ~ P2-59 At total d~p~h ~.~.__-~----~,~ ;' ~"1. Field and Pool' 1691' FNL, 4218' FWL, SECV. 2, TI,?.N FI14E .............. 5-~-Eievation in feet'iindicate KB, DF, '~te.) 16, Least'Designation and ~erial No, . ..... Point Mclntyre KBE = 40.45'I ADL 365548 12, Date SPudded" 113, Date T.D. Reached I 14. D~te Comp,. Susp., or"Aband.llS. Water depth, ii"offshore 1'~6. N~','of ComPletions /s 90 ! I e/ /97 j N/A ~SLt One j17. Total Depth (MD+TVD) j18. PlUg BaCk DePth (MD,TVD)J19. D'Jrectional ,~urvey ~0, Depth Where SSSV set J21. T~icknes~i"-of Permafrost 14375 ,9577 FTJ 14268 9496 F,J ~Yes I']No J .............. 2095'MD J ,650"(Approx.) 22. Type Electric o~ Other Logs Run .............. ' DIUG....R/A. MS, LDTICNL/NGT/AMS/GMT, R.FI~.,;,,,DLL/Sonic/GR/AMR 23. . .......... . .............. ~^SlN(~, LINER ANI~"~'~'ENT~NG RECORD ............................................................ CASING S ET¥i'~ DEPTH HOLE ............... ' ............. ' SIZE _. WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20' 133# K,55 SurfaCe 114' 26. 180 cuff Coldset II .......... 13-0'~8'~"- ' 68# ~'¥~YHE Surface"' 2990' 17-1/2" !J~'40:~"~:u ft Coldset II....... · .................. 9-5/8';' ...... . 47'~ NTB0S Surface 13409" 1'~-1/4" 2850 cuft C'J~ss "G"' 7" 29# L-80 13112' 1434~' 8-1/2" 582 cuft CI-ass "G" ,, 24, Perforations open to Productio'~ (MD+TVD of Top and" ~5, ' ..... TUBING REOOI~D Bottom and interval, size and number) SIZE'" ' ,w~, DEPTH SET (MD) PACKER SET (MD) 6-3/8" Gun Diameter 6spf 4-1/2"L-80 ..... 13148' .... 13058' MD TVD MD TVD .................. 13646-13686' 9011 '-9042, ...... 261 AOID~ FI~ACTURE, CEMENT SQUEEZE, ETCi ........... DEPTH INTERVAL (MD) AMOUNT & KIND O1= MATERIAL U$~,D _~._7_,._ PRODUCTION T;~';=T ....... Date First Production J Method of Operation (Flowing, ga~'iitt, etc,) ......... 8/5/97 J Gas Lift ~ale of Test HOurs Te'.~ted PRODUCTION For~" OIL-RIal GAS-M~F WATER-~BL CHOICE ,SIZEmGAS-OIL RATIO ...... TEST PERIOD Flora'Tubing Oas:ino Pressure CALCULATE~' ........ OILJ~aL GAsLMcF "'~/VAT6R-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. '"~O~-R~' DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water. Submit core chips. ' .......... RE£EIVED NOV Form 10-407 Rev. 07-01-80 Submit In Duplicate FROH,: ARCO ALASKA FAX NO.: 9072634894 11 - 17-97 08: 25Ai P. 02 ,..~ Marker Name Measured True Include interval tested, pressure data, all fluids .... Depth Vertical recovered and gravity, GOR, and time of each phase. UgnuANest S~, 7230' "" i~l~l* ............. Colville Mudstone 10642' 7074' HRZ 13468' 8866' Kalubik 13621: 8991' Kuparu k 13642' 9008' 3t. List of Affael~ment$ .......................... TELEX of work completed 32. I hereby ~'~rtify that/tll'e_~fore~'oing is true and correct to the be~i of my ~nowledge ..... ' Signed Title ....~ ,"'.~..e.v"~/~, ,"/--~' Date ' lA -'7"/~ ,~- ..... ,,, .... ,,,,, ...... , ........... P2;-$9 90-140 Prepared By Name/Number: W~II Numl~er Permil No. J Approval No.,, 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. I'r~ 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply /or inje~ion, 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 e~nd in any attachments, ITEM 16/~,O 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 ~how 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 cementing and the location of the cementing tool. ITEM 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, SI3ut-ln, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 RECEIVEI) 17 l gl' Alaska 011 & Sas Con~. Commt~iot~ Anchorage 4 2 C0:[LED TUBINg UNIT BOP EOM ! PI,tENT 1. 500C) PSI '7" WELLHEAD CC~INECTOR FLANOE 2. 5000 PSI 4, 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/IS" SHEAR RAMS 5~. 5000 PSI 4 1/IS" BLIND RAMS 6. 5000 PSI 4 1/1 IS" STUFFING BOX 2 N]REL ]NE BOP EOUIPHENT 1. 5DDO PSI 7" WELLHEad) CONNECIOR FLANGE ,i 2. 5ODD PSI WlRELINE RAMS (VARIABLE SIZE) ~ 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OrE P2-59 Intended P&A Procedure Objective: P&A existing interval in preparation for CT sidetracking operations. Intended Procedure RU slickline unit, tag bottom and run a Kinley caliper log in the 7" casing. RU e-line unit, run and set top of whipstock in 7" casing at - 13610'. RU CT. Pump 30 bbls Class 'G', 17 ppg cement. Clean cement top to ~-13620' md (KOP for CTU drilling at 13615') WOC, Tag top of whipstock. September 29, 1998 FROM,: 11-15-97 05:08P P.09 RRCO ;~LRSK~ FR× NO.: 9872654894 { P2-59 Event History Well Date i Comment P2-59 02/16/97 -. P2-59 02/17/97 P2-59 03/23/97 ..... .. P2-,59 P2-59 P2-59 ... P2-59 P2-59 P2-59 P2-59 P2,59 P2-59 .... P2-59 ., P2-59 P2-59 P2-59 P2-59 P2-59 P2-59 P2-59 P2-59 P2-69 P2-59 P2-59 P2 P2-$9 P2-S9 P2-59 P2-59 I PUL,L_P._L...U. GS, RUN LIB. i RUN LIB AND STATIC, 'CTU COMPLETED' FCO, ' ............ 0~.2.,7/97 ._.RA__N. L.i_~B~'A.-N[~-~',~iLER (.FULL FF PROPPANT) 04/08/97 CTU RIGGED UP FOR FCO. JOB SHUTDOWN DUE T~'wIN~)-'DIRECTION AND GAS ~ .__. VENTING. ..0.~!'.0../._9..7. ,,CTU COMPLETED REVERS[?ouT"(~'FRAC SA~I'~, ' ......... .... 9_4./..!.9.1_9.7.. iAT~'E'~?TT'-~-$PEAR IBP, UNSUCE$SF~t~_- .............. 04/20/97 'SL TAG AT 13829 04/21/9;~ .... -~[~-,~G W/LIB AT 13829 CORRECTED ............... 05~1 .... ;~iT IA TO 2000 PSI, GOOD, " ..................... ~11/97 i CE~'~:-~'~QUEEZE. ' ......................... .0...5/. ! .,4f/. 9..7 A'FI'EMPT TO PRESSURE '~EST SQUEEZED PERFS 05/15/97 . SL DRIFT A.N..[._T.~G_,.!__R.E FRAC ................... "~)'~i1..6. !.9.7 ..i~'~K DETECTION LOG AND ATT~'['~'~'~"PERFORATE," GUN~"MtSFIRED 06!..2.6_!97 ,CT....U__S. pOT~"~AI~D--~'[~'UG. ES~-T~-I~"~,'~"'i'~6g2 CTM.' ................ 06/27/97 .'...S.._L...T..AGED SD PLUG TOP AT 13687 SEM, DUMI~"'~Aco~ CAP-IN PROGRESS, 06/2~/9.7. .......... ; .S..L C_ .OM P LETED"~'~,~i=-R~'(~' WO R Ki ..................... ...0.6./3.0..!9_7' .......... FRAC .S...C..R__E.E..N.".E.'~._~_'ii'f'W-'T~' P.p.A...AT PERFS, 31~]'~ LBS.IN F?.R..~, 2gM LBS IN TBG. 07/01/97 'CTU CLEANED OUTFRAC SAND. 07/02/97 COMPLETED TAG AT 13675 Fl: '1~.' 07/06/97 BROUGHT WELL ON TO TANK. WOULD NOT ~['~W. " 0.7./.!.,5.!9..7. ........ _S....L.A'FrEMPTED TO RUN GLVS-~"~-(~-E-~'~i'~D'RATES AT ~71~'0 'FT,' ..... 07/18/97 , CTU REMOV'~i~-i-(~-i~ PLUGS'"~'"i"~'~,~' & 2150'. RIH TO ~50~;"['A~'i"'"(~EAR simp = 1050 PSIG' , @ 2150 HRS. FRZ PROm, ~',~/'9~ ...... i~3LV INSTAL~¥i~'N I~'PRO'GRESS ................... 0.7!2.!/97 !HO.T...O.[.L....J..O. B:...O....N...L..y2 BBLS A.W.'~'~?..A.~'-i~.ii~ AT 900 FT " 07/23/97 .CTU JE'I-rED PLUG. 07/24/97 ....~'[~/c/~"i'~"P ROG R ES,~'; ....................................... 07/2...5./.9..7 ..... .c_O_M. pLETED GL,V......C_!._O..:, PT,..H_ARDLINE FOR GAS...L!Fi- ~,~O FLOWLINE, 08/05/97 =BOL AT 1;]45 HR, 08/05/97 JOG 0'~/'(~'~)97 :SI A'NI~"~;iE'WI;I;~'-(~'~, ' ............ ! 0/0.)'?.,~',.,' 'i',i' i,DRIFT AN, ,D_.T.A_..G. ,A, T.'~i 4-7~.~ii .......... P2-59 , 10/02/97 P2-59 = P2-59 P2-59 P2-59 10/06/97 P2-,.c,9 P2-59 .... P2-59 P2-~9 ' ' ~ , P2-$9 P2-$9 'FCO TO 13700 CTMD ......... 10/0.3,./...9...7. ....... ._.D.U...¥,.M,..Y.,.G....L.VS, INCOMPLETE, PRE-FRAC 10/,.0.4/.9.,7 ,CONTINU.E_D._U.,.MMY GLVS-PRE FRAC 10/05/97 ;CIRC IA, SET DGLV, MIT IA,'TAG & RUN'I~'R~c' ~'LEE~E' TAG AND RUN FRAC SLEEVE lO(.!..5_/?.7,,,, i ~)~_~i~i~'.ET Ei~'i~,'~"~: R EAT M ENT,' ........... 10/16/97 COMPLETED CTU FCO FOLLOWING FRAC. 10/19/97 GLV C/O IN PROGRESS, 10/21/97 10/29/97 .G,L,V,..C....o.. ,C.0MPLE.,,T.,.E.i_.B_O.L,,,,AT 2217 . .J..E....T....H....Y...DRATE$, FILL CLEAN OUT-IN PROGRESS. COMPLETED FCO, ATTEMi~:i:i~D-~(~"§(~I'''. ~i/~'~J"~iP. Page 1 of 1 11112/97 FROMm: ARCO ALASKA Well: P2-59 Spud Data; 1110§/90 Original RKBE: 41.5' Top of Formation: 13642' Annular Fluid: DIESEL TO 3500', 9.6 BRINE Reference Log: DIFL/SFL/GR NOTE: FAX NO. : 9072634894 11-13-97 03:09P Alaska, Inc, - GPMA WELL SCHEMATICS A PI#: 500292209600 ~[. Type: PRODUCER Completion: 12/27/90 Workover; Status: ACTIVE Hanger Type: Hanger: 34' Max Hole Angle: 60° MD:6100' Angle O TF: 37~ Angle @ TD: 41° Date: 12/17/90 Tie In: Date: P.10 Jewelry (J) MD Description 1 2096' 2 13032' 3 13057' 4 13115' 5 13136' 6 13148' 7 8 9 13831' 10 13833' 11 13841' 12 13845' 15 13848' CAT I- SSSV II H2S (ppm) 4-1/2' OTIS SVLN, ID=3.813" - WlO WR SSSV, Frac sleeve installed 10/6/97 4-1/2" SWS NIPPLE 4-1/2" X 9-5/8" PACKER, OTIS, ID=3.850" 4-1/2" SWS NIPPLE, ID=3.813' 4-1/2" SWS NIPPLE, ID=3.813"" 4-1/2" PARKER WLEG (13150' ELM) FISH - 2,5' ON TOP OF FILL/PKR (CTU FISHING NECK / WASHOUT NO;ZZLE) FILL/FISH @ 13829' SL CORR, SAND AND CARBOLITE BAKER INFLATABLE BRIDGE PLUG (FISHING NECK) est. top ?' OTIS WD PACKER (WD PACKER SLIPPED APPROX, 22' DOWN THE HOLE. NEW LOCATION SHOWN)~ 4-1/2' 'X' NIPPLE, ID=3.813" 4-1/2~ 'XN' NIPPLE, ID=3.725" 4-1/2" OTIS WLEG Min ID: 3.813" OTIS SSS¥ NIPPLE @ 2096' MD Oesc MD TVD Sin GLM 3533' (3004) 1 GLM 7516' (5294) 2 GLM 10094' (6750) 3 GI.M 11217' (7404) 4 GLM 12302' (8039) 5 GLM 12990' (8503) 6 Casing and Tubing (C) Size Weight Grade Top 1 13 3/8" 73# L-80 0' 2 9 5/8" 47# L-BO 0' 3 7" 29# L-80 13113' 4 1/2" t2t6# L-80 0' 4 1/2" 12.6# L-80 1383;~' Mandrel Information (I,G,M) Mandrel CA, MMG CA-MMG CA-MMG CA-MMG CA-MMG CA-MMG Perforation Data (ELM Depths) (P} Interval Zone FT 1 1,3646' - 13686' Kuparuk 40' I 13640' - 137§9' 12;3' 2 13784' - 13810' 26' 3 13840' - 13860' 20' Datum 8600' SS: 13183' ~ PBTD= 14268' 8800' SS = 13435' r vD TD=-14375' r VD Bottom Description 2990' CASING 13409' CASING 14348' LINER 13148' TUBING 13848' TUBING ODValve Type Latch 1.5" CA PD RK 1.5" CA F~ RK 1,5" CA RD RK 1.5" CA RD RK 1.5" CA RD RK 1.5" CA FO RK Port TRO SPF Date Comments 4 05/19/97 Reperfed Date 10/O.~/g7 10/05/97 10/06/97 Squeezed & partially circ'd out, 5/11/97 Squeeze cemented, 5/11/97 Squeeze cemented, 5/11/97 Tag= 13678'1VD Type: SLMD-CORRECTED Date: 10/06/97 Revision Date: 10/06/97 Revision NO: 9 FROM: ARCO ALASKA' FAX NO.: ARCO Alllkl, II~ Pod OIiOB BQK 1~ A~dlamgl, AJImkm Oo610.~ 9872654894 11-15-97 0~:06P P.81 GREATER POINT M¢INTYRE AREA DAT~: ~.o ~ CC_ RECEIVED F?~OV t:. ]997' ,A/aska Oil & ~as Cons, Commissio~ ,~nChorage FRO~: RRCO ALASKA' FAX NO.: 90?2654894 11-15-97 ,,' STATE OF ALASKA { ALASI~ .~IL AND GAS CONSERVATION COMMISSIC,,N APPLICATION FOR SUNDRY APPROVALS O5:O7P P .02 ~ Type of Request: Abandon Alter casing _ Suspen0ed Repair well Change approved, progra, m .-- Pull tubin,~ . Variance ._~ 2. Name of Operator 15."' Type of Well; ARCO Alaska, Inc. I Development _X_ J Exploratory 3. Address J Stratigraphic P.O. Box 100360, Anchorage, AK 99510 J Service Operation Shutdown ~ Re-enter suspended well,x_ .... Plugging ~ Time extension BtJmulate ,P, erforate 3, Datum elevation (DF Or KB) RKBE -- 41.5' 7. Unit or Property Dame Point Mclntyre feet 4. Location of well at surface 535' FNL, 1048' FWL, Sec. 14, T12N, R14E At top of production interval 2077 FNL, 3964' FWL, Sec. 02, T12N, R14E At effective depth At total depth 1691' FNL, 4218' FWL, Sec. 02, T12N, R14E ., 2. Present well condition summary Total Depth: measured; B. Well number P2-59 g. Permlt number 90-140 10. APl number 500292209600 11, Field/Pool Point Mclntyre true vertical: 14360 feet 9565 feet Plugs (measured) None. Effective Depth: Casing Conductor Surface measured: true vertical: Length Size 114' 20" 2990' 1 14268 feet Junk (measured) None. 9495 feet Cemented Measured depth 180 ft3 Coldset II 114' 2402 fi3 Coldset II 2990' True vertical deDIh 114' '2680 Intermediate 13409' 9-sis'' 2850 ft3 Class G 13409' 882O Liner 1235' 7" 562 f¢ Class G 13113-14348 8588-9555 Perforation depth: measured 13646-13769', 13784-13810', 13840-13860' true vertical 9010-9109', 9121-9141', 9165-9181' Tubing (size, grade, and measured depth) ORIGINAL 4-~/~'' 12,6# LB0 @ 13148' Packers and 8SSV (type and mea3ured depth) 4-1/2" X 9-5/8" Otis Pkr @ 13057'MD; TRSV SSSV profile at 2096' MD REC ' V'ED Alaska Oi~ & Gas Cons,, Commissio,~ A, nchor'ag(; 13. Attachments Description summary of proposal ._..X Please refer to the attached · , 14. Estimated date for commencing operationFebruary 14, 1997 Detailed operation program 15. Status of wail classification as; Oil X___ Gas BOP sketch 16. If proposal was verbally approved Name of apl)rover Date approved 17. I hereby certify that the foregoing is true cna correct to 1he best Of my knowledge. Signed Lowell Crane Title Sr. GPMA Engineer Suspended Service Date October 3, 1997' FOR .~:~MMISSION USE ONLY Conditions of approval: Notify Commission so representer'lye may witneSS" Plug integrity __ BOP test ~ Location clearance __ ApDroved Dy order g~_tBe Comml,sion~,- -'o --~0.,a.Vid W. J0hnst0~ Commi,sioner Form 10-403 Rev 06/15/86 Approved Copy Returned SUBMIT IN TRIPLICATE FROM': ARCO ALASKA' FAX NO.: 9072634894 11-13-97 Addendum to Form 10-403: Application for Sundry Approvals Summary of proposed well work for P2-59 Before any work was done, the well had XX plugs at 2076' & 13 ! 34' SLM- see figure 1. · Pull pxnplugs · Run Static Bottomhole Pressure Survey Clean out fill to top of fish Use CTU to push fis~ and inflatable bridge plug to the mp of the 4, V~" ~ubing at 13833' MD · Cement off all upper perforations, leave cmt plug · Reperforate 13646-13686' MD after completion of injection tests on squeezed perfs - see figure 2. · Dump sand for hydraulic frac- sand top 5' below perfs (approx. 13691' MD) · Run hydraulic frac FCO- see figure 3, Tcst frac performance Refrac if necessary Figure 3 shows current well configuration. 03:07P P Alaska {)ii & C~a~x {;ohs. ~3om'missio~ .Anchora-fle FROM': ARCO ALASKA' P2-59 50-029-22096 C-1 G-1 FAX N0.: 9072634894 1 1-15-97 03:0?P Figure 1: Original Weli Configuration P .04 well status: Fro~ucer, Workover required to raize wellhead Surface Location: 535' FNL, 1048' ~WL. Sec 14, T12N, Ri~E Original RKBE: 41.5 Feet RKB to Tubing Han~e,': 3a Feet Top of Kuparuk: 13642' MD Reference Log: $W$ DIFL/SFL/GK - 12-17-90 Annulus Fluids: Diesel to kQ~ 9.6 Brine below. SDud Date: 11-6-90 Co~91etiun Date: 12-27-90 Upper wellbore fluids are crude, water J-2 J~3 J~LaY (J) 1. 2096' MD- 2, 4. 5. 7. J-4 11. 13841 12. 13845 J-5 1~. 13~4.R C-2 ~ J-6 _~ CASI'N~SIzEAND TUBINGwT(C) 1. 13 3/8" 72~ 3, 7" 4 1/2" 12,6~ 4 1/2" 12,6~ J-12 J-13 OTIS SSSV LANDING NIPPLE, 3,813' ID, W/ XX PLUG 13032' MD - 4-1/2" SWS NIPPLg 13057' MD - 4-1/2" X 9-5/8" PACKER, OTIS, 3,850" ZD 13115' ~D - 4-1/2" SWS NIPPLE, 3.813" ID, w/XX PLUG 13136' MD - 4-1/2" SWS NIPPLE, 3-813 ID 13149' MD ~ ~ 1/2" _PAEKEE~LE~G 2.5' FISH ON TOP OF FILL (CTU FISHTNG NECK/WAShOUT MOZZLE) FILL @1__~?_50' MD SAND AND CARBOLITE 13771' MD - MAKEK INFLATABL~ BRIDGE PLUG (FISHING NECK) 13833' MD - 7" OTIS WD PACKE~(WD PACKER SLIP~ED APPROX 22' DQWNHOI,E. NEW LOCATION SHOWN.) ' MD - 4-1/2' 'X' NIFFLE OTIS, 3,813" ID ' MD - 4-1/2" ~ZN' NIPPLE OTIS, B,725" ID 3.813" ID SSSV NIPPLE AT 2096* GRADE TOP BOTTOM DESC. 5-80 SURFACE 2990 CASING L-80 SURFACE 13409 CASING 5~80 13113 14348 I,INER L-80 0 13148 TUSING L-~0 13833 138d8 TUBING GAS LIFT ~RS5 ~NFO (G) DEPTH TVD SIZE/TYPE 3533 (300~) 1 1/2" C~.{CO TDS 7515 {5294} 1 1/2" CAMCO TDS 10094 (~751) ~ 1;Z" CAMCO 'i'DS 11217 (7404) 1 1/2" CAMCO TD$ 12302 (9039) 1 1/2" CAMCO TDS 12995 (850~) I 1/2" CAMCO TDS PERPORAT~ON DA~ (~LM D~PTHS) (P) INTERVAL ZONE FT SPF SIZE 13646 -13769 123 6 3 13784 -13810 26 6 3 3/8' 13840 -13860 20 6 3 3/8" 14262 MD - PBTD 14268 MD -TD VALVE/LATCH DUMMY / RK DUMMY / RK DUMMY / RK DUMMY / RK DUMMY / RK DUMMY / RK PHASE D^TE GO 6O MAX HOLE ANGLE ~9-4~ AT 6900' MD HOLE ANGLE THROUGH KUPARUK = 36~ Lower wellbore fluids are seawater, mud FR.O~ DR¢O DLDSKD~ API # 50-029-22096 J-1 G-1 FRX NO.: 9072634894 11-13-97 03:07P · Figure 2: Well after%=qz & reDerf pre sand du~np &frac w~ll SLaLus: workover required to raise wellheact Surface Location: 535' FNL, 1048' FWI,, Sec 14, T12N, RI~E Original KKBE: 41,5 Feet RRB to Tubin~ Han~er: 34 Feet Top of Kuparuk: 13642' MD Reference Log: SWS DIFL/$FL/GR · 12-17-90 Annulus Fluids: Diesel to 2~ 9.6 Brine below, ~pu~ Date: 11-6-90 ComDletion Date: 12-27~90 Upper wellbore fluids are crude, water P .05 J-2 J-3 J-4 J-6 P-1 J-~ J-9 J-10 J-il P-3 J-12 J-13 O~T;~LRY (J) 1. 2096 MD - OTIS SSSV LANDING NIDPLB, 3.813" {I} 2, 13032 MD -. 4 1/2" ~W~ NIPPLE 3, 13057 MD - ~-1/2' X 9-5/8" PACKER, OTIS, 3,850" 1D 4, 13115 ~D - ~-1/2" SWS NIPPLE, ~,~13" ~D 5. 13136 MD - 4-1/2" SWS NIPPLE, 3-813 ID 6, 13148 MD ~ ~ 1/2" PARKER WLEG 7. 2.5' FISH ON TOP OF FTLT, (CTT! DT~HING NECK/WA~OUT NOZZLE} 8, FILL @ 13829' MD SAND, CARBOLI'rE 9. 13~2' MD - BAKER INFLATABLE BRIDGE PLUG (FISMING NECK) 10, 13833' MD ~ 7" OTIS WD PACKER (WD PACKER SLIPPED APPROX 22' DOWNHOLE, NEW LOCATION SHOWN.) 11. 13841' MD - 4-1/2' 'X' NIPPLE OTIS, 3~813" ID 12. 13845' MD - 4-1/2" 'Xl~' N~PPLE OTIS, 3.725" ID 13. 13848' MD - 4-112" OtTS W LEG MINiMT3~ ID~ 3.813" ~D SSSV NIPPLE AT 3096' MD CAEING AND TUBING (C) SIZE WT GRADE TOP BOTTC) M DESC, 1, 13 3/8" 72~ L-80 SURFACE 2990 CASING 7i, 9 .g / 8" ~75 L-~0 SUR?ACE 13409 CASING 3 . 7" 29~ L-80 13113 14348 LINER 4 1/2" 12.6~ L-80 0 13148 TUB IN~; 4 1/2" 12.6~ L-80 13833 13~4~ TUBING LIFT MANDREL INFO DEPT~ TVD SIZE/TYPE VALVE/LATCH 3S33 (3004) 1 1/2" CAMCO TD$ DUMMY /RK 7516 (5294) 1 1/2" CAMCO TDS DUMMY / RK 11217 (7404) 1 ~12" CAMCO TD$ DUMMY ,t RK 12302 (8039) 1 1/~" CAMCO TDS DUMMY / RK 12995 (8504) 1 1/2" CAMCO TDS DUMMY / RK PBRFORATION DATA (ELM DEPTNS) INTERVAL ZON~ FT SPF SIZE PHASE DATE 13646 -13686 40 6 3 3/8" 60 R~PER? 13686 -13769 83 6 3 3/9" 60 SQUEEZED 13784 -13810 26 6 3 3/8" 6~ SQUEEZED 13840 -13860 20 6 3 3/8" 60 SQUEEZED 142~2 MD - ~TD ~a268 MD - TD MAX HOLE ANGLE 59,4~ AT 6000' MD ~OLM ANGLE THROUGH KUPARUK = 36" Lower wellbore fluids are seawater, mud FR4]M~: ARCO ALASKA' P2-59 A]~I # 50-029-22096 FAX HO.: 9072654894 11-15-97 05:08P ,( Figure 3: Current ~chematic, Post Frac & FCO W~11 Stat~s: workover req~ire~ to raise wellhead Surface Location: 535' PNL, 1048' FWL. Sec 14, T12N. Original RKBE: ~1,5 Feet RKB to Tubinc Hanger: 34 Feet Top of KuDaruk: 136~2' MD Reference Log: SWS DIFL/SFL/~R - 12-17-90 Annulus Fluids: Diesel to 2000' 9.6 Brine below. SDud Date: Compl=tion Date: 12-27-90 P .06 Upper wellbore fluids are crude, water J-2 J-3 J-4 J-5 C-2 J-6 P-1 J~8 P-2 J~ J-10 J-11 J-12 J-13 diEW~ LRY (J) 2096 ' MD 130~2' MD 13057' MD 13115 ' MD 13136' MD 13148' MD - OTIS S$SV LANDING NIPPLE, 3.813" ID - ~-1/2" sw$ NIPPLE - 4-i/2" X 9-5/8" PACKER, OTIS, 3.850" - ~-1/2" SWS NIPPLE, 3,~13" ID - ~1/2" $W$ NIPPLE, 3.813 ID - 4 1/2" PARKER WLEG 7 ~,%' FTSM ON TOP OF FILL (CTU FISMING NECE/WASMOUT NOZZLE) 8 PILL ~ 13678' MD SAND, CARBOLITE, AND CEMENT 9 13832' MD - BAKER INFLATAEDE BRIDGE PLUG IFISHING NECK~ 10, 13833' MD ~ 7" OTIS WD ~ACKER (WD PACKER SLIPPED APPROX 22' DOWNHOLE. NEW LOCATION SHOWN.) 11. 13841' MD - 4-1/2" 'M' NIPPLE OTIS, 3.813" ID 12. 13845' MD - 4-1/2" 'MN' NIPPLE OTIS, 3.725" ID MINI~g3M ID: 3.813" ID SSSV NIPPLE AT 2095' MD CA~IN~ AND TUBIN9 (C) SIZE WT GRADE TOP BOTTOM DESC. 1. 13 3/8" ?2# L-80 SURFACE 2990 CASING 2. g S/~" ~7~ L-SO SURFACE 13409 CASING 3. ?" 29# L~80 1311~ 14348 LINER 4 1/2" 12.6# b-80 0 13148 TUBING 4 1/2" 12,6~ L-80 13833 13848 TUBING 8AS SIFT MANDR~L INFO (G) DEPTH TVD SIZE/TYPE VALVE/LATCH 3533 (3004) 1 !/2'~ CAMCO TLS DUMMY / RK 7516 (5294) 1 ~/~" CAMCO TDS DUM~Y / RK 10094 (6751) 1 1/2" CA~CO TLS DUMMY / RK 112~7 (7404) 1 1/2" CAMCO TDS DUM~Y / RK ~302 (8039) 1 1/2" CAMCO TD$ DUMMY / RK 12995 (8504) 1 1/2" CAMCO TDS DUMMY / RK ~R~ORATZON DATA (EL~ DEPTHS) INTERVAL ZONE FT 13646 -13686 40 13686 -13769 83 6 13784 -13810 26 6 13840 '-13860 20 6 SIZE PHASE DATE 3 3/8" 60 *~ARTIALLY COVERED 3 3/8" 60 SQUEEZED 3 3{8" 60 ~QUEEZED 3 3/8" 60 SQUEEZED 14262 MD - PDTD 14268 MD - TD MAX HOLE ANGL$ 59.4~ AT 6000' MD HOLE ANGLE THROUGH KUPARUK = 36" I mud,I --------'----'-~~ Lower wellbore fluids are seawater, BP EXPLORATION Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Chairman Johnston, BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 October 6th, 1997 Pursuant to the Point Mclntyre Agreement Regarding Interim Funding, Final Equity Determination, and Facility Sharing dated 4/28/92, please transfer the name of Operator of the following wells from BP Exploration (Alaska) Inc. to ARCO Alaska, Inc.: Well Permit # P2-59 (Formerly Point Mclntyre #9) P2-58 (Formerly Point Mclntyre #6) P2-60 (Formerly Point Mclntyre #13) 90-0140 90-0008 91-0091 Yours Sincerely, / Robert W. Janes ( Manager, Greater )int Mclntyre Area cc. Joe Leone (ARCo Alaska, Inc.) Jim Branch (Exxon Co. USA) RECE!V:[D " ....... 1997 Alast~a .0il & ~,ao Cons, ARCO Alaska, Inc. Posl Office Bo~, ~.90360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 March 31, 1995 Mr. David W. Johnston Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Johnston, Re: Suspended Well Update ARCO Alaska Inc. ("ARCO") has compiled data pertaining to the 25 suspended wells described in your August 19, 1994, letter. Any additional suspended wells which were discovered during our research are also included in this update. I have attached an update on each well and grouped the wells by geographic area. If you have any questions, please call the ARCO Contact indicated for each geographical area or me at 265-6914. Sincerely, ~ James R. ' egarner, CPL · , ......... Sen~or Landman'" //" JRW:hb ,,' Enclosures ,, CC: M. L. Bill L. D. BroWn H. R. Engel R. M. Lance T. W. McKay G. K. Phillips M. J. Reisterer ATO 1528 LAO 466 ATO 1918 ATO 1420 ATO 1202 ATO 496 ATO 1439 RECEIVED APR 1 4 1995 Alaska 0il & Gas Cons. Commission Anch0ra,",, ARCO Alaska, Inc. Is a Subsidiary of Atlantic Richfield Company RECEIVED Greater Pt. Mclntyre Area (ARCO Contact: George Phillips 263-4280) APR 1 4 1995 Oil & Gas Cons. Commission Anchora. ARCO hereby requests extensions of "suspended" status for the following wells. Additionally, an exception to the surface plug requirement of AOGCC 20AAC25.110(c) is requested. All of these wells are located in safe and accessible locations on producing drill sites that are monitored daily. The individual status of each well is detailed below. West Beach State #3, APl # 50-029-20208-00, Permit # 76-0034-0 This well was Certified Capable of Producing in Paying Quantities on February 1, 1979. The well was with suspended with a cement plug. An abandonment cap has been installed and tested. This well has the potential for use as a gas injection well to support the West Beach #4 well either by re-entering and/or sidetracking. 'Pt. Mclntyre P2-59 (PM-9), APl # 50-029-22096-00, Permit #90'0140-0 ~ This well has not been tied into the facilities. It tested at a rate of 1208 BOPD from the Kuparuk formation. It was suspended with tubing and packer and with a plug in the tubing. The SSSV is Closed and a back pressure valve is set. To produce this well will require a workover. This well is being evaluated as a producer. More data from offset Pt. Mclntyre wells is being used to determine the economics. Pt. Mclntyre P2-50A, APl # 50-029-22261-00, Permit # 92-0065-0 This well is being evaluated as a sidetrack to a new Pt. Mclntyre development location. The following wells have changed their status since you requested your update: Pt. Mclntyre P1-03 (PM-4), APl # 50-029-21912-00, Permit # 89-0013-0 This well was Certified Capable of Producing in Paying Quantities on February 13, 1989. This well is now a producer. Pt. Mclntyre P1-25 (PM-5), APl # 50-029-21937-00, Permit # 89-0041-0 This well was worked over in August of 1994 and converted to a water injection well. ARCO hereby requests extensions of "suspended" status for the following wells. Gull Island State #1, APl # 50-029-20151-00, Permit # 74-0057-0 This well was Certified Capable of Producing in Paying Quantities on February 1, 1977. Gull Island State #2, APl # 50-029-20195-00, Permit # 76-0013-0 This well was Certified Capable of Producing in Paying Quantities on April 26, 1977. The following wells have changed their status since you requested your update: Pt. Mclntyre P1-03 (PM-4), APl # 50-029-21912-00, Permit # 89-0013-0 This well was Certified Capable of Producing in Paying Quantities on February 13, 1989. This well is now a producer. Pt. Mclntyre P3-01 (PM-5), APl # 50-029-21937-00, Permit # 89-0041-0 This well was worked over in August of 1994 and converted to a water injection well. Pt. Mclntyre P2-50A, APl # 50-029-22261-00, Permit # 92-0065-0 This well was suspended with a waiver for a bridge plug at 200' & 300'. This well is being evaluated as a sidetrack to a new Pt: Mclntyre development location. BP EXPLORATION To: David W. Johnston Chairman Alaska Oil & Gas Commission From: Steve Herren, Drlg Mgr Shared Services Drilling ARCO Alaska, Inc. --- Date: 09/307~:4~L'-~§'~ 7~ Subject: Suspended wells Compliance with re.gtJlati0n$ In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan REEEIVED ' OCT 1 4 1994 Alaska 0il & Gas Cons. Commission ,4.nchor~e Suspended Wells, Request to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-,¢'04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13) in this area. MPB-02; 029-20662-00 81-/¢/142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-~001 Future utility as a Schrader Bluff producer with producing utility when sudace infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0013 N-01 B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-0110 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may possess utility in either production or injection operations. DNR recently certified this well as capable of production. No Point #1; 029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 welll Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80~0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island #1,289-20018-00 81-0119 Alaska Island #1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk #lA, 029-20156-01 76-OO28 Niakuk #lA was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk #2A, 029-20180-01 76-0079 Niakuk #2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit #1,223-20006-00 70-0060 Kemik Unit #1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site inspection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-01 40 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta #3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-0066 MP 33-11-12, 029-20504-00 8O-OO92 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11 - 12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 o Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission, will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as ~uspended, as~r.r~qui..r.e.d~y 20 AAC 25.110(e), must have well site znspections ~is ye~~.~,~-t9 snow covering the locations. ~~~~~inc~l"; ............ , ................... ...... " David W...Johnston ~ ' ' ........... Chairman ',,,~ Attachments c: Blair Wondzell bew/llbp~usp 8/15/94 BP SUSPENDED WELLS SINCE 1980 AUGUST 1994 PAGE PERMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRUDHOE BaY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 1 DEU SUSP PRUDHOE BaY UNIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BaY I/NIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 i DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND 1 EXP SUSP MILNE POINT UI~IT B-02 DEV SUSP MILNE POINT UNIT a-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT UNIT C-16 DEV SUSP PRUDHOE BaY UNIT X-22A DEV SUSP PT MCINTYP~E P2-59 EXP SUSP PRUDHOE BaY UNIT S-10A DEV SUSP NORTHWEST MILNE i EXP SUSP PRUDHOE BaY UNIT U-01 DEV SUSP PRUDHOE BaY UNIT Z-32A DEV SUSP NO POINT i DEV SUSP STATUS DATE 4/15/80 10/11/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 1/18/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/18/85 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 O7 27 36 O5 30 30 11 19 23 3O 25 25 10 33 14 35 25 18 19 O6 TWP 13N 11N llN llN 12N 12N 10N llN llN 10N 13N 13N 13N 12N 12N 111q 12N 12N 14N 11N llN RNG 010E 012E 012E 012E 016E 01SE 013E 013E 013E 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U U U U U U U U U U U U U U U U 8/15/94 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 PAGE PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 ~;]ELL WELL W~ELL NA/~E CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BAY LrNIT 33-12-13 D~V SUSP KEMIK I/NIT i DEV SUSP PRUDHOE BaY I/NIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-a EXP SUSP NIAKUK 2-a EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-a EXP SUSP PRUDHOE BaY LTNIT TERM C BEV SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 O4 26 26 35 35 10 O3 T%qP 11N 12N 01N 11N llN 12N 12N 12N 12N llN llN 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E MER U U U U U U U U U U U DOCUMENT STORAGE, INC. "State-of-the-Art A.rcl, iving" "$tate-of-the-Art Archivin$ " 2410 East 88th Avenue tn Trautwein And~orage, Alaska 99507 ~ Store Manager Tel (907) 522-26M Fax (907) 522-2686 FROM: PLORATION ALASKA INC. -, AMPLE TRANSMITTAL BP Exploration Alaska, Inc. c/o Document Storage Corn Store 2410 W. 88th Ave. Anchorage,.Alaska 99507 Attn: John Trautwein (907) 522-2684 TO: AIRBILL #i CHARGE: · 'D ~'-'t,~'T DATE: TRANSMITTAL NO.: WELL NAME: P F' /nc. SAMPLE TYPE: ~iP, P NUMBER OF BOXES: REFERENCE: ,~T-/W-.ff- c.w,e~ c , DESCRIPTION OF MATERIALS TRANSPORTED: . Please acknowledge receipt in whole of the material described above by signing this transmittal and returning a copy to the address shown above. Date: Date: RECEIVED Alaska Oil & Gas Cons. Commission Anchorage RR,lCl C;.r~lcwin ~I',','('I e A nr'h,','n,,e. A lnsl. m 00507 DOCUMENT STORAGE, INC. "State-of-the-Are Archivin$" i'PLORATION ALASKA INC. · ~o~8~^-~, [AMPLE TRANSMITTAL · ohn Trautweln Anchorage, Alask~ 99507 , ' ~ore Stor~ Manager Tel [907) 522.2684 Fnx (907) 522-2686' ' ' · . FROM: BP Exploration Alaska, Inc. c/o Document Storage Core Store 2410 W. 88th Ave. Anchorage,Alaska 99507 Attn: John Trautwein (907) 522-2684 TO: "State-of-tile-Art A .rchiving " AIRBILL #!. CHARGE: ' 'D e ~t VeXeD ~3'-t,~ "T' TRANSMITTAL NO.: WELL NAME: /~ 7- /n.c. wi 7/ SAMPLE TYPE: '~ · NUMBER OF BOXES: /2. 2"-~'Y///~,-r z,, F.c/7 REFERENCE: ~T'~. DESCRIPTION OF MATERIALS TRANSPORTED: ?, Please acknowledge receipt in whole of the, material described above by signing this transmittal and returning a copy to the address shown above. Date: Date: NECE'IVED DEI*AIIT~IENT OF LAW ! OFFICE OF THE AT'TORNEY GENERAL Shawn J. Holliday Groh, Eggers & Price 2550 Denali Street, suite 1700 Anchorage, Alaska 99503 Billie Pirner Garde Hardy, Milutin & Johns 500 Two Houston Center 909 Fannin at McKinney Houston, Texas 77010 July 18, 1991 WALTER J. HICKEL, GOVERNOR fO REPLY TO: ~ 1031 W4THAVENUE, SUITE 200 ANCHORAGE, ALASKA 9950 I- I994 PHONE: (90;') 269-5100 FAX: (907; 276-3697 0 KEY BANK BUILDING 100 CUSHMAN ST., SUITE 400 FAIRBANKS, ALASKA 99701-4~79 PHONE: (907) 452-I568 FAX: (907) 456-I317 {~ P.O. BOX K - STATE CAPITOL JUNEAU, ALASKA 99811-0300 PHONE: (907) 465-3600 FAX: (90.7} 463-5295 Re: Exxon Corp. v. Burglin, civ. H-90-3995 Our file: 661-92-0017 Dear Mr. Holliday and Ms. Garde: I represent the Alaska Oil and Gas Conservation Commission with respect, to the. deposition subpoena that was directed to its records custodian in the above'referenced case. Some of the materials requested in that subpoena are reqUired to be maintained confidential by AS 31.05.035(c). A review of the Commission's files shows that these materials are the reports and information required by AS 31.05.035(a) for Pt. McIntyre 3, 3 dpn, 4, 5, 6, 7, 8, 9, 10, 11, 12, and 13 Since the Commission is precluded by law from disclosing these materials, the Commission objects, pursuant to Federal Rule of civil'Procedure 45(d)(1), to inspection or copying of these materials. I note that all of the materials in question were filed with the Commission by the owners of the wells to which they relate, and that the owners themselves are of course not subject to the constraints of AS 31.05.035(c). Perhaps you will wish to consider directing your discovery efforts to those owners. I EC IVED JUL 1 9 A. laska .Oil .& 6as Cons, Sincerely, CHARLES E. COLE ATTORNEY~ g' GENERAL ~ By: Robert E. Mintz Assistant Attorney General 03.C5LH BP EXPLORATION June 14, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 BP Exploration (Alaska) Inc, 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Subject: W~,.I! Data Transmission Dear Mr. Smith' ~ ~ ~z -~ Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 is the following well data: Routine Core Analysis, Pt. Mclntyre #9 disk (with oil and water saturation data), to accompany previously sent Routine Core Analysis Report. The oil, water and gas saturations were inadvertently left off the disk(s) we recently sent to you for Pt. Mclntyre #9. Although we were aware of this problem, we elected to send you the disks anyway because of possible delays in getting a more complete disk from Scotland. We apologize for any inconvenience this may have caused. We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Bryan E. Stepanek, MB4-6 Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, AK 99512-6612 Received Attachments Date: KEY TO ATTACHED ASCII LISTING' · CN : SPLE : CDEP : KMAXA : KMAXL : KVRTA : PHIA : DRSATO : DRSATG : DRSATW : -12.00 : -17.00 : -18.00 : -19.00 : Core Number Sample Number Core Depth (feet) Horizontal Permeability Ka (mD) Not Applicable Vertical Permeability Ka (mD) Helium Porosity (per cent) Dean and Stark Residual Saturation Oil (%) Dean and Stark Residual Saturation Gas (%) Dean and Stark Residual Saturation Water (%) Chip Sample Fracture Damage <0.01 BP EXPLORATION May 31, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Subject' Well Data Transmission Dear Mr. Smith: Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 is the following well data: Routine Core Analysis, Pt. Mclntyre #9 (with disk) We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Bryan E. Stepanek, MB4-6 Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, AK 99512-6612 BES/mmh RECEIVED dUN 1 4 lggl Attachments BP EXPLORATION .April 17, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 Subject: Well Data Transmission BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Dear Mr. Smith: Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 are well cuttings from Pt. Mclntyre #9. We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Bryan E. Stepanek, MB4-6 Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, Al 99 ,-6612 Received by: BES/ Attachments TRANSMI'¥TAL t1:1127 Ap'ri'l. 24, 199:1. BP EXPI_OIr~ATION (ALASKA), INC, 1310 'West' 56th Avenue Anchorage, Alaska 99518 Attn: CORE STORE M~', I... C, Smith Alaska OJ. 1 & Gas Con.se~'vatio'n ComTniss:i. on 300.l Po~-cc~p:Lne 13~', Anchora.cje, Al/, 99501-:1.433 Re'f"e~'ence: "l'~,aTtsm:i. ss:i.c)'n o'f" D'ry Cutt:i.'n.gs samples 'f"'rom well I:.'t, Mc:y'n't'.y~'e :11:9 · f" o 'r s .1:. a .1:. e s a m p .1. e 1 :i. b ~' a 'r y, -f' I'.1 Iii: I::' 0 I... I... 0 W I N G M A T Iii: R I A I... I S B I!:' I N G S U B M I 'T T E D I"1E R E W I '1" I'.1 , t.- I... I::. A,:)I::. A C K N C) W I... E [)C') IE f .... I:> S " R I.:.': C Ii!: I P T' Iii Y S I., N .I. N G A C; 0 Y0 F" '1" H I I... I!i: '1" T I!E R A N D R E'T' tJR N 1' N G :1: T' 'T' C) T' I"11 ,S 0 F:' F" I C E: BP EXPLORATION April 17, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Subject: Well Data Transmission Dear Mr. Smith' Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 is the following well data: BP Exploration Pt. Mclntyre #9 Well Test Report HRS Surface Well Test (Post-Stimulation) Data Report, Pt. Mclntyre #9 HRS Surface Well Test (Pre-Stimulation) Data Report, Pt. Mclntyre #9 BJ Services Post Frac Report, Pt. Mclntyre #9 We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, AK 99512-6612 Received by' Date: · BES/mmh Attachments BP EXPLORATION April 19, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Subject: Well Data Transmission Dear Mr. Smith' Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 is the following well data: Schlumberger Production Log and sepia for Pt. Mclntyre #9, run 8 We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Bryan E. Stepanek, MB4-6 Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, AK 99512-6612 Received b~k~ %~~ ~ RECEIVED APR 2 ~ Alaska 0il & Gas Cons. Commission Anchorage Date: BES/mmh Attachments BP EXPLORATION April 10, 1991 Mr. L. C. Smith, Commissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Subject: Well Data Transmission Dear Mr. Smith: Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 is the Routine Core Analysis Final Reports (Robertson Group) for Pt. Mclntyre #9. We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Please acknowledge receipt of the attached well data. Should further information be required, please contact me at 564-5511. Sincerely, Bryan E. Stepanek, MB4-6 Niakuk/Pt. Mclntyre, BPX Alaska P.O. Box 196612 Anchorage, AK 99512-6612 Receivedbc,/ / /"'"' c,,'" RECEIVED APR 1 5 1991 .~:0i! & r_.._._, Oo_n_~: r_.o~mi~ion Anchorage BES/mmh Attachments RECEIVED APR 1,5 t991 Alaska,011 & Gas Cons. Commission /~nchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Thursday, March 14, 1991 AOGCC Porcupine Drive Anchorage Alaska Att'n' Mr Bob Crandell Dear Sir: Please find enclosed drilling reports for Point Mclntyre #9 as you requested. Please note that information contained in these reports is Confidential as with all other data regarding the well. I trust that these reports will provide sufficient information for your records. If there any questions, please call me at 564-4441. Yours Truly, C.R. Maskell Sr Drilling Engineer RECEIVED Alaska.Oil & Gas Cons. ANSMITTAL ~ 1112 March 8, 1991 EXPLORATION (ALASKA) , '10 West 56th Avenue .chorage, Alaska 99518 tn: CORE STORE INC. ~rry Gran'E Laska Oil & Gas Conservation Commission )01 Porcupine Or. ~chorage, Al< 99501 m.gerence: Transmission o¢ Dry Cuttings samples t~roTM ..~e].l Pt. Mcyntyre '%? -Cot sta't~ sam~!e library. E FOLLOWING MATERIAL IS BEING SUBMITTED HEREWITH. ~PLEASE ACKNOWLEDGE RETtJRNING IT TO THIS OFFICE: ~CEZPT 8Y SZGN.~N6 A..COPY OF THIS LETTER AND One set (total o1" 3 boxes) o'¢ Dry samples i-'rom well is 'From 85,60-13670. Box 2B 8560-10890 6B 10890-12960 lOB 12960-13670 · ~' 't i n ~ s The sampled interval Sent by:' ~-.' ,, :teceived :Y Bate BP EXPLORATION February 28, 1991 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Mr. L. C. Smith, Comissioner Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-1433 Subject: Well Data Transmission Dear Mr. Smith' Attached pursuant to regulations at 20 AAC 25.070 and 20 ACC 25.536 are the completion report, drilling summary, mud logs, coring summary, logging summary, directional surveys, and well test data for Point Mclntyre #9. We hereby request that pursuant to regulation at 11 AAC 82.810 that all information about Pt. Mclntyre #9 be kept STRICTLY CONFIDENTIAL from individuals, other companies, and other government agencies. Should further information be required, please contact me at 564-5511. Sincerely, Niakuk/Pt. Mclntyre, BPX Alaska BES/mmh Attachments POINT MCINTYRE #g · Tape ~ '~ ~ I Tel~::x) MWD olden hole log data c., .~ ,~ 'b..~.~ 1 Schlumberger open hole log data ~ ~ .t/',,~o~~ 1 '--{ ~'O C~ Schlumberger RFT data -- ~J., ~ .~ ~ o. ~ 1 '---! ~ ~ Schlumberger GCT data - ~t .~ /- I MWD Loas & Seolas -- - /'-Teleco RWD 1:240 TVD ,"T'eleco MWD 1:600 MD --'T'eleco MWD 1:600 TVD One I 1 One I 1 One I I Mud Loas & Sepias( -- /Epoch Mudlog One 1 1 Open Hole Loos & Sepias ,,~Schlumberger Dual Induction - SFL z. ¢---',"" C,x.~' One .--Schlumberger Dual Laterolog ~;z. +-s"") c,.,-,.,- Ip One .-Schlumberger Compensated Neutron Lithode nsity ~Rp~Vo~t2~y)~?~,~ One ...Schlumberger Compensated Neutron Lithodensity One .-Schlumberger Borehole Compensated Sonic¢ :z'%-' "c..~.~ ~ One ...Schlumberger Natural Gamma Ray Spectrometry Log ( ~.'~¢"~¢~,.-~ One .-Schlumberger Repeat Formation Tester One I 1 I 1 1 1 1 1 1 1 1 1 1 I Cased Hole Lo_as & Sepias --'Schlumberger GCT Gyro Continuous Survey ..Schlumberger Cement Bond Log (CBT) .-.Schlumberger Cement Evaluation Log (CET) .,Schlumberger Perforating Depth Control Log ..Schlumberger Packer Positioning Record Productign LOgS & Sepias /,~chlu mberger Base Temperatu re-Pressu re ~L0g:. ,i;"~ !~-i "::.'~ '!'i'!. '~ O n e 1 1 ,.-Schlumberger Perforating Record " ' Two I 1 ..-.Schlumberger PL/PBU Logs ,~ ~,~,~'~ 0!i ,!!, ,':;;:'.?:: ~";:.':;'.:~.~:... !:.:.~':~'r~:~:~:%r. Two 1 1 ..-Schlumberger Pedorating Record '" ~ ......... /~,r~:~:.-:::r?: Three 1 1 ,Schlumberger Production Logs Three 1 1 ~Schlumberger Production Logs Four 1 1 .-Schlumberger Perforating Record Four I 1 .Schlumberger Production Logs / Flow Data Five 1 1 .-Schlumberger PL Logs / Spinner Profile Six 1 1 ~Schlumberger Pressure Build up / Gradients Six 1 1 One I 1 One 1 1 One I 1 One 1 1 One 1 I The above materials were received and will be held strictly confidential by:~--~_ .-I.,-~S,~Commissioner Date: ~ Return to: Bryan E. Stepanek, MB4-6 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 POINT MCINTYRE #9 fEpoch Well Logging Core Summaries Eastman Christensen Core Summary CONFIDENTIAL Survey --"~reat Land Directional Drilling, Inc. Survey Report ,..Schlumberger Sub-Sudace Dirctional Survey Miscellaneous ...~Nell Completion Report (2) .-Daily Activity Record (2) .3'eleco Well Report Lltholoov Cuttlnas Cuttings will be shipped under separate cover letter directly from BP's core store / warehouse. Core Chi_~ Core is currently preserved. One foot interval core chips will become available in March when core is depreserved. Well Test Data Well testing is ongoing. Additional information will become available upon completion of program. The above materials were received and will be held strictly confidential by: L.~, Commissioner Return to: Bryan E. Stepanek, MB4-6 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 't STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT 1. Status of Well OIL [] GAS 1'3 SUSPENDED [] ABANDONED [] SERVICE [] 2. Name et Operator 7. Permit Number BP Exploration 90-140 8. APl Number 50- 029-22096 Classification o! Service Well (Onc~ t~tin~_ is completed.) 3'. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surtace 535'FNL, 1048'FWL, SEC. 14, T12N, R14E At Tog Producing Interval 2077' FNL, 3964' FWL, SEC. 02, T12N, R14E At Total Depth 1691'FNL, 4218'FWL, SEC. 02, T12N, R14E 15. Elevation in leet (indicate KB, DF, etc.) KBE = 40.45' 12. Date Spudded 11-05-90 17. Total Depth (MD+TVD) ~ - - '- r~ v' :,,~ - ~ ADL 365548 ~'".~ ......... ' ~.~u~' 13. Date T.D. Reached ~14. Date Comp., Susp. or Aband. 12-16-90 ~1~ 18. Plug Back Depth (MD+~D)[19. Directional Survey ~20. 14268'MD/9496'TVD ~ ~ D ~ B I 143 75'MD /95 77'TVD 22. Type Electric or Other Logs Run DIL/GR/AMS, LDT/CNL/NGT/AMS/GMT, RFT, DLL/Sonic/GR/AMS 9. Unit or Lease Name Point Mclntyre 10. Well Number Pt. Mclntyre #9 1. Field and Pool Point Mclntyre 15. Water Depth, it offshore 16. No. et Completions N/A feet MSL ONE Depth where SSSV set2095, feet MD 12;' Thickness °f Permafr°s t700' 23. CASING SIZE V~I'. PER FT. 20' 133# 13-3/8" 68# 9-5/8" 47~ GRADE K-55 NTSOCYHE NTSOS CASING, LINER AND CEMENTING RECORD HOLE SIZE SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2990' Surface i 13409' 13112' 14348' 26" 17-1/2" 12-1/4" CEMENTING RECORD 180 cu ft Coldset II 2402 cu ft Coldset II 2850 cu ft Class G 7" 29# L-80 8-1/2" 562 cu ft Class G AMOUNT PULLED 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Schlumberger 3.3/8" @ 6 spf MD TVDss 13646~13769' 9011~9109' 13784~13810' 9121~9142' 13840~13860' 9166~9182' 25. TUBING RECORD SIZE DEPTH SET (MD) 13148' PACKER SET (MD) 13O58' 4-1/2" L-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9-5/8"X 13-3/8" Freeze Protect Annulus with 120 bbls DrY Crude 27. PRODUCTION TEST Date First Production 1-21-91 Date of Test Hours Tested 2-4-91 24 F~ow Tubing Casing Pressure Press.'125 20 28. IMethod of Operation (Flowing, gas lift, etc.) Flowing (13646'-13769'MD) I PRODUCTION FOR IOIL-BBL IGAS-MOF ~0ATER-BBL TEST PERIOD ~ 1697.3 1456 --TER-BBL CALCULATED . p,L-BBL IGAS-MCF 17 24-HOUR RATE I~ 1697.3 1456 CORE DATA ICHOKE SIZE IGAS-OIL 56/64 1654 OIL GRAVITY-APl (corr) 27 RATIO Briel description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. Core #1 - 13544'-13593' Cut 49', Recovered 43'- Shale Core #2 - 13642'-13702' Cut 60', Recovered 60.3'-Shale, porous sandstone, oil stained, glauconitic Core #3 - 13702'- 13762' Cut 60', Recovered 60'-Porous sandstone, oil stained, fractured Core#4 -13762'-13812'Cut50', Recovered28'-Porous sandstone, oilstained t IIFIDE flAL. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate '~ '" "'~";'": 30. GEOLOGIC MARKERS FURMATION TESTS N,~E '' Include interval tested, pressure data. all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Ugnu/West Sak 7230' 5118' Colville Mudstone 10642' 7074' HRZ 13466' 8866' Kalubik Ck 13621' 8991' Kuparuk River 13642' 9008' * RFTpressures from 4409 to 4548 psi at 13668;14134'MD. £7o API oil recovered from 13646' to 13749' 654 GOB Milne Pt. Mbr 14150' 9407' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S 9.ed T ,,e Date / / - / ! 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- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, ~as t Item 28: Form 10-407 DEPTH ... 3 -Nov ~-' .... Zl-Nov CbdFIDENTIAL INFORMATION IRig up on well slt,e, l Mud engineer on location 2 Nov, 1990. Havtnq mud delivered. 5--Nov [ 800[Spud in at 0930, drilled Lo 493' made bit trip_kicked o~ 6-Nov · ,. · 1740 made bit trip (m 1478% 2675 Drilling, made a blt trip, building angle (44 deg.). Having some blt bailing, mixed no success as 1/eL . 3000 D for. 13 3/8',casing, CBU, short trip, C'BU, PO(0H,Ught, spo~02S', ...... had to rotate brough It, Cleaned Cla off' BHA RIH C§U POOH, ri u casi'~ 3000 Cemented 1;5 318' casin~ POOH did ~Down. ?a~3OOO]Cleaned pits, tested the BOP's, RIH, drilling cement. Albert Is bypassed Iwhile drllllnc1 cement. ' ..... 4500 Drilling. Flow line pluged ol3' aL 3563'. AL 3845' the torque was I000 amp. but, IL dropped back t.o 700 ~L 4126'SUII had Li iht S l~ [s around 3800% 4981 Made a bit trip at 4646~ot at 3845% Drilled to 4981',POOH~Rih. to 6209', POOH for bit. over to NewDrill~tem at 6000'. 73351Drilled to 69 I0', short'trip, drilled to 7335', POOH for blt. 8120 Drilled. to 7986', 8 stand short trip, Drilled Lo 8120', torque Increased after trip, angle off and drtilincL rate slowed down; CBU for trip. 8150 trip, drilled lo 8150'. Had a fire in the SCR room lost all power Lo the rig for 3 hours back, POOH into castna,: Work on SCR, 8150 Work on SCR room. 8150[Work on SCR room. 8150. Work on SCR room. Test BOP. P/U BHA and RIX. 8564 Rlh, CBU at 3000', 5100', 8150'. Drtlltnq ahead to 8564', Pooh for motor. DATE DEPTH INFORMATION 21-Nov 89991DynaDrill to 8999'. 22-Nov I 9700 IDynaDrilling' 23-Novl lOlOOIDynaDrlll to 9878', Pooh, change BHA, Rlh. DynaDrllllng. · 24-Novl 107871DynaDrilling. - . ' - ' I Adding MOt Nut Plug to help reduce torque. 25-Nov 110671 Irlll to 11067'r Pooh, change BHA, RIh. 26--Nov I 1150;51nih, Dy. naDrilling. ... 27'Nov 11920 I DynaDrilling to '11920', Pooh. .. 120;58 29-Nov I ;122621Dynaortll to. 12262', Pooh. ;50'Nov 1260;5 Rih w/rotary assembly, drilling ahead. Conditioning mud for high LOS. 1-DecJ 12751JDrtll Co 12605'~ Pooh, Change BHA, RIh...DynaDrilling. 2-Dec 12954 ,naOrIll .to 12885', Pooh, change BHA. Rih. Drill to i;501' w/rolmry assembly, Pooh. · 3-Dec 1;511 Rth, drill ahead. Raise mud weiqht to 10.0 ppg. "; 4,Dec · 1;5;550 I Drill to 1;5250', Pooh, change BHA~ Rih. Drilling ahead. ..... 5-Dec! 1;5420 Drill to casin ' o tnt, short Ltl Lo 12000' Rih CBU, Pooh. R/U and run 9 5/8" ~~ 6-Dec 1;54201Run casing, circulater cemenL~ and displace as per BP. 1;5420j Test BOP, work on electrical wiring to accumulator. 1 O-Dec 1;54;501Rih, displace New Drill mud w/BP coring fluid. Drilling ahead. 1;55441Dr111 to 1;5544', Pooh f/core barrel. 1359;5 j Rih w/barrel, cored 49', care packed off, Pooh. J Mixing LubrtBeads for torque. '" CONFIDENTIAL OATE I OEPTH I ..... INFORMATION 11-Dec J 1:5643 J L/D core, Rih. Corinq. ........... .Tm :.-,: .: .:... 12-Dec J 13762 J Core to 13702', Pooh, L/D core. Rib w/barrel. .. 13-OecJ 14-DecJ 15-OecJ 13812 J Core [o 13812'. Pooh r/new Teleco tool. RIh. 14182JRih, finish logs, drill to 14182'~ Pooh. 14255JPooh~ Rih, drilling ahead. 16-Decl 14375 Drill to TD-14375'r CBU w/high vis sweepr pull 5 stand short ~ip, Rih~ CBU, POOH. ' 17-Decl 14375 Pooh, R/U and loq. 18-Decl, 14375JRth,CBU; .short b'tp, CBU w/sweep, raise mud wt. t~ 10.2 ppg. CBU. Pooh (canc.el last log)..'. I g-Dec I 20--DecJ 14375 R/U and run 7" liner, c!rculaLe~ cement and displace as per BP. 14375J Clean out runs for casinq and liner, ' · 21-DecJ 14375 Change over to 9,6 ppg briner filter. · 22-Decl 14375 Complete well as per BP. kLASKA PRODUCTION ~¢r 17~ lZ....e ~ ,)( l:Z, 0 ~7 ,1, "ALASKA PRODUCTION c~G a R, 7 7O ~,78 TPtli. lt ALASKA PRODUCTION °" c> d),'/.., i,Ve",-. I/'7 ~o .5/Z~ -30c~ ,,q e..s' ? · ALASKA PRODUCTION MuD H~ vii, it,:, /,~ ~..--/,../., ,"" ~, o , o /700 ° ~,4o0 ti'! /,d,d ALASKA PRODUCTION C · TIBIA ~,LASKA PRODUCTION kLASKA PRODUCTION ~9 '"/,6' '70 . 17.0 X.T 70-7z ALASKA PRODUCTION 17'oo ~/3 ... zqqo HP .,o ,..¢o7.y ~ ~LASKA PRODUCTION HI" ALASKA PRODUCTION /0 ALASKA PRODUCTION ,5" /7- ?~ ALASKA PRODUCTION H~ J~ AI. ASY~ PRODUCTION PiT ALASKA PRODUCTION ALASKA PRODUCTION T1M~ , ~ ql et M.a.K~'MOOe~ .H~ 4"/ '.Y 2 z,. 7 ,~ -- SI'A/II:lARD ALASKA PRODUCTION '21 w°e Z o / M O ,-,, w~' I ,/ '"16 29?0 ~7 o 9do. ' i IT.' ALASKA PRODUCTION : · ~ . ~ ~. E~ ~ , ~.~ ___ IZ Ir,r' HP ~k /0 / ,/d c ! __ · __ · --.. ii ALASKA PRODUC"I'ION 12.$ ,d I?o.~ /~..t/'e ..o _%. '"' ! ALASKA PRODUCTION HP ~7~o kLASKA PRODUCTION ,'11 H~ 7 ii ii ii ii , 1- ,,., · i im i 'V ~.LASKA PRODUCTION:. "' 9'90 'Z:/,. 7 ~ /~. 777~ 2 ~0o · _.1 II )'TAitDAlU) iASKA PRODUCTION ~7o ALASKA PRODUCTION I?oo I$ tOG ~ (t~l! p,~ lyre, c~lOO -. i, __ III, ASICA PRODUCTION zT~; I .... · -. ~'oo_ ~, o o ,~ ~~,'¢L,~~ ~//~ z_~_z' --~~'~ m m ....... F40 / _0o u~"..C,'~, .,,- ............ i z-~-- - d __. ,,__~ . . -~-. -.- ' I ......... ..... i i i i ......... - ............ _ _ - i . im ,1 , - .. ~ .... . .............. - ....... .. i -- ...... ~ --' - ...... ..... s. .... m 'm mm i ... m i m . . . ...... ...... i i i Ih II III ~ .... II I I I I II I I ii ..... . -' I i I II I I ~IL~ :~ ...... ........... II II III _ I I I. I ALASKA PRODUCTION /~ ~? q?o ~l (. K/143'1 ALASKA PRODUCTION 12Gq~ I.gS'~rS' ~ ~o ~ ~z ~ ~ · '~. ~ ' C/r'c. /?$so .. . ALASKA PRODUCTION C, ~o kLASKA .PRODUCTION HP Io~0 P~ H ALASKA PRODUCTION " Is"' o , o. ALASKA PRODUCTION I~qzo // .-. ALASKA PRODUCTION j, zooo _ ALASKA PRODUCT'ION lip LASKA PRODUCTION f"lT ~,LASKA PRODUCTION ./ //~ /7O ALASKA PRODUCTION HP 1.3 ;cio | fHn'. H~ ~LASKA PRODUCTION ? ~,LASKA PRODUCTION ouT' MI" -t. - J LASKA PRODUCTION I/ Hit* -3Wo fl~ I. ' ~/ z. ASKA PRODUCTION I! 7 ALASKA PRODUCTION ALASKA PRODUCTION . ! PIT "" .,-,,' / p,m.l.,t/t'][~ PRODUCTION ,/ /, ii i .... ..~ ALASKA PRODUCTION w~LL ;,La. ME ~. HP t?~0 ~L Il _ J ii ALASKA PRODUCTION /_.,~,/',2 lip .ASKA PRODUCTION '.luL~r~ y f, ~ · ALASKA PRODUCT'ION. M~T YP HP i lin Il I -rllnl it. ALASKA PRODUCTION Yp Jl,.I ALASKA PRODUCTION CUM. ALASKA PRODUCTION ell YP H~ 1700 .5' ALA51~ PRODUCTION ~H~K · o ALASKA PRODUCTION I~--rl ou'r CUM. ~0 BP EXPLORATION HYDRAULIC FRAC OPERATIONAL SUMMARY REPORT OPERATION: Pt. Mclntyre//9 FRAC DATE: 2/19/91 RECEIVED APR 2 2_ 991 Alaska Oil & Gas Cons. Oomrnission Anchorage 0 800 SIWHP = 950. lAP = 160. OAP= 200. Ambient temp = -40 F. 10 mph winds PU BJ. Stab tree saver. RU HB & R. Heat DSL to 100 F 1130 R U SWS. Wtr QC: SWTR Base: 85 F. 7.3 ph. 2.0 ppm iron. 140 ppm bi-carbs 50# gel: 7.4 ph, 46 cp. X-link: 10.2 ph, time = 2:31 (Pipe time = 6:15). 16:15 Prime up w/DSL. Attempt to PT. SWS riser leaking. 18:15 Unable to locate leak. RD riser. PT to 7500. Hold safety mtg. 2144 Pump acid as per summary. 2300 Close well in. SD for night due to high winds. (-100 F wind chill). TIME BPM ANNP WHP STAGE CUM COMMENTS VOL VOL ...... J~'i'44 " Oi .......... 2475 "900 .......... O/ ..................... Begin DSL. cheCktree'saver, o'K"' 46 4.3 2550 3170 4/0 SD. Batch to 10# gel. 55 O/ 2400 1060 O/ Begin 15% HCL. 59 11 2525 3570 12 2200 6.7 2500 3240 25 3 7.2 2475 3240 50 11 7.2 2375 3230 101/0 Begin 10# gel. 14 10.4 2350 3340 20 17 10 2300 3220 50 19 9.9 2300 3130 75 21 10.5 2300 3075 95 23 10.5 2275 3005 119 O/ Acid at perfs. 24 10.5 2250 2950 130 10.5 2250 3000 140 26 7.2/0 2250 2700 150 31 SD for soak. ISIP = 2000 28 0 2150 1900 44 O/ 2150 1300 Resume pumping. 46 10.5 2275 2950 165 10.7 2275 2975 175 Begin DSL. 47 21.1 2275 3820 185 48 20.2 2250 3810 200 49 20.2 2250 3920 219 101/0 10# at perfs. 50 20.6 2250 4100 240 (Losing hydrostatic/inc, friction) 51 20.2/0 2250 4200 260 SD pumping. ISlP = 2600. 59 1900 Close well in. Bleed IA to 1000. .69 frac gradient. SUMMARY FLUIDS PUMPED' 4 bbls DSL to check the tree saver / establish rate. 101 bbls 15% HCL 175 bbls 1 O# gel (soaked acid after 31 bbls out peals) 85 bbls DSL freeze protect. BP EXPLORATION HYDRAULIC FRAC OPERATIONAL SUMMARY REPORT OPERATION: DATE: 2/20/91 Pt. Mclntyre//9 Frac (Cont'd) 1000 Temp = -30 F, 15 mph winds. SIWHP = 720. lAP = 1100, OAP=200. RU SWS (changed out 'O' rings in riser) 1130 RU BJ, Veco, CWC 1300 Prime up w/DSL. PT to 7500 Attempt to RIH w/E-line. Leak in 3" riser and lubricator. POOH. 1545 Fix leaks. Re-pressure test to 7500. RIH w/E-line. 1740 Tie-in to 1/1/491 Base Line Temp Pass (-1' correction) Hang pressure gauge at 13600'. BHT = 180 F. BHP = 4400 psia. RU HB & R to IA. Pressure to 2500. Hold safety meeting. 1900 Pump data frac as per summary. 2125 POOH w/E-line. RD SWS. Analyze data frac. 2/21/90; 100 Analysis complete. Call out 100M and 20/40 proppant. 300 Prime up. PT to 7500. Hold safety meeting. 435 Pump frac as per summary. Screened out w/33000# behind pipe. 508 Closed well in. Flushed lines. RDMP. TIME BPM ANNP WHP STAGE CUM COMMENTS VOL VOL 1900 Pump 12 bbls DSL to check tree saver. 123 bbls SWTR & 97 DSL in tbg. 1932 0/ 2700 850 0/ 35 2725 1700 3 Flowmeter quit momentarily. 38 2.0/ 2725 2110 8 40 2.9/ 2725 2580 14 43 4.0/ 2725 2950 26 46 5.1/ 2725 3050 Frac van generator quit. 47 5.9/ 2725 3195 86 On emergency power. 49 7.2/ 2700 3340 98 Ext. psi = 6400 BHP..71 frac gradient. 51 8.6/ 2700 111/0 SD pumping. Back on power. 2007 0/ 2725 1270 0/ Begin prepad. Meter not working 2009 0/ Begin again 14 36.6 2725 5050 115/0 Begin x-link / buffer / FLA 16 35.8 2725 4585 60 17 36.1 2725 4660 100 19 36.1 2725 4815 150 20 36.4 2725 5060 200 36.4 2725 5125 220 0/ X-link at perfs 23 31.5 2725 4700 300 1 pump off line. 24 35.5 2725 5120 355 25 35.5 2725 5070 400 27 35.5 2725 5040 450 Cut LFC 28 35.5 2725 4950 500/0 280 Flush 30 35.9 2725 4970 50 31 36.1 2725 5000 100 32 36.6 2725 4825 135 33 36.4 2725 4740 150 SW to DSL 160/0 34 35.8 2725 5135 45 35.7/0 2725 5300 61 Flush at perfs. SD pumping. ISIP = 2180 40 0 2725 2100 Not bleeding. 46 0 2725 1940 Bleeding slow. 2100 0 2700 1485 2114 0 2700 1380 FP pump w/DSL. 22 Flushed w/20 bbls DSL. (TELEX CONTINUED) WELL: Pt. Mclntyre #9 "TIME'I ..... BPM ......I ..... AN'NP'"'[ WHP I STAGE'"I ...... OUT I ............... COMMENTS .... I I I I VOL I PERFSI ... 3:34 31 O0 785 4 Pump DSL to check tree saver. Batch up to 50# 435 O/ 3050 850 /0 !Begin prepad 38 22 3150 4910 40 Start x-linker 32.9 3075 5660 65/0 Pad 40 33 3075 5445 35 41 34.5 3075 5575 70 35 3075 5330 1 O0 42 35.2 3075 4800 130 43 35.3 3075 4505 170 44 35.3 3075 4605 200 45 35.3 3075 4590 220 0 Pad at perfs 46 35.3 3075 4590 270 47 35.3 3075 4590 310 49 35.3 3075 4600 357/0 137 .6 PPG, 20/40, lOOM. 50 35.3 3075 4590 35 51 34.9 3075 4590 80 (Mistakenly reset) 52 34.9 3075 4590 122/0 259 1 PPG. 20/40. Cut FLA 53 34.9 3075 4590 30 54 34.8 3075 4575 75/0 334 3 PPG. 20/40 55 34.8 3075 4480 23 357/0 100 M at perfs 56 35 3075 4430 40/0 17 5 PPG, 20/40 57 35 3075 4270 29/0 46 7 PPG, 20/40 58 35 3075 4140 31/0 77 7 PPG, 16/20 34 3075 3980 31/0 108 9 PPG, 16/20 59 33.8 3075 3970 14 122/0 1 PPG at perfs 500 33.3 3075 4060 50/0 36 11 PPG, 16/20 (Did not reset) 01 33.3 3075 4260 39 75/0 3 PPG at perfs. Cut-LFC 02 33.3 3075 4425 71/0 32 13 PPG 8 40/0 5 PPG at peals 03 33 3075 4505 37 29/0 7 PPG (20/40) at perfs 04 33.8 3075 4525 68 31/0 7 PPG (16/20) at perfs 05 34 3075 4960 99/0 31/0 9 PPG at peals. Flush /0 6700 8 8 Screen out 116000 # pumped. 33000# behind pipe (12000# 16/20) 08 2850 Close well in. Flushed lines. SUMMARY FLUID SUMMARY: DATA FRAC: 12 bbls DSL - check tree saver. 111 bbls 50# linear gel - step rate test 115 bbls 50# linear gel - prepad 500 bbls 50# x-link gel - minifrac 150 bbls gel-flush 70 bbls DSL - flush 20 bbls DSL - Freeze protect pump. rreatin,q pressure = 5050 psi / 36 BPM. Pressure indicates hiqh perf friction/hiqh near well bore pressure :lrop (1000 psi). Bottom hole frac pressure from step rate test = 6400 psi due to unfavorable orientation. Data frac results: P-Closure = 5600. Time-Closure = 13.6 min. (14.2 min pump time) Frac H = 110'. P - Net = 305. C = .0032. Eff = 42% FRAC: 4 bbls DSL - check tree saver. 65 bbls Prepad 357 bbls Pad 122 bbls (Dirty) .6 PPG, 100M 75 bbls (Dirty) 1 PPG, 20/40 Carbolite 40 bbls (Dirty) 3 PPG, 20/40 Carbolite 29 bbls (Dirty) 5 PPG, 20/40 Carbolite 31 bbls (Dirty) 7 PPG, 20/40 Carbolite 31 bbls (Dirty) 7 PPG, 16/20 Carbolite 50 bbls (Dirty) 9 PPG, 16/20 Carbolite 71 bbls (Dirty) 11 PPG, 16/20 Carbolite 99 bbls (Dirty) 13 PPG, 16/20 Carbolite 8 bbls Flush. Rapid screenout w/9 PPG at perfs. Estimate 33,000# behind pipe (1200# of 16/20). 83000# left in tubinq. rreatin,q pressure durinq pad = 4590 psi/35 BPM. Max pressure at screenout = 6700. Load volume (including acid iob): 2100 bbls. OPERATION:POINT MCINTYRE #9 WELLTE~T TEST #1~ 13,646-769 Post-Frac Production Test (2/27-3/1); Surfactant Treatment (3/1-3/3); Acid Stimulation (3/3-3/4) TIME WHP WHT WC Qo CUM CUM COMMENTS PSIG DEG % STB/ OIL WTR F DAY BBL 2 / 2 7 Inlet wtr cuts taken @ outlet of heater. 1900 80 37 I 671 2133 Rates and Cummulatives taken from tank straps. Rigging up Schlumberger ,qr/ccl/hum/,qrad/p/t/spinner 2000 50 43 8 331 2148 Oil Mtrfactor.1%r 1 hrShrikage 0.9984 2100 95 39 20 812 2181 2200 50 40 4 832 2224 Dumped 8 bblwtr 2300 116 37 6 551 2250 Dumped 3 bbl wtr .Han,(] pressure probe ~ 13710 MD 2400 84 37 3 491 2272 Dumped 2 bblwtr Begin monitoring FBHP /0 2 / 2 8 Note: Cum oil figures prior to 2400 hrs include wtr prod. 0100 52 40.7 20 220 10 0200 171 37.7 1.5 721 40 Dumped 3.3bblwtr 0300 130 37.4 .8 801 73 Dumped.84 bbl Calculated wtr cut 5.3% 0400 124 37.6 .5 821 107 0500 114 37.7 .3 701 137 0600 102 37.4 tr 741 167 0700 107 37 .4 641 194 0800 117 38 6.0 341 208 0900 83 37 7.0 541 231 1000 128 37 4.0 912 269 1100 124 38 4.0 751 300 Dumped 3.74 bblwtr 1200 117 38 1.0 894 337 Ph7, Salinity 27000 1300 122 38 1.5 651 364 1400 150 38 .5 791 397 Pedorm production logging including petal basket flowmeter 1500 85 38 2.6 461 416 1600 127 37 5.0 621 442 1700 104 38 4 561 465 1800 135 38 2 741 495 1900 125 37 0 481 515 Dumped 2.7 bbl water from separator 2000 148 38 0 881 552 2100 464 559 SI WELL @ 20:22 for STEP RATE TEST 2200 0 559 2300 0 559 FLOW WELL ~ 23:24 - RECOVERED 156 BBL DIESEL 2400 18 50 0 0 559 3/1 1714 638 0100 293 44 0 0 638 0200 132 41 1.8 1770 749 Dumped 3.34 bblwater from separator 0300 114 40 6.0 972 789 0400 122 39 0 902 827 0500 126 39 0.3 802 860 0600 120 39 0 782 728 0700 130 39 2 561 751 0800 129 38 5 731 782 0900 128 38 3.5 731 812 Dumped 3.27 bblwtr from separator OPERATION'POINT M(~I',,~rYRE #9 WELLTEST TEST(~6 13.646-769 TIME WHP WHT WC Qo CUM CUM ~MENTS PSIG DEG % STB/ BBL W'i'R F DAY 1000 132 38 1.5 781 845 1100 118 38 .5 801 878 1200 114 39 .3 822 912 1300 118 38 581 937 1330 POOH w/logging tools 1400 104 39 4 611 962 1500 107 38 1.5 631 988 Dumped 8.54 bbl water from separator 1600 98 37 6 831 1023 1700 136 39 791 1056 1800 107 39 872 1092 1900 106 39 .5 792 1125 2000 138 39 I 551 1148 Dumped 1.02 bbl water from separator 2100 169 40 I 1042 1192 Dumped 1.01 bbl water from separator PERFORM SURFACTANT TREATMENT TIME WHP WHT WC BFP CUM CUM COMMENTS PSIG DEG % D BBL WTR F BBL 2200 156 39 2 772 1224 SI @ 2200 FOR SURFACTANTTREATMENT CHEMICALS (BJ) USED IN JOB: 4200 Gals Seawater 21 Gals MMR-2 (Non-Ionic Sudactant/Matrix Mud Remover) 21 Lbs GBW-5 (Gel Breaker for water) 9 Gals MS-10 (Mutual Solvent) 60 Lbs Divert I I Gal AG-12 (gelling agent for diverter) Job staged as 25 Bbls/5 Bbls/70 Bblsr 5Bbls w/gelled Divert I. 2300 2400 3/2 0100 0200 ~0212 finish surfactant treatment. Leave well shut in. 0300 1006 77 0400 922 77 0515 892 77 Open well for flowback. Note Re-zeroed cum oil 0600 10 51 0 561 Dsl returns 0700 9 49 0 561 53 Dsl returns 0800 8 48 0 370 69 Dsl returns 0900 9 47 0 331 83 Dsl returns , 1000 8 45 0 321 96 1100 8 44 0 301 108 1130 MIRU Nowcam CTU. P test/function test BOP's 1200 2 43 0 661 136 NOTE: 1230 1 0 83 160* 139/ Re-zero cum fluid. Switch out of diesel return tank 8. * NOTE: 0* Rates and Cums are total liquids (oil and water). 1300 13 43 100 321 7 RIH with coiled tubing 1400 62 25 98 721 30 13:30 Begin N2 @ 1500'r Cont in hole with coil 1500 110 43 95 1513 63 Coil@6000ft Cont in hole with coil 1530 Coil ~ 7000 ft. Reduce N2 to 400 SCF/min 1600 70 43 72 571 123 113.6 Page 2 OpERATION:pQINT MC',,,£YRE #9 WELLTEST TEST~ff6 13,646-769 TIME WHP WHT WC BFP CUM CUM ~MENTS PSIG DEG % D BBL WTR F BBL 1645 Reduce N2 to 200 SCUM 1700 60 41 40 731 154 126 1745 Stopcoil~12300 MD 1800 115 42 60 711 184 1900 185 43 50 681 212 2000 188 44 55 1042 256 2100 99 41 20 902 294 185 Total wtrusedduringsuda~anttmatment= 220 Bbls. 2200 117 41 25 721 323 2300 79 40 22 721 353 2400 170 42 15 1202 403 Wtrstmpintank#6- 32.6bbl 3/3 0100 99 42 12 396 420 0200 107 39 10 942 459 0300 183 42 12 732 489. STOP N2 5 0400 5 41 9 571 513 0500 85 39 7 711 543 0600 377 45 7 1483 605 0700 100 318 620 0800 100 0.9 254 629 228 0900 8 39 0.9 390 645 229 CTU PERFORATION WASH/N2 LIFT TIME WHP WHT WC BFP CUM CUM COMMENTS PSIG DEG % D BBL WTR F BBL 0937 Shut in well. Fluid pack tbg w/36.1 bbl Dsl 1055 460 Finish fluid pack. RIH w/coil 1012 600 Begin 5% acid @ 1.2 BPM 1020 1520 1.1 BPM CTP 3500 psi 10 bbl acid pumped 1027 20bbl acid pumped 1031 1640 1.3 BPM~ Acid ~ peals/Begin recip 25 bbl pumped TIME WHP CTP STG RATE NZL COMMENTS VOL BPM DEPTH 1036 2020 3560 30 1.2 13690 1045 2180 3100 42 .25 13640 Reduce rate. CTU packoff grabbing/ try to free up. 1055 1480 3500 13645 Resume pumping and recip 1058 1960 3560 50 1.3 13744 1109 2030 3560 60 1.2 13646 Packoffs sticking again. Slow rate to .25 bpm while oiling packoff. 1115 1990 3610 70 1.2 13744 1121 2020 3610 77/0 1.2 13640 Switch to SW. 1129 2010 3750 5 1.3 - 1132 2060 3800 10 1.3 - 1136 2060 3800 15/0 " " Switch to diesel 1142 2070 3800 5 1.2 - Page 3 OPERATION'POINT Mct~rYREi #9 WELLTEST TEST'~6 13.646-769 TIME WHP CTP SIG RATE NZL COMMENTS MDL BPM DEPTH 1144 " " 10 " " Acid away @ 8 bbl diesel pumped ACID SUMMARY: 3 MGALS 5% HCL W/FOLLOWING HALLIBURTON ADDITIVES: 45~ GALS FERCHEK-A (IRON SEQ'G AGENT) 5 GALS (TOTAL) PEN-5 (NON-EMULSIFYING AGENT) 6 GALS (TOTAL) HAl-85 (CORROSION INHIBITOR) 1150 " " 15 " " 1153 " " 21 1.2/0 " End treatment. 5 min SIP 1630 1200 1590 Pull out of hole to change packoff and prepare for N2 lifting.. Open wing to blow down WHP Fluid Summary: 58 bbl DSL, 77 bbl 5% HCL, 15 bbl SW Job Summary: Acidized peds with 77 bbl 5% HCL at 1.3 BPM, 2080 psi. Ovedlushed acid with 13 bbl sea water. Saw +/- 150 psi decrease in injection pressure during the job. TIME WHP WHT WC BFP CUM CUM COMMENTS PSIG F % D BBL WTR 1300 184 46 .7 2668 758 230 Monitor well while changing packoff 1400 3 48 .5 551 781 230 .......... 1500 101 42 .5 671 809 230 Finish packoff installation. P-test~ trouble getting prime 1600 33 37 .5 1223 859 230 RIHwcoil~ 15:45. Begin N2~ 1600 hrs. 1700 50 43 75.0 1402 918 274 Begin N2 again @ 1735. Injector head hose broke. Stop coil at 3800 ft & repair hose. N2 truck quit after 10 min of pumping ~ 500 SCF/M 1800 72 43 50.0 772 950 284 Rate ~ wtr affected by Meoh comming out of the coil. 1815 RIH w/coil again~ Begin N2 ~ 500 SCF/min 1900 123 41 20 1393 1008 295 2000 234 45 13 1813 1090 306 2030 Nozzle ~ 12000~ rate reduced to 200 SCFM 2100 257 47 20 1793 1158 320 , 2120 POOH 2200 236 47 20 1603 1225 333 2230 Nozzle @ 3000~ stop pumping N2. 2300 205 46 I 1202 1275 334 CTUOOH FINAL FLOW PERIOD TIME WHP WHT WC BFP CUM CUM COMMENTS PSIG F % D BBL WTR 2400 146 45 10 1273 1328 339 3/4 0100 160 45 10 1162 1377 344 0200 144 44 5 1002 1418 346 0300 157 45 10 1263 1471 352 0400 164 45 8 1383 1529 356 0500 156 45 8 1383 1586 361 0600 157 47 5 1182 1636 362 0700 197 48 8 1523 1699 367 0720 Switch into separator 0800 159 46 2 1250 1742 368 Page 4 oPERATION:POINT M(~rYRE #9 WELLTEST TEST "~t~ 13,646-769 TIME WHP WHT WC BFP CUM CUM COMMENTS PSIG F % D BBL WTR 0900 163 46 6.4 1383 1800 425 1000 162 46 4 1282 1853 427 1100 125 45 3.7 1323 1909 430 1200 165 47 5.3 1352 1965 432 1300 154 46 6.0 1323 2020 436 RUN SWS IN HOLE W/HP/GRADIO/TEMP/PETAL BASKET SPINNER ~ 13:28. 1400 149 45 4,0 1292 2073 438 1500 146 44 4.0 1112 2120 440 1600 135 43 3.5 1042 2164 441 HP Gauge Pressure @ 0410 = 2180 psi. P1=.58 Stb/psi. Monitor BHP for I hr before running Prod logs. 1700 158 45 2.8 1263 2215 443 1800 162 47 3 1281 2270 445 1900 122 45 3 1374 2330 447 2000 153 45 3.5 1296 2382 449 2100 160 46 3.5 1192 2432 450 2200 144 45 3.5 1232 2483 452 2230 POOH due to Spinner malfunction 2300 156 46 3.5 1263 2536 454 2400 155 46 4.0 1162 2584 456 SWSOOH 3/5 0100 150 46 3,0 1323 2639 458 SWS change spinner and cjradio and RIH 0200 147 45 3.7 1062 2683 459 ' 0300 143 45 3.5 1232 2735 461 HP Gauge Pressure ~ 0300 is 2100 psi 0400 160 46 2.5 1192 2784 462 0500 162 48 2 1363 2841 463 0400 begin spinner passes 0600 176 48 2.5 1333 2897 465 0700 149 46 1.2 1333 2952 465 Hang pressure pmbe~ 13724' MD BKB 0800 164 46 4 1323 3007 468 0900 197 48 3.6 1252 3059 469 1000 156 47 4 1192 3109 471 1100 169 48 3.9 1222 3160 472 1200 189 49 4.0 1082 3205 474 1300 188 48 1.4 1363 3262 475 1400 180 49 3.1 1212 3312 477 1500 180 49 3.0 1352 3368 478 1600 180 49 1.5 1262 3425 479 1700 142 47 4.75 1262 3478 481 Page 5 TREE: 4-1/~6" 5000/1 FMC PT. MclNTYRE ~/9 KB. ELEV=40.0' WELLHEAD: 13-5/8" 5000# FMC TEST~iI GR. ELEV= 2.0' ii ~ iii iii ACTUATOR: OTIS ~ i,.,.-- SSSV LANDING I '~ NIPPLEI 2096 13-3/8", #/ft, ~ (OTIS)(3.813" ID) L-80, BTRS .ii_, I I ~ k GAS LIFT MANDRELS 2990 I '~(~AI~ ICO WITH RK LATCH~ No MD(BKB/ TVDss ~ 6 3533 2964 KOP: 500' , 5 7516 5253 4 10094 6711 MAX ANGLE: 59.4 3 11217 7364 2 12302 7999 ~ I 12995 8463 4-1/2", 12.6#/ft, L-80 TUBING I TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT I ~ 4-1/2" 'SWS' NIPPLE I ii (PARKER) (3.813" ID) 13022 ( OTIS )( 3.850 'ID) I 13057 ! I, 4-1/2" 'SWS" NIPPLE I TOP OF ' ': ~ (PARKER) (3.813" ID) I 13115 7" LINER 113113 I ~'~ ~-J-/ 4-1/2"(PARKER)(3.813,, ID)'SWS' NIPPLE '1 13136 9-5/8", 47#/ft, I ! ~ (bottom) i I~NOTE: WD PACKER HAS SLIPPEDA PERFORATION SUMMARY ~TOTAL OF 22 FEET DOWN THE REF: LOG: BASELINE TEMP/PRESS1/7/91 ~HOLE. NEW LOCATION IS SHOWN SIZE SPF INTERVAL OPEN/SQZ'D '-~ ~ _ 4-1/2" 'X' NIPPLE I I -I.-~ 4-1/2" 'XN' NIPPLE I DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9 1-9-91 RRB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 1- 19-91 SFM PERF'S & TD SEC 14 ; T12N ; RG14E 1-22-91 CMM TEST #1; REVISED WD LOCATION BP Exploration (Alaska) GAS LIFT MANDRELS GAI~ lCD WITH RK LATCH} No MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 I 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13840-13860 OPEN GAS LIFT MANDRELS 'CAI~ICC WITH F K LATCH~ Nm MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 1 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13784-13810 OPEN 3 3/8 6 13840-13860 OPEN TREE: 4-1/16" 5000# FMC PT, MclNTYRE #9 KB. ELEV =40.0' WELLHEAD: 13-5/8" 5000# FMC TE~T i ."2 GR. ELEV = 2.0' ACTUATOR: OTIS ' I ' ~ I SSSV LANDING ! . ~ -L--- NIPPLE I 2096 ! 3~3~/8 ~.,.,., ,.?/ft, ~ ! (OTIS)(3.813" ID) L-13U, D/MO ~ / , , ,/ , i / ~, I GAS LIFTMANDRELS I 2990 I -- . ! I'.CAI~ICOWITH FKLATCH! ' / ' Nm MD(BKB) TVDss , ~/ 6 3533 2964 | !MAXANGLE: 59.4 ~ ! 4 , 10094 6711 ~'-- I ~ 3; 11217 7364 ! "-r~ - 2 12302 7999 ~ ~ 1 i 12995 8463 4-1/2", 12.6#/ft, L-80 TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT -' ', / / ~- ~, ~ 4-1/2" 'SWS' NIPPLE ~ '-'1--- (PARKER)(3.813" ID) I 13022 l ~~' TUBING SEAL ASSY' I 13039 [ ~;~ ~ 9-5/8" PACKER I !"--1 (OTIS)( 3.850 "ID) T~D ~ , , ' ~ ~ .__.[--.- 4-1/2" 'SWS" NIPPLE I 'F"; ER I 13113 I ---- z. (PARKER)(3.813",D)1 13115 I I~ 4-1/2" 'SWS' NIPPLE I , i TI (PARKER)(3.813" ID) ' "l--f[~ 4'1/2" Tubing Tail I ~314~ I 9-5/8", 47#/ft, i 13409 I J I ~ (bottom) , L-80, NSCC I ! --"-- I ELMD I 13150 MARKER JOINT ~NOTE: WD PACKER HAS SLIPPED A PERFORATION SUMMARY ~ ~TOTAL OF 22 FEET DOWN THE REF' LOG' BASELINE TEMP/PRESS1/7/91 r::l · ' i 'E'HOLE, NEW LOCATION IS SHOWN ;SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 i 13784-13810 OPEN 7" OTIS"WD" PACKER 13833 ! ; ! ! ~_ 4-1/2" 'XN' NIPPLE I 13845 '~- ' _1 (OTIS) (3.813' ID) I , '~ i ~ 4.112. WLEG 113848 ', ', ' ELMD I 13847 ___, I PBTD ~ ~ , E LH D 1 q2 6 2 7", 29#L-80 BTRS I 14348 ] ' ''''~ DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9 1-9-91 REB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 1-19-91 5F1"1 PERF'S & TD SEC 14 ; T12N ; RG14E 1 -27-91 C1"11"1 TEST ~2 BP Exploration (Alaska) TREE: 4-1/16" 5000# FMCPT. MclNTYRE ¢/9KB. ELEV=40.0' WELLHEAD: 13-5/8" 5000# FMC TES-1-~.3,i GR. ELEV= 2.0' ACTUATOR: OTIS I ~-' SSSV LANDING ' 13-3/8", #/ft, I NIPPLE 2096 L-80, BTRS i i--- (OTIS)(3.813' ID) I ~ 'lk GAS LIFT MANDRELS 2990 'CAk CO WITH Fi K LATCH3 ~ N~ MD(BKB} TVDss ! 6 3533 2964 KOP: 500' ' 5 7516 5253 MAX ANGLE: 59.4 4 10094 6711 3 11217 7364 2 12302 7999 4-1/2", 12.6#/ft, L-80 TUBING 1 ;'~' 1 12995 8463 TUBING ID: 3.958 - I CAPACITY: 0.0152 BBL/FT I i 4-1/2" 'SWS' NIPPLE (PARKER) (3.813" ID) t~t TUBING SEAL ASSY. 113039 ~;~ ~;~ 9-5/8" PACKER I I i' ( OTIS )( 3.850 "ID) I 13057 I II I 4-1/2-'sws- NIPPLE I TOPOF7. LINER 13113 ~7 ' · i~ (PARKER) !3.813"1D) I 13115 I I =1 II-- 4-1/2' 'SWS NIPPLE 'I I (PARKER)(3.813" ID) I 13136 I 9-5/8", 47#/ft, ~/,_l_ 4-1/2" Tubing Tail L-80, NSCCI134°9I ~ /k, (bottom) ELMD I 1:3150 I EINOTE: WD PACKER HAS SLIPPEDA PERFORATION SUMMARY~[~TOTAL OF 22 FEET DOWN THE REF: LOG: BASELINETEMP/PRESS1/7/91 TOLE. NE.Vt LOCATI.ON IS SHOWN SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13714-13724 OPEN '-~ f'-'l 4-1/2" 'X' NIPPLE I 3 3/8 6 13840-13860 OPEN I I '"Jl'"'"-'"-- ( OTIS ) ( 3.813" IDI13841I ~ (OTIS (3.813" ID)I ~'""'"'~ 4-1/2 WLEGI 13848 I ELMD I 13847I I 7",29# L-80 BTRS I 14348 I DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9, 1-9-91 RRB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 l- 19-91 SFM PERF'S & TD SEC 14 ;T12N ; RG14E 1-27-91 CMM TEST ~3 BP Exploration (Alaska) GAS LIFT MANDRELS 'OAk CO WITH Fi K LATCHI N" MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 1 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13714-13724 OPEN 3 3/8 6 13784-13810 OPEN 3 3/8 6 13840-13860 OPEN TREE; 4-1/16" 5000# FMCPT. MclNTYRE ~/9KB. ELEV =40.0' WELLHEAD: 13-5/8" 5000# FMC TEST~!4 GR. ELEV= 2.0' ACTUATOR: OTIS ~ SSSV LANDING NIPPLE I2096 13-3/8", #/ft, NJ,F (OTIS)(3.813" ID) L-80, BTRS I j k GAS LIFT MANDRELS 2990 CAIV CO WITH FIK LATCH~ N-° MD(BKB): TVDss 6 3533 " 2964 KOP: 500' ! 5 7516 5253 4 10094 6711 MAX ANGLE: 59.4 L 3 11217 7364 2 12302 7999 1 12995 8463 4-1/2", 12.6#/ft, L-80 TUBING . TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT I i 4-1/2" 'SWS' NIPPLE -'--~"(PARKER) (3.813" ID) I 13022 i ' ( OTIS )( 3.850 "ID) 13057 TOP OF7~ II. 4-1/2-'sws" NIPPLE I I I_[_ 4-1/2" 'SWS' NIPPLE I I ! (PARKER)(3.813" ID) I 13136 I 9-5/8", 47#/ft, 1 ~, (bottom) ' l- -- MARKER JOINT I 13593 EI NOTE: WD PACKER HAS SLIPPEDA PERFORATION SUMMARY~]TOTAL OF 22 FEET DOWN THE REF: LOG: BASELINE TEMP/PRESS1/7/91 . ~HOLE. NEW LOCATION IS SHOWN SIZE SPF INTERVAL OPEN/SQZ'D / ;3 3/8 6 13784-13810 OPEN '-~ /'-1 4-1/2" 'X' NIPPLE ! 33/8 6 13840-13860 OPEN i, , ..1..------"'- ( OTiS ) ( 3.813. iD 1138411 '! I~, ~ 4 1/2" 'XN' NI.P. PLE 13845 , I I PBTD ~ ' ;~,,,',~~ ELMD 114262' I I I DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9 1-9-91 REB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 1- 19-91 SFM PERF'S & TD SEC 14 ;T12N ; RG14E 1-27-91 CMM TEST ~4 BP Exploration (Alaska) GAS LIFT MANDRELS CAIV CO WITH FIK LATCH~ N-° MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 1 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13646-13769 OPEN 3 3/8 6 13784-13810 OPEN 3 3/8 6 13840-13860 OPEN TREE: 4-1/10" 5000# FMC PT. MclNTYRE #9 KB. ELEV =40.0' WELLHEAD: 13-5/8" 5000# FMC TEST~,~5 GR. ELEV= 2.0' ACTUATOR: OTIS =--' SSSV LANDING 13-3/8", #/fi, O NIPPLE I2096 L-80, BTRS ~ ! (OTIS)(3.813" ID) I I (~AI~ICO WITH FIK LATCH~ N~ = MD(BKB) TVDss 6 ~ 3533 2964 KOP: 500' ' 5 7516 = 5253 MAX ANGLE: 59.4 ~ = 4 i 10094 6711 ! 3 i 11217 7364 !' -- 2 i 12302 7999 ~ I ' 12995 8463 4-1/2", 12.6#/ft, L-80 TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT I i --:~ 4-1/2" 'SWS' NIPPLE ! (PARKER) (3.813" ID) I 13022 I f t '-- TUBING SEAL ASSY' I 13039 I ~;~ ~;~ 9-5/8" PACKER (OTIS )( 3.850 "ID) I 13057 7" LINER I 13113 ~ i ! I-- I ( PARKER )( 3.813" ID) 13136 , ,--- 4-1/2" Tubing Tail I 13148 9-5/8", 47#/ft, L-80, NSCC I13400 I~ "~ k (bottom) I REF: LOG: BASELINE TEMP/PRESS1/7/91 IBP CENTER ] 377G ;SIZE SPF INTERVAL OPEN/SQZ'D !3 3/8 6 13646-13769 OPEN~ NOTE' WD PACKER HAS .SLIPPED 3 3/8 6 ! 13784-13810 OPEN* APPROX 22 FEET DOWN THE HOLE. .i i I I -"~ 4-1/2" 'X' NIPPLE ~Perfs I I !~ open I ! -. (OTIS) (3.813" ID I 13841 I ~ut isolate¢ ! below IBP ' ', 4-1/2" 'XN'NIPPLE I 13845 I : ~(OTIS ) (3.813" ID) PBTD I 14268 I ,,,,,,,,,,,,. DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9 1-9-91 REB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 l- 19-91 SFM PERF'S & TD SEC 14 ; T12N ; RG14E 1-27-91 RWJ TEST ~5 BP Exploration (Alaska) GAS LIFT MANDRELS (~AI~ICO WITH FIK LATCHI N'~ MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 I 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D ~3 3/8 6 13646-13769 OPEN 3 3/8 6 13784-13810 OPEN* 3 3/8 6 13840-13860 OPEN* ~Perfs open ~ut isolate¢ below IBP TREE: 4-1/16" 5000// FMCPT, MclNTYRE #9KB. ELEV =40.0' WELLHEAD: 13-5/8" 5000# FMC ~ GR. ELEV= 2.0' ACTUATOR: OTIS ~ SSSV LANDING NIPPLE I2096 I 13-3/8", #/ft, ~ (OTIS)(3.813" ID) L-80, BTRS I I j ; ~, GAS LIFT MANDRELS 299O I I '(:;AI~ ICC WITH FK LATCH~ N-° MD(BKB) TVDss ! 6 3533 2964 : KOP: 500' 5 7516 5253 4 10094 6711 MAX ANGLE: 59.4 3 11217 7364 2 12302 7999 ~, 1 12995 8463 4-1/2", 12.6#/ft, L-80 TUBING ' TUBING ID: 3.958" ~ CAPACITY: 0.0152 BBL/FT I I ~ 4-1/2" 'SWS' NIPPLE I Ii (PARKER) (3.813" ID) 13022 ~;~ ,~;~~ 9-5/0" PACKER ( OTIS )( 3.850 "ID) I 13057 I I I~-~2" 'sws-NIPPLE I TOP OF I I_L 4-1/2" 'SWS NIPPLE I I i/ (PARKER)(3.813" ID) I 13136 ; ' ~-l-- 4-1/2" Tubing Tail I 13148 9-5/8", 47#/ft, ! ~, (bottom) PBTD @ 13,750'~, .' I--- MARKER JOINT I 13593 Note-2.5' Fish on top o¢ I:1 BAKER PERMANENT IBP z,e)~ H / TOPFiSHiNGNECK i ]377] (CTU fishing neck/washout noz , ~ PERFORATION SUMMARy ~?:!i.'.$]~::iii!~ IBP CENTER I 13776 REF: LOG: BASELINETEMP/PRESS1/7191 ~ IBP ]~ ' SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13646-13769 OPEN "r NOTE: WD PACKER HAS 5LIPPED / 3 3/8 6 ! 13784-13810 OPEN* I APPROX 22 FEET DOWN THE HOLE. 133/8 6 13840-13860 OPEN* -. .~1 NFW ~ OCATION' IS SHOWN ~ ' I --'"' 7' OTIS ~VD"PACKER,I I I Ii ~ 4-1/2" 'X' NIPPLE , ~)Utbelowi so lat e¢lBP ~ ~. ,~N (OTIS)4-1/2 'XN(3.813.NIPPLEID) I 1 38 45 ~! ~4-1/2"WLEG I 13848 I PBTD I 14268 I ; ; ' I 7", 29#L-80 9TRS I 14348 I DATE REV. BY COMMENTS WELL:Pt MclNTYRE #9 1-9-91 REB PUT ON MAC (42-02-12-14) APl NO: 50-029-22096 I-19-91 SFM PERF'S & TD SEC 14 ;T12N ; RG14E 1-27-91 RWJ TEST ~6 BP Exploration (Alaska) GAS LIFT MANDRELS '(;AI~CO WITH FK LATCH~ No MD(BKB) TVDss 6 3533 2964 5 7516 5253 4 10094 6711 3 11217 7364 2 12302 7999 1 12995 8463 SIZE SPF INTERVAL OPEN/SQZ'D 3 3/8 6 13646-13769 OPEN 3 3/8 6 13784-13810 OPEN* 13 3/8 6 13840-13860 OPEN* ~Perfs open but isolate( below IBP PT MCINTYRE #9 POINT MCINTYRE ~/9 WELL TEST REPORT TEST #1 11840-860' MD BP EXPLORATION RECEIVED APi:~ 2 2 1991 OPERATION: 1/18/91 0900 1100 1250 1420 1900 PT MOINTYRE #9 TEST #1 - 11,840-860' AbMD0il & Gas Cons. Commission Anchorage Well status prior to perforating: 10# completion brine app to lowest GL mandrel. Diesel to surface. Underbalance 1100 psi. RU SWS RIH with Gun #1. Tie in to Baseline Temp/Press Icg of 1/14/91. Fire Gun #1. POH. RIH w/Gun #2. Note WD Packer has dropped 17'; POH, Gun #2 aborted. RDMO; SIWHP 980 PSI. 1/19/91 RU Otis. RIH wi plug. Set plug and POH. RU hot oil unit. Pressure up to 4000. WHP holding (app 60 mins), bleed to 2000 psi. RD hot oil unit. RU Otis Wireline. RIH w/equalizing prong, latch plug and POH. RDMO. 1/20/91 Suspend operations, waiting on weather. 1/21/91 073O RU SWS. SIWHP=1150 psig. RIH with GR/HP/CCL/HUM/GRADIO. Find Diesel/Water interface at 11580 MD. Measure BHP at 8800 TVDss = 4312 psia. Create new tie in Icg. Find WD packer moved down the hole another 3 feet since perforating. Park tools with HP at 13850 MD and HUM at 13841 MD. Prepare to flow well. 1/22/91 0115 0400 0530 Relog rathole, WD, Perfs, and CCH. Find diesel/water interface at 10120 MD. RD SWS. RU Little Red. Pump 11 bbls diesel at 3500 psi (freeze protect). RD Little Red. Secure well. TIME CHOKE RATE W/C WHP CUM DSL COMMENTS (HR) (64TH) (BPD) (%) (PSIA) (BBLS) 1/21/91 1430 closed 1150 0 open Well at 1430 1433 3 2 0 diesel 113.7 0 Liquid to sudace 1445 32 349.92 diesel 7.05 2.91 1500 32 200.64 diesel 8.35' 5.00 1530 32 200.40 diesel 8.2 9.18 1600 32 80.16 diesel 6.77 10.85 1630 32 116.4 diesel 6.5 13.28 1700 32 140.28 diesel 6.7 16.2 ' 1730 32 140.28 diesel 7.42 19.12 1800 32 120.48 diesel 6.03 21.63 1830 32 100.32 diesel 4.8 23.72 1834 closed 2.5 23.72 Shut-in well for PBU - ' i itCROFILHEDa :el POINT MCINTYRE ~9 WELL TEST REPORT BP EXPLORATION PT MCINTYRE #9 TEST #1 11840-860' MD PERFORA'nNG RECORD 3-3/8" Hyperjet II, 6 SPF, 60° phasing, random orientation, 41B charges, 13,840-13,860' MD Ref Baseline Temp/Press log. Shot with 1050 psi underbalance. SUMMARY OF OPERATIONS: Run in hole with pressure, temperature, holdup meter, and gradiomanometer. Measure static reservoir pressure. Open well to flow. Flow 24 barrels diesel load fluid to tanks for four hours. Shut in well for app 5.5 hour PBU. Pull out of hole. Bullhead diesel down tubing: injectivity 0.1 BPM at 3500 psi. Pumped 11 bbls diesel, underbalance 1050 psi. Page 2 POINT MClNTYRE #9 WELL TEST REPORT BP EXPLORATION OPERATION: PT MCINTYRE WELLTEST- TEST #2 13,784-810; 13840-860 1/22/91 1300 RU SWS. SIWHP -- 950. RIH with Gun #1/1A. Tie in to Baseline Temp/Press log of 1/14/91. 1811 Bleed off WHP to tank. 1830 Fire gun#l, 13804-810. Flow well. 1845 Fire gun#lA, 13,784-804, continuing to flow well. 1915 SI Well. POH. 2130 Flow well. 1/23/91 1400 RU SWS. RIH with 3.5" Fullbore Spinner, temp, HUM, Gradio, CCI, GR. Log while RIH. At 1530 hrs, find transition from brine to water occuring at 2000 ft MD. Observe the following gradient info while RIH: MD TVDSS PSIA Temp Gradient 0 0 38 2118 2000 1000 47 0.48 3592 3000 1444 61 0.44 5317 4000 1850 78 0.414 7104 5000 2342 98 0.492 8798 6000 2775 118 0.433 10585 7000 3133 138 0.358 12302 8000 3553 166 0.420 13434 8800 3954 1 86 0.501 2200 psi. Interface observed while RIH corresponds well with where bottoms up should be based on tank straps. MIRU Hot Oil pump truck. Freeze protect flowline with MEOH. Bullhead 140 bbls. diesel down tubing to underbalance well 1000 SI well. Page 1 POINT MCINTYRE #9 WELL TEST REPORT PT M(~INTYRE WELLTEST- TEST #2 13,784-810:13.840-860 Page 2 BP EXPLORATION PRODUCTION DATA TIME CHOKE RATE W/C WHP WHT CHLORIDE CUM LIQ COMMENTS (HR) (64TH) (BPD) (%) (PSIA) (DEGF) (PPM) (BBLS) 1/22/91 1807 bypass 955 46 0 Open well 1830 18 80 Diesel 55 31 1.7 Fire gun #1 1845 18 401 Diesel 18 29 4.2 Fire gun #lA 1900 18 321 Diesel 161 24 7.5 Flow well 1915 18 601 Diesel 157 23 15.5 Shut-in well. POHwith guns 2130 18 0 Diesel SI P = 871 Open well to flow 2200 18 500 Diesel 225 24 34 2400 22 400 Diesel 25 25 61 1/23/91 0200 22 321 Diesel 22 26 90 0400 22 262 Diesel 19 27 115 0600 22 200 Diesel 15 27 136 0800 22 361 Diesel 1 2 29 153 1000 22 28 Brine 28 31 166 Brine to sudace 1100 14 80 Brine 234 33 1 69 Small gas kick. Reduce choke 1200 24 160 Brine 15 26 173 Increase choke 1300 24 160 Brine 15 26 180 1500 32 200 Brine 24 25 220,000 195 Increase choke. 1700 32 200 Brine 27 25 229,000 216 1800 36 200 Brine 20 25 130,000 1900 36 200 Brine 36 26 233 2000 36 210 Brine 27 25 35,000 2100 36 220 100% 18 25 251 2200 36 160 100% 23 25 25,000 2232 36 160/0 100% 24 25 264 Shut-in well PT MCINTYRE WELLTEST-TEST Page 3 POINT MCINTYRE ¢f9 WELL TEST REPORT #2 13.784-810' 13.840-8§@ BP EXPLORATION, PERFORATI~ RECORD 3-3/8" Hyperjet II, 6 SPF, 60° phasing, random orientation, 41B charges, 13,784-13,810 MD Ref Baseline Temp/Press log. Shot with 1050 psi underbalance. SUMMARY OF OPERATION~: Flow well to reduce WHP and increase underbalance. Perforate well. Flow 30 minutes at 300 BPD increasing to 600 BPD. SI well to POH. Flow well overnight and next day and get bottoms up. Run production logs. Freeze protect flowline. Bullhead diesel back down well to underbalance well 1000 psi for next perf job. POINT MCINTYRE ~J WELL TEST REPORT BP EXPLORATION OPERATION: 13.840-860 1/24/91 0830 1130 1145 1245 1330 1500 1730 POINT MCINTYRE #9 WELLTEST TEST #3 13.714-724; 13,754-810; RU SWS. RIH With 3-3/8" Gun. Tie in to Baseline Temp/Press log 1/14/91. Flow well to underbalance well. SI well to shoot. SIWHP 350 psi when gun fired. Underbalance was 650 psi. Flow well. SI well to POH. POP. RU SWS RIH with GR/CCL/HUM/FBS/Petal basket flowmeter/Gradiomanometer. TIME WHP WHT CHOKE LIQ RATE CUM LIQ* COMMENTS (HR) (PSIA) (°F) (64th) (BPD) (BBLS) 1/24/91 1330 909(SI) 51 12 0 0 1430 179 40 16 681 32 1530 89 40 18 621 60 1630 34 39 24 681 86 Chk changed @1615 hrs 1730 229 38 26 1262 127 Chk changed @ 1715 hrs 1830 94 48 26 20 134 1930 143 35 32 180 138 Gas Gravity 0.761 2000 162 36 40 441 147 2100 20 35 44 281 168 2200 62 30 40 381 184 2300 24 38 44 651 211 2400 40 34 44 371 227 1/25/91 0100 62 38 44 501 248 0200 65 37 44 401 273 Petal Basket Station Summary: Station RPS Depth, MD 13,812 2.0 13,759 10.75 13,679 19.3 SUMMARY OF OPERATIONR: Perforate interval from 13,714-724' MD. Unable to unload well and stabilize. Run production log suite and opened petal basket flowmeter between each set of perfs and above all three. Preliminary production total to surface from 1130 hrs on 1/24/91 to 0219 hrs on 1/25/91 indicated total of 273 bbls liquid produced; 140 bbls load diesel, 71 bbls oil, and 62 bbls water. Page 1 POINT MCINTYRE ~ WELL TEST REPORT BP EXPLORATION OPERATION' POINT M(;INTYRE #9 WELLTEST TEST #4 13.646-769: 13,784-810: 13840-60 0915 0950 1130 1320 1535 1800 1900 2200 1/25/91 0200 RU SWS. P-test lubricator to 3000 psi. SI well. RIH with 3-3/8" tandem guns. SIWHP -- 400 psi. Open well. Tie in to Baseline Temp/Press log 1/14/91. FWHP = 75 psi. Perforate 1/1A at 13724-44 and 13744-54. Flow well for 45 minutes and POH. With well SI, RIH with tandem guns. Unable to get below 712' MD. POH. Open well to flow and warm up. SI well. RIH w/Guns 2/2A. Flow well at FWHP--100 PSI. Fire Guns 2/2A. Flow well for 8 minutes, SI, and POH. Once at surface, flow well at 400 psi FWHP. SI well, RIH w/Guns #3/3A. Can't get below 2000 ft. POH- very stiff fluid in tbg. POP thru separator. Thick, viscous fluid coming back. MIRU Hot Oil pump truck. Bullhead 80 bbl diesel down tubing. Last 40 bbls pumped away at approx 0.6 BPM @ 2800 psi RIH with guns #3/3A. SIWHP -- 800 psi. Tie in and open well. Fire guns 3/3A w/well flowing, FWHP = 220 psi. Flow well for 3 minutes and SI. POH. 1/26/91 021 5 RIH w/Guns 4/4A. Tie in to Temp/Pressure log. SIWHP -- 810 psi. Open well and lower WHP to 230 psi. Fire Guns 4/4A. Flow well 4 more minutes and SI. POH. O8OO Run HP gauge/temp/gradio in hole for cleanup operation. Winds picked up to 40-55 MPH. Suspend operations indefinitely. Flow summary: Flowed a total of 206 bbls of fluid during perforating from 0200 1/25 to 0420 hrs on 1/26/91. This included 29.2 bbls diesel flowed back, leaving 51 bbls of diesel in well. PRODUCTION DATA telex. No detailed information kept on production during perforation operations summarized on this 1/26/91 2330 RIH with SWS tools still in riser. SWHP 735 psi. fire up steam boiler. Frozen valve. Repair. RIH with Sampler/CCL/GR/Gradio/H P. Get on bottom, attempt to 1/27/91 0 7 3 9 Flow well, unloading diesel. Record BHP. 1 640 Production log interval. Page I POINT M¢INTYRE #9 WELL TEST REPORT Bp EXPLORATION POINT MC:INTYRE #9 WELLTEST TEST #4 13.646-769; 13.784-810' 13840-60 Page 2 1 81 0 POH with SWS. RD. 2200 RU ACT108 coiled tubing. Fill/PT coil. RU Halliburton N2. 01 40 RIH with 2.5" CTN/2 CV's. 1/28/91 0155 Begin jetting at 1000 ft while RIH. 0300 Jet from 5300 MD = 4000 TVD at 350 SCFM. 0620 Jet from 7104 MD = 5000 TVD 1200 Jet from 8798 MD = 6000 TVD TIME WHP WHT Q-EXE RATE CUM WTR CUT C.,Otv~ENTS (HR) (PSIA) (°F) (64 t h) (BFPD) FLUID ( % ) (BBLS) 1/27/9 1 0739 735 63 0 0 0 Open well 0800 717 35 16 1090 16(Dsl) 0900 403 38 20 682 44(Dsl) Choke setting chg @919 Hrs 1 000 14 7 3 4 2 4 1 58 50 ( D s I) Choke setting chg @950 Hrs 11 00 1 09 3 5 3 0 5 2 3 * 51 ( D si) Choke setting chg @1050 Hrs / 17' 1200 77 32 40 761 49* Choke setting ch,(] @1123 Hrs 1300 77 34 40 531 71 * 1400 96 36 48 641 98* 1500 7 7 3 9 5 6 61 I 1 23 * Choke setting chg @1543 Hrs 1600 50 40 56 641 150' 1700 68 41 56 762 182' 1 800 5 5 4 3 5 6 731 21 3 * 8 9 POH SWS HP gaucje 1900 49 43 56 590 237* 85 2000 25 44 56 892 274* 50 2100 58 43 56 701 303* 80 2200 72 42 56 721 334* 39 2300 40 43 56 1092 379* 90 POINT MCINTYRE ~) WELL TEST REPORT POINT MCINTYRE #9 WELLTEST TEST #4 13.646-769: 13.784-810:13840-(i.0 Page 3 TIME WHP WHT Ci-[3KE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64 t h) (BFPD) FLUID ( % ) (BBLS) 2400 76 43 56 541 402* 15 1/28/9 1 0100 44 43 56 641 428* 70 Begin N2 lift @ 0155; 4000' 0200 1 77 4 3 5 6 741 45 9 * 75 Assumes 0.38 psi/ft gradient below N2 point. 0300 21 6 44 44 1172 508* 55 0400 212 44 44 710 538* 60 0500 178 44 44 913 576* 35 0600 182 4 3 4 4 902 61 3 * 4 0 Move N2 lift @ 0616; 5000' 0700 214 45 44 922 652* I 7 0800 194 45 44 902 689* 1 0 0900 157 47 60 941 728* 1000 92 44 60 821 791 * 1100 177 49 60 821 825* 1200 124 48 60 1423 884' Begin flow to tanks on 4 hour intervals, strap with kolor kut to get cum oil and water for the period. Move N2 lift @ 1200; 6000' 1300 172 49 60 841 919' 1400 1002 961 * 20 BP EXPLORATION * These cum rates are total liquid after diesel unloaded-no oil water split due to not going through separator. BP EXPLORATION- POINT MCINTYRE ~) WELL TEST REPORT POINT MCINTYRE #9 WELLTEST TEST #4 13.646-769: 13,784-810; 13840-6_n Page 4 PERFORATION SUMMARY: Perforations 1/1A through 4/4A opened entire interval from 13,646-13,769' MD (6 SPF), 1/25-26/91.. Individual gun depths · Guns 1/1A: at 13724-44 and 13744-54. Guns 2/2A:at 13696-706 and 13676-96. Guns 3/3A:13,754-13,769' /13,706- 13,714'. Guns 4/4A:13,666-13,676 and 13,646-13,666'. POINT MCINTYRE #9 WELL TEST REPORT OPERATION: POINT MCINTYRE #9 WELLTEST TEST #5 13,646-769 1/28/91 1 9 0 0 SI well. POH 2050 RIH w/Baker permanent IBP. 2200 Set IBP. POH. 1/29/9 0100 0230 0330 0530 0600 1200 1 OOH; RDMO ACT; SI well. RU Otis wireline to dump bail sand on IBP. RI H. Hung up at 3500'; POH to add weight. Suspend operations due to high winds. RD Otis. Freeze protect surface facilities w/MEOH and pump 30 Bbls diesel downhole (0.5 Bbls/min @ 1700 psi. Freeze protection completed. Wait on weather from app. 1200 on 1/29/91 to 1000 on 1/31/91. 1/31/91 11 00 RU Otis WL. RIH w/slickline for TD run. Tagged bridgeplug center at set depth (+/-), w/center of bridge plug at 13,776, top of fishing neck at 13,771'. 2/1/91 0500 0545 2/2/91 0200 0900 POOH w/dump bailer. Finished dumpbailing 5' sand on IBP w/top at 13,771'. Open well. Well cleaning up - BS&W at 10% Open choke to maximize stabilized rate Continue flowing to stabilize Prepare to open well. 2/3/91 0800 1530 1550 1720 1810 1845 Well stabilized at 109 psig, 700 bpd; wait on weather to RU SWS (~60° below zero) Initiated flow to surge tank. Surge tank operated at about 20-25 psi. Flare ignited. Line from surge tank to tank farm frozen. Resume flow directly to tanks. Initiated flow through separator. Flare ignited. BP EXPLORATION Page I POINT MCINTYRE ~ WELL TEST REPORT BP EXPLORATION POINT M¢INTYRE #9 WELLTEST TEST 5 1:3,646-769 Page 2 2/4/91 0000-2400 Flowed well at stabilized rate. Waited on weather to warm above -40 F to R/U SWS to run production logs and HP gauge for PBU. 2/5/91 0230 0700 0800 0130 023O R/U SWS. RIH w/Gradio/HUM/Full bore spinner/Temp/Pedal Basket Spinner/Gamma Ray/CCL/HP & strain gauge. SWS reached TD. Monitored BHP - approx. 2176 Psi Drawdown at perfs (0.33 Stb/D/Psi PI). Ran 40' Down/Up pass w/Full bore spinner. Unable to resolve flow contributions due to fluid fallback. Gradio/HUM indicate water in weelbore from 13,714' MD. Waited to let BHP stabilize to run full production suite Ran full production suite w/ 40/60/80/100 fpm Up/Dwn Fullbore Spinner passes. Spinner still unable to resolve flow contributions due to fluid fallback. Ran Pedal basket spinner beginning at 13,756' w/stops every 5' to top of perforations. Contributions vs. depth detailed in table below. Set HP gauge at mid-perfs. Flow well until 2/6/91. SI well for 72 hr PBU @ 17:00 Hrs. POINT MCINTYRE #9 WELL TEST REPORT BP EXPLORATION POINT MCINTYRE #9 WELLTEST TEST 5 13,646-769 Page 3 Petal Basket Spinner Survey Spinner Velocity, Station Depth RPS % Total Flow 13,756 3.2 13.3 13~750 4.8 20.0 13~745 6.0 25 13r740 6.5 27 13,735 8.6 35.8 13~730 8.8 36 13,725 10.1 42 13,720 11.5 47.9 13,715 11.6 48 13r710 17.8 74 13,705 19.3 80 13,700 20.0 83 13~695 20.2 84 13~690 20.9 87 13,685 22.1 92 13~680 22.5 93.7 13,675 23 95.8 13~670 22.0 91.7 13~665 22.4 93.3 13,660 23.0 95.8 13,655 23.7 98.8 13r650 23.9 99.6 13,645 23.7 98.8 13,640 23.8 99.2 13,620 24.0 100 POINT MCINTYRE ~ WELL TEST REPORT BP EXPLORATION POINT MCINTYRE #9 WELLTEST TEST Page 4 13,646-769 TIME WHP WHT CHOKE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64th) (BFPD) FLUID (%) (BBLS) 2/1/91 0545 808 28 32 0 0 0600 267 27 40 2525 26.3 Choke to 40/64ths at 0548 0630 13 25 52 581 38.4 0 Choke to 52/64ths at 0616 Well SI 0700 13 32 36 128 39.2 Choke to 36/64ths at 0628 0730 10 40 36 0 39.2 0800 128 40.0 Well SI 0830 43 36 36 0 0900 41 33 36 120 41.7 0.2 0930 34 34 36 120 44.2 1000 32 34 36 401 52.6 1030 31 34 36 202 56.8 0.5 1100 47 32 36 441 66.0 90 1130 101 34 36 1002 86.9 5.0 1200 61 32 36 202 91.1 1230 31 33 44 521 102.0 Choke to 44/64ths at 1219 1300 43 33 44 0 102.0 1330 25 35 44 281 107.8 0 1400 151 33 44 681 122.0 1430 14 37 44 202 126.2 21 1500 12 37 44 240 131.2 1530 169 33 44 561 142.9 1600 12 36 44 240 147.9 60 1700 36 34 44 240 157.9 75 1800 13 37 44 502 178.8 40 1900 26 34 44 391 195.1 60 2000 41 33 44 691 223.9 35 2100 31 34 44 672 251.9 20 2200 176 36 44 470 271.5 25 POINT MCINTYRE ~ WELL TEST REPORT POINT MCINTYRE #9 WELLTEST TEST 5 13,646-769 Page 5 TIME WHP WHT CHOKE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64th) (BFPD) FLUID (%) (BBLS) 2300 25 35 44 180 279.0 2400 67 36 44 742 309.9 20 2/2/91 0100 118 37 44 401 326.6 40 0200 154 37 44 821 360.8 10 0300 116 37 44 710 390.4 1 0 0400 124 37 44 622 416.3 8 0500 118 37 44 650 443.4 6 0600 126 37 44 641 470.1 8 0700 113 37 44 600 495.1 5 0800 117 37 44 622 521.0 3.5 0900 122 38 52 641 547.7 2 Choke to 52/64ths at 0915 1000 75 36 52 521 569.4 4 1100 82 35 52 761 601.1 1 1200 138 37 52 782 633.7 1300 124 37 52 60 636.2 0 1400 88 35 52 802 669.6 0.6 1500 156 38 52 1202 719.7 0 1600 111 37 52 641 746.4 0.2 1700 133 38 52 773 778.6 0 1800 120 38 52 802 812.0 0 1900 136 38 52 710 841.6 0.2 2000 117 38 52 752 872.9 0 2100 117 38 54 701 902.1 0 Choke to 54/64ths at 2109 2200 112 38.5 56 772 934.3 0 Choke to 56/64ths at 2117 2300 114 38.5 56 701 963.5 0 2400 114 38.6 56 721 993.6 0 28.3° APl 2/3/91 0100 93 37.5 56 701 1022.8 0 0200 113 38.7 56 681 1051.2 0 0300 108 38.6 56 721 1081.3 0 0400 110 38.8 56 721 1111.4 0 BP EXPLORATION POINT MCINTYRE #9 WELL TEST REPORT POINT M(;INTYRE #9 WELLTEST TEST 5 13,646-769 Page 6 TIME WHP WHT CHOKE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64th) (BFPD) FLUID (%) (BBLS) 0500 108 38.7 56 681 1139.8 0 0600 108 38 56 711 1169.4 0 0700 108 39 56 721 1199.5 0 0800 109 39 56 691 1228.3 0 0900 108 39 56 752 1259.6 0 1000 108 39 56 681 1288.0 0 1100 108 39 56 691 1316.8 0 1200 105 39 56 722 1346.9 0 1300 108 39 56 622 1372.8 0 1400 107 39 56 701 1402.0 0 1500 109 39 56 761 1433.7 0 1600 111 39 56 666 1461.5 0 1700 104 39 56 773 1493.7 0 1800 114 39 56 595 1518.5 0 1900 112 39 56 481 1541.9 0 2000 118 39 56 641 1568.6 0 2100 119 39 56 762 1600.3 0 2200 121 39 56 681 1628.7 0 2300 123 39 56 721 1658.8 0 2400 125 39 56 721 1688.9 0 2/4/91 0100 125 39 56 701 1718.1 0 0200 125 39 56 671 1746.1 0 0300 126 40 56 711 1775.7 0 0400 126 39 56 711 1805.3 0 0500 125 40 56 671 1833.3 0 0600 125 40 56 742 1864.2 0 0700 125 39 56 671 1892.2 0 0800 124 39 56 661 1919.8 0 0900 124 40 56 691 1948.6 0 1000 125 39 56 721 1978.7 0 1100 126 39 56 691 2007.5 0 BP EXPLORATION POINT MCINTYRE ~:J WELL TEST REPORT POINT M¢INTYRE #9 WELLTEST TEST 5 13,646-769 Page 7 TIME WHP WHT CHOKE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64th) (BFPD) FLUID (%) (BBLS) 1200 124 39 56 711 2037.1 0 1300 125 39 56 671 2065.1 0 1400 126 39 5 6 671.3 2093.1 0 1500 124 39 56 701.5 2122.3 0 1600 124 39 56 691.4 2151,1 0 1700 126 39 56 711.4 2180.8 0 1800 123,5 39 56 691.4 2209.6 0 1900 126 39 56 721.4 2239.6 0 2000 125.7 40 56 671.3 2267.6 0 2100 121.8 40 56 681.4 2296.0 0 2200 118.8 40 56 741.6 2326.9 0 2300 119.1 40 56 681.4 2355.3 0 2400 117.7 40 56 741.6 2386.2 0 2/5/91 0100 117.1 39 56 681.4 2414.6 0 0200 120.9 39 56 661.4 2442.1 0 RU SWS @0230. RIH. 0300 107.9 37 56 651.4 2469.3 0 0400 47.4 39 56 210.5 936.1 0 0500 191.4 36 56 150.2 2484.3 0 0600 77.8 35 56 921.8 2522.7 0 0700 70.5 35 56 521 2544.4 0 0800 112 35 56 611.3 2569.9 0 0900 32.0 35 56 1052.2 2613.7 0 1000 84.0 35 56 1122.2 2660.5 0 1100 114.5 36 56 300.7 2673 0 1200 148.7 37 56 150.2 2679.3 0 1300 131.8 37 56 761.5 2711.0 0 1400 131.8 37 56 631.2 2737.3 0 1500 102.0 36 56 791.5 2770.3 0 1600 37.7 36 56 470.9 2789.9 0 1700 99.0 37 56 761.5 2821.7 0 1800 130.9 38 56 531.1 2843.8 0 BP EXPLORATION POINT MCINTYRE ~ WELL TEST REPORT BP EXPLORATION POINT MClNTYRE #9 WELLTEST TEST 5 13.646-769 Page 8 TIME WHP WHT CHOKE RATE CUM WTR CUT COMMENTS (HR) (PSIA) (°F) (64th) (BFPD) FLUID (%) (BBLS) 1900 122.5 38 56 681.4 2872.2 0 2000 99.7 37 56 551 2895.1 0 2100 104.2 38 56 731.5 2925.6 0 2200 68.7 38 56 651.4 2952.8 0 2300 96.9 37 56 681.4 2981.2 0 2400 131.1 38 56 659.3 3008.6 0 2/6/91 0100 86.4 37 56 621.4 3034.5 0 0200 79.2 37 56 653.3 3061.7 0 0300 84.8 37 56 641.3 3088.5 0 0400 97 37 56 591.1 3113.1 0 0500 108.1 37 56 679.7 3141.4 0 0600 110.2 37 56 601.2 3166.5 0 0700 118.7 38 56 671.3 3194.4 0 0800 126.4 37 56 671.3 3222.4 0 0900 121.4 37 56 661.4 3250 0 1000 122.6 37 56 611.3 3275.4 0 1100 99.8 37 56 581.3 3299.6 0 1200 91.8 37 56 691.4 3328.5 0 1300 102.9 36 56 641.3 3355.2 0 1400 123.1 36 56 651.4 3382.3 0 1500 105.9 36 56 721.4 3412.4 0 1600 127.2 36 56 651.4 3439.5 0 1700 124.3 37 56 631.2 3465.8 0 Shut in well @ 1700 hrs. . P~dhoe Bay Stimulation " Ernulsion / Sludge Test Data Jet .PBOC Engr. File ..._._Anch Slim Group ._.__Anch Centr~,l Fiie Well:_ Zone(s) Treated; Date Oil Sample Received: ARCO Engineer; _ Field Vctumes: Lab Vclumes: ~ ~'/0 ("¢¢._./..- Test Date: ~/~//9// Pre- or Post-Job .Test? Service Co.: /'4~. //1' ~--~p rJro Service Co. E.":gineer:~ APR 2 2 1991 I. Dis:ersi~ty/Sotubility Test Alaska Oil & Gas Cons Co~, a) C'otor I ~ ~ b) Clarity (C[earlC~oudy) ~/¢~ c)~~e~~ (Y/N) I!. Emu!s/on Test Initial Emulsion Volume (mi) Acid Phase Volume (15 rain) Live Acid Phase Volume (30 rain) Acid Phase Volume (,.~ rain) Nnat Ac!d Breakcut (~,,,~N,~o ~ Locaticn cf Fines''~°'° 2 25 mi oil 75 mi acid Spent 50 mi oil 50 mi acid Live' i S~nt 75 mi oil 25 mi acid Livo I Spent Z' <'" 75-, 76 7S- i Note I: FTnal Acid Bre~oul (%} = (Acid Breai,,out Volume / Initial Volume at Ac:d Adcle<:l X 100 where InitiaJ Volume of Ac~d Added should be e~ual to 25. 50. or 75 mt. Note 2: 'A' denotes fines at bottom of graduA~e~l cyiincler and '~' denotes fines at acx:[ / oil interface III. Sludge Test (A) (c) (o) Final Volume of Oil Phase (50150 oil/acid mixture); Filter Paper wt.: Fiiter P~per/Naturat Residue wt.: Natural Residue wt.;. Filter Paper wt.: Filter Paper/Sludge wt.: Sludge wt.; Normalized Residual Sludr. e = C' /,,E:)~' r~rams -- /. Z.Z. grams ~.¢'~ ~rams = A' //-,q orams /.,57-. ~rams ¢.'~9 2rams = B' C' = ( B' - A' ) X (Initial oil vctumeTM -~ / Final oil volume ) = (~). ~FO ~rams.'~o,o, Note 3: Initial oil volume should be 50 mi as required by lesting procedures Note 4: C' < 0.5 grams lo pass sluclge test PAGE I of 2 (Page 2 of 2 is 'l'T~:';r.,n fcrm) B P EXPLORATION PRUDHOE LABORATORY ANALYSIS REPORT SAMPLE: C~-~e 0,' ! LAB #: See ~z/oW FACILITY: ~?. ~4c ~r,,+yr= SOURCE: tt ~ COMMENTS: DISTRIBUTION: , ~,',,%tl E3 ;lc __ ANALYST: DATE: THE ROBERTSON GROUP plc PETROLEU%I DMSION REPORT NUMBER: C1/407 ORiGIIIAI, BP PETROLEUM DEVELOPMENT LIMITED ALASKAN SAMPLES II CONVENTIONAL CORE ANALYSIS REPORT by B. SONDORS F.E. MATHESON A.J. GOODAY RECEIVED APR 1 5 'I99'i Alaska 0il ,& ~Ga, s :Cons,, Comm,i,ssion PROJ£CT NUlVlBER: RGPD/90I/AC/407 Prepared by: Robertson Group plc Petroleum Division Unit 5 Wellheads Crescent Trading Estate Wellheads Industrial Estate Dyce Aberdeen AB2 0GA Prepared for: British Petroleum Research Group Sunbury Research Centre Chertsey Road Sunbury-on-Thames Middlesex TW16 7LN Alaska 011 a ~as Cons. Co~ml$slon Anchorage Gro p INTRODUCTION CONTEl'eTS . METHODS CONVENTIONAL CORE ANALYSIS DATA - ALASKAN SAMPLES STATISTICAL ANALYSIS - ALASKAN SAMPLES - Histograms Statistical Summary for Horizontal Permeability (Air) Statistical Summary for Helium Porosity - Crossplots Helium Porosity Vs Horizontal Permeability (Air) 5. RAW DATA SHEETS - ALASKAN SAMPLES / ,,}Roberlson Group ptc ABBREVIATIONS a/a abun AGG ang arg B(IT) bd biocl biomld biotb calc CALT carb CGL CHK CHT cl CLYST cmn cm[ cmt(d) crs crp deb dissem DOL f fei riss foss frac frags fri glc grd grns/grnd GYP HAL hd He hot Ub IGN ind lam LIG Ins LST as above abundant agglomerate angular anhydrite ar~l~ac~ous bkumen/bituminous bedded/bedding bioclastic biomould bioturbated calcareous calcite carbonaceous conglomerate chalk chert clasts claystone common cement cement(ed) coarse cryptocrystalline debris disseminated dolomite/dolomitic f'me feldspatkic fissile fossils/fossiliferous fracture fragments friable glauconite/glauconitic graded/grading to grains/grained gypsum halite hard haematite horizontal interbedded igneous rocks indurated laminae/laminated lignite/lignitic lens(es) limestone Rober son Group pic mass MDST reed MET mie micr min told mn~ mod nat NDP NFS? nod NPP 0C¢ ool ops OS P pb poss pred pyr QTZ(T) S sft SH shly sig sil sks si SLT(ST) slty SND sndy SST st stks styl sucr tr V vis W w/ xln massive mudstone medium metamorphic mica/micaceous micritic mineral mouldic minor moderate natural no data possible no fluid saturation possible nodule/nodular no horizontal plug possible no vertical plug possible occasional oolitic open pore space oil stained poorly pebble possible predominantly pyrite/pyritic quartz(itc) siderite soft shale shaly significant siliceous slickenside surface slight(ly) silt(stone) silty sand sandy sandstone stained streaks stylolite sucrosic trace(s) very visible vein well with crystalline Group pk Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sampls Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP -1 Number ~ Loss & Extracted cc Initially cc Methanol cc ~ cc cc cc co % % pv % pv ! pv (Ka) mD atmos ALASKAN SAMPLES 2-3 139 03 0.01 7 15 SH, mod ind, ccc pyr, lam, si fiss, frac. 400 1X5 132.36 54.94 48.33 6.61 2.71 12.0 - - - FRAC 2-5 133 72 SH, a/a, w/ tr pyr. 1.58 6 70 400 1X5 127.32 47.68 42.65 5.03 2.70 10.6 - - FRAC 2-6 135 32 SH, a/a. 0.03 6 90 400 1X5 128.61 52.29 47.29 5.00 2.72 9.6 - - FRAC 2-7 153 12 0.23 5.95 400 1X5 147.26 54.08 48.06 6.02 3.05 SST med-crs, mod ind, mod pyr, vsl DOL, tr green clay, sl granules, frac. 11.4 99.8 0 0 2 FRAC 2-8 136 39 0.26 6 15 400 SST med, mod tnd, sl pyr, s[ v crs gms, frac. lX5 130.39 54.41 47.78 6.63 2.71 12.2 93.7 0 6 3 FRAC 2-9 162 63 0.09 3.30 400 lX5 158 54 55.94 50.12 5.82 3.16 SST med-crs, patchy arg, w.ind, cmn ?S, sl green clay, tr pyr, sl pb. 10.4 57.3 14.8 27 9 0.22 0 47 2-10 144 47 0.18 3 70 400 SST f, patchy ind, ccc green clay, sl ?S, sl pyr. 1X5 136 88 55.50 46.32 9.18 2.95 16.5 40.7 47.6 11 7 0 96 0 73 2-11 141 99 0.21 6 10 SST a/a, w/ sl granules. 400 1X5 135 43 54.31 47.17 7.14 2.86 13.1 86.3 6.4 7 3 3 59 0 53 2-12 181 26 0.04 1 80 400 1X5 179 04 56.96 54.35 2.61 3.29 SST f, w.ind, v DOL, v ?S, occ green clay, sl crs-v crs gms, part open nat fracs. 4.6 69.7 17.4 12 9 <0 Ol 0 37 ~-. 2-13 135 01 0.20 6 85 400 1×5 SST f-med, mod ind, mod green clay, sl DOL, ccc granules. 128 37 53.29 45.96 7.33 2.79 13.8 94.4 0 5 6 0 67 0 64 2-14 143 41 0.10 7 60 400 IX5 135 81 5G.2~ 48.30 7.97 2.81 SST f-med, mod ind, sl green clay, sl patchy pyr, sl DOL, sl closed nat fracs. 14.2 96.3 0 3 7 0 42 0 57 2-15 135 37 0.20 7 20 400 1X5 128 71 55.03 47.67 7.36 2.69 SST f-med, mod ind, occ green clay, sl carbonate, occ v crs gms-granules. 13.4 98.8 0 1 2 0.74 0 66 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP _ Number ~ Loss g Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv (Ka) mD atmos 1 2-16 172.11 0.06 2.40 400 1X5 SST, f-med, v w.ind, cmn carbonate, mod green clay, sl pyr, frac. 169.42 54.66 51.16 3.50 3.31 6.4 69.2 8 8 22.0 FRAC 2-17 132.14 0.12 6 70 400 1X5 125.23 53.34 46.24 7.10 2.71 SST, f-med, mod ind, occ green clay, sl carbonate, rare granules-pbs. 13.3 95.3 3 6 1.1 O.54 0.61 2-18 162.14 0.26 3 85 400 1X5 156.87 55.57 49.19 6.38 3.18 SST, f-med, mod-w.ind, cmn carbonate, mod green clay, frag calc biocl, si granules, sl chipped. 11.5 60.9 24 6 14.5 CHIP 2-19 130.14 0.08 6.00 400 SST, vf w/ f-med grnd patches, mod ind, si carbonate. 1X5 123 74 54 58 46.40 8.18 2.67 15.0 74.1 4 7 21.2 0,69 ,-~'"~-.66 2-20 132.04 0.02 4 25 SST, f, mod tnd, sl carbonate. 400 lX5 125 67 54 18 47.01 7.17 2.67 13.2 59.9 23 1 17.0 0.32 0.55 2-21 133.17 0.06 5 15 400 SST, f-med, mod tnd, occ green clay, si v crs gms. 1X5 126 32 54 21 46.91 7.30 2.69 13 5 71.3 25 7 3.0 0.25 0.48 2-22 134.16 SST, a/a. 0.09 4 40 400 1X5 128 32 54 50 47.52 6.98 2.70 12 8 63.7 22 7 13 6 0.21 0.46 2-23 129.99 0.11 5.45 SST, a/a, w/ no v crs gms. 400 1X5 123.28 54 51 45.93 8.58 2.68 15 7 64.2 15 7 20 1 1.20 0.74 2-24 136.84 0.02 3.80 SST, a/a, w/ no v crs grns. 400 1X5 131 27 54 91 48.95 5.96 2.68 10 9 64.4 23.3 12 3 0.16 0.42 2-25 136.94 0.05 5.35 400 lX5 SST, a/a. 131 09 54 45 48.22 6.23 2.71 11 4 86.7 8.2 5 1 0.11 .37 2-26 136.51 0.17 4.70 400 1X5 SST, a/a. 130 60 55 O0 48.23 6.77 2.70 12.3 70.1 19.5 10 4 0.26 0.59 2-27A 131.68 0.02 4.55 400 1X5 SST, f, mod ind. 123.20 56 71 46.07 10.64 2.68 18.8 43.2 34.0 22.8 25.7 0.77 2-27B 129.15 0.01 4.30 400 1X5 SST, a/a. 121.28 54 87 45.33 9.54 2.68 17.4 45.5 34.5 20 0 13.8 0.67 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP' -1 Number ~ Loss 5 Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv (Ka) mD atmos 2-27C 131.48 SST, a/a. 0.02 4 45 400 1X5 123.31 56.07 46.26 9.81 2.67 17.5 45.8 36.7 17.5 13.6 0.'67 2-28 133.58 0.22 3.80 400 SST, f-med, mod ind, ccc green clay, ccc v cra gms. 1X5 128.38 53.67 47.40 6.27 2.70 11.7 61.2 24.7 14.1 0.14 0.41 2-29 159.38 0.27 5 10 400 1X5 151.94 56.98 47.55 9.43 3.19 SST, f-mad, mod ind, mod patchy pyr, ccc green clay, sl carbonate, rare granules. 16.5 54.6 34.8 10.6 0.05 0.37 2-30 136.29 0.02 4.65 400 SST, f-mad, mod ind, cmn green clay, sl carbonate, pb. 2-31 138.87 0.19 5 50 400 SST, f-med, mod ind, cmn green clay, mod carbonate. 1X5 131.61 53.17 48.12 5.05 2.74 9.5 93.0 0.5 6.5 0.04 ~'~37 lX5 133 10 54.57 48.48 6.09 2.75 11.2 91.2 4.0 4.8 0.32 0,53 2-32 153.96 0.11 5 25 400 1X5 146 24 56.32 46.83 9.49 3.12 SST, f-mad, mod ind, cmn green clay, mod patchy carbonate, pyr cmtd nat frac. 2-33 141.69 0.07 7 10 SST, med, mod tnd, cmn green clay, mod ?S. 2-34 136.40 0.27 8 O0 SST, med, mod tad, cmn green clay, ccc ?S. 16.9 55.9 28.9 15.2 1.32 0.53 400 1X5 132 70 54.52 43.52 11.00 3.05 18.6 16.2 0.64 0.64 127 51 53.96 44.15 9.81 2.88 400 1X5 2O.2 65.2 18.2 82.4 9.4 8.2 0.71 0.66 2-35 85.87 0.10 3 60 400 1X5 SST, med, mod ind, cmn green clay, cmn ?S, nat frac w/ brown cmting min. 2-36D 164.55 0 8 1 400 1X5 ?SST, med, mod-w.ind, cmn ?S, ccc green clay, sl iron oxide. 81 23 31.26 26.04 5.22 3.12 154 75 55.92 46.27 9.65 3.36 16.7 69.7 12.7 17.6 DAM 17.3 84 8 7.3 7.9 0.03 ~37 2-36E 140.92 0.04 6 3 SST, mod, mod tnd, mod gr~.~.u clay, nl ?S. 400 1X5 75 8 9.5 132 29 53.91 45.52 8.39 2.91 15.6 14.7 0.26 0.50 2-37 147.47 0.19 7 10 400 SST, med, mod tnd, mod ?S, mod green clay, sl pyr. 1X5 138 67 54.30 43.60 10.70 3.18 19.7 67 0 17,3 15.7 1.38 0.54 2-38 159.20 0.24 7 40 SST, a/a, w/ cmn ?S. 400 1X5 151 19 56.24 46.81 9.43 3.23 16.8 79 3 6.5 14 .2 0.05 0.37 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP -1 Number ~ Loss ~ Extracted cc Initially cc Methanol cc ~ cc cc cc cc Z % pv % pv % pv (Ks) mD atmos 2-40 133.44 0.25 8.65 400 1X5 123 42 52.24 40.54 11.70 3.02 SST mod, mod ind, mod ?S, mod green clay, nat fracs w/ brown cmting mtn. 22.4 74.7 12.5 12 8 FRAC 2-41 152.40 SST a/a. 0.08 5.85 400 lX5 145 55 54 57 46 10 8.41 3.15 15.4 70.3 12.7 17 0 0.95 0.70 2-42 119.55 0.04 8.90 400 SST f-med, mod ind, cmn green clay, si carbonate. 2-43 130.08 SST a/a. 1X5 0.04 6.90 400 lX5 107 75 51 09 38 05 13.04 2.83 119 07 53 59 40 78 12.81 2.92 25.5 68.9 24.5 23.9 54.4 26.3 6 6 19 3 8.99 0.az 76.2 ~-~. 90 2-44 127.14 SST a/a. 0.19 6.75 400 lX5 115.76 53 67 39 60 14.07 2.89 26.2 48.5 36.8 14 7 97.4 0.89 2-45 139.73 0.03 7.20 SST s/a, w/ occ ?S. 400 1X5 129.42 54 58 42 04 12 54 3.08 23.0 58.0 19.6 22 4 3.44 0.70 2-46 109.01 SST a/a. 0.11 6.60 400 1X5 100 22 45 79 35 02 10 77 2.86 23.5 61.9 22.4 15 7 8.35 0.83 2-47 125.31 0.21 8.10 SST, a/a, w/ si iron oxide st. 400 1X5 112.82 52 08 37 13 14 95 3.00 28.7 54.7 32.8 12 5 26.4 0.76 2-48 156.35 0.01 5.75 400 SST, f, mod-w.ind, cmn ?S, cmn green clay, si pyr. 2-49 130.36 0.06 5.90 SST, f, mod tnd, mod green clay, occ ?S. 1X5 400 1X5 149 93 54 35 46 83 7 52 3.20 122 25 53 45 41.90 11 55 2.92 13.8 77.2 5.6 17.2 0.02 0.37 21.6 51.6 21.2 27.2 6.45 .78 2-50 139.77 0.17 7.90 SST, a/a, f-med grnd. 400 1X5 125 03 54 31 41.57 12 74 2.99 23.5 62.6 20.5 16.9 9.68 0.82 2-51 146.89 SST, a/a. 0.30 6.85 400 1X5 135 86 54 O1 43.74 10 27 2.86 19.0 67.4 23.9 8.7 1.33 0.59 2-52 133.58 0.03 6.50 SST, a/a, f-med grnd. 400 1X5 124 74 54 82 42.11 12 71 2.96 23.2 51.7 20.3 28.0 45.5 0.83 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP -1 Number ~ Loss ~ Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv {Ka~ mD etmos 3-1 136.66 0.26 SST, e/a, f-med grnd. 4.35 400 lX5 131.05 54.80 45.23 9.57 2.89 17 5 45.9 14.4 39.7 8.05 0.80 3-2 107 18 0.22 5.50 400 SST, f, mod-w.ind, cmn ?S, mod green clay, frac. 1X5 162.00 54.97 49.35 5.62 3.28 10 2 98.1 0.9 1.0 FRAC 3-3 136 47 0.22 5.65 400 SST, f-med, mod ind, cmn green clay, patchy ?S. 1X5 125.83 54.72 42.85 11.87 3.16 21 7 48.1 27.9 24.0 23.7 0.79 3-4 154 43 0.31 5.40 400 SST f-med, mod-w.ind, patchy pyr cmt, cmn green clay. 1X5 144.51 55.54 46.39 9.15 3 10 16 5 59.6 39.9 0 5 8.53 3-5 142 43 0.17 7.30 400 1X5 SST f-med, mod ind, cmn green clay, occ ?S, occ crs-v crs grns. 133.69 55.47 44 07 11.40 3 O1 2O 6 64 7 13.6 21 7 3.63 0.70 3-6 151 24 0.20 7.15 400 1X5 SST med, mod ind, cmn ?S, mod green clay, occ crs-v crs grns. 141.05 55.82 45 01 10.81 3 13 19 4 66 8 14.6 18 6 2.19 0.61 3-7 143 59 SST a/a. 0.11 7.25 400 1X5 134.00 53.97 44 16 g. 81 3 03 18 2 74 6 14 7 0.64 10.7 0.62 3-8 145.71 0.21 5.20 400 1X5 SST f-med, mod tnd, mod green clay, occ ?S, sl broken lam. 137.77 55.28 46 54 8.74 2.95 15 8 60 I 25.7 14 2 1.00 0.60 3-9 144.82 0.13 5.70 400 iX5 SST f-med, mod ind, cmn ?S, occ green clay, occ mid vugs (up to lxlmm) 3-10 136.22 0.21 6.20 400 SST, f-med, mod ind, patchy ?S, si green clay. 136.62 56.57 44 60 11.97 3 05 21 2 125.42 55.72 43 97 11.75 2 85 48 1 21 1 22.4 53 3 29 5 31.0 27.0 0.76 15 7 1X5 .83 11.8 3-11 140.09 0.20 7.50 400 SST, f-med, mod ind, cmn ?S, occ green clay, tr lam. lX5 129.81 54.34 43 20 11.14 3.00 20.5 68 0 16.4 15.6 2.18 0.62 3-12 142.48 0.15 6.30 400 SST, f-med, mod ind, occ ?S, occ green clay. 1X5 127.75 54.28 43 54 10.74 2 93 19 8 59 2 26.1 14.7 3.68 0.71 3-13 130.34 SST, a/a, med grnd. 0.07 5.20 400 lX5 120.62 53.21 41 45 11.76 2 91 22 4 44 7 37.4 17.9 14.6 0.75 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP- -1 Number ~ Loss g Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv (Ka) mD atmo~ 3-14 141.40 SST, a/a. 0.11 5.70 400 1X5 132.89 54.61 44.96 9.65 2.95 17.7 59 7 22 2 18 1 1.36 0.62 3-15 140.03 0.09 5.00 400 1X5 132.84 54.64 46.50 SST, f-med, mod ind, occ ?S, occ green clay, sl lam, sl mld vugs (<2x2mm). 8.14 2.85 14.9 62 0 9 5 28 5 0.88 0.70 3-16 151.94 0.05 2.25 400 1X5 145.32 52.70 45.14 SST, f-med, mod-w.ind, mod patchy pyr cmt, occ ?S, occ green clay, part open nat fracs, frac. 7.56 3.21 14.4 30 1 54 8 15 1 FRAC 3-17 133.84 0.09 2.20 400 SST f-med, mod ind, occ ?S, si green clay. 1X5 126.48 53.87 43.58 10.29 2.90 19.1 21 6 56 6 21 8 69.7 3-18 131 22 SST a/a. 0.40 2.70 400 1X5 122.06 54.34 43.22 11.12 2.82 20.5 24 5 63 7 11 8 165 0.90 3-19 128 96 SST a/a, w/ sl ?S. 0.33 3.05 400 1X5 120 12 55 71 44.06 11.65 2.72 20.91 26.4 54 1 lg 5 435 0.94 3-20 139 14 0.03 SST a/a, w/ occ pyr cmt. 3 70 400 1X5 131 O0 52 86 43.92 8.94 2.98 16.9 41 8 50 7 7 5 FRAC 3-21 141 05 0.01 SST a/a, w/ occ pyr cmt. 4 10 400 1×5 132 28 55 18 45.36 9.82 2.95 17.8 42 2 53 5 4.3 49.1 0.84 3-22 155 81 0.15 SST a/a, w/ cmn ?S. 2 25 400 1X5 3-23 163 44 0.01 3 40 400 1X5 SST f-med, mod ind, cmn ?S, cmn iron oxide st, sl green clay. 151 35 55 07 49.26 157 72 56 17 49.64 5.81 3.06 10.6 6.53 3.18 11.6 42 1 52 6 31 4 34 7 26.5 O. 50 O. 62 12.7 2.09 ~'~'-'62 3-24 143 21 0.09 4 95 400 SST f-mod, mod ind, occ ?S, sl green clay. 1X5 135 19 55 19 45.91 9.28 2.95 16.8 53 9 30 5 15.6 7.02 0.80 3-25 141 84 0.00 3 65 SST a/a, w/mod patchy pyr cmt. 400 1X5 135 06 54 83 45.63 9.20 2.96 16.8 40 1 38 2 21.7 55.8 0.85 3-26 149.75 0.19 3 40 400 1X5 143 50 54 74 46.52 SST f-med, mod ind, cmn patchy ?S, si green clay, part open nat frac, chipped. 8.22 3.08 15.0 418 3O 2 28.0 CHIP Weight on Volume of Volume of Pipette Dry Sample Depreservtn Grain Water Methanol used Volumes of Weight Number ~ Loss g Extracted ce Initially cc Methanol cc ~ 3-27 140.00 0.18 4.35 400 1X5 130.54 SST, f-med, mod tnd, mod patchy pyr cmt, ccc patchy ?S, sl green clay, sl lam. Bulk Grain Pore Grain Volume Volume Volume Density Porosity cc cc cc cc % 56.63 45.54 11.09 2.85 19.6 Water Saturation Oil Saturation Gas Permeability RMP' -I % pv % pv (Ka) mD atmoa 39.6 44 2 16.2 9.63 0.82 3-28 131.94 0.07 SST, a/a, w/ no vis lam. 4.05 400 1X5 123.16 53.06 43.04 10.02 2.86 18.9 40.8 48 3 10.9 51.3 0.85 3-29 171.27 0.21 4.30 400 ?SST, f-med, mod ind, v cmn ?S, ccc green clay. 1X5 165.25 57.22 50.85 6.37 3.25 11.1 68.2 13 3 18.5 0.78 0.69 3-30 149.19 0.00 4.85 400 1X5 143.35 SST, f-med, mod tnd, mod patchy ?S, ccc green clay, ccc patchy dissem pyr. 3-32 169.87 0.30 4.10 400 lX5 164.23 SST, f-med, mod-w.ind, cmn ?S, cmn dissem pyr, ccc green clay, ccc crs grns. 56 05 55 85 48.60 7.45 2.95 13.3 49.39 6.46 3.32 11.6 65,8 84.1 14 4 17 8 19.8 1.52 18.1 0.41 0.66 3-33 154.87 0.17 5.20 400 SST, f, v crs, mod-w.ind, cmn ?S, ccc green clay, frac. lX5 148.50 52 28 45.14 7.12 3.28 13.6 73.8 17 8 8.4 FRAC 3-34 150.09 0.06 5.10 400 1X5 SST, f-med, mod tnd, mod ?S, ccc green clay, part open nat frac. 142 73 55 64 47.01 8.63 3.04 15.5 59,7 20 1 20.2 4.94 0.75 3-37 148.74 0 3.8 400 SST, f-med, mod ind, mod ?S, ccc green clay. 1X5 143 35 56 61 48.75 7.86 2.94 13.9 48.8 22.4 28.8 3.76 0.71 3-38 159.92 0.06 3.85 400 SST, f-med, mod ind, cmn ?S, mod dissem pyr, ccc green clay. 3-39 150.23 0.05 5.35 400 SST, f-med, mod tnd, mod ?S, ccc green clay, sl pyr. 1X5 1X5 154 139 39 56 57 58 32 49.91 6.41 3.09 11.4 89 46.98 11.91 2.97 20.2 60.7 45.4 20.2 19.1 5.22 0.79 36.1 18.5 68.4 ~-87 3-40 137.67 0.03 6.30 400 SST, f-med, mod ind, ccc green clay, si ?S. 1X5 126 41 58 28 45.73 12.55 2.76 21.5 50.7 35.6 13.7 18.4 0.74 3-41 146.17 0.00 3.90 400 SST, f-med, mod ind, ccc ?S, ccc green clay. 1X5 140 00 55 58 46.35 9.23 3.02 16.6 42.7 27.5 29.8 4.96 0.75 3-42 152.52 0.13 SST, a/a, w/ tr lam. 5.65 400 1X5 144 21 58 51 48.77 9.74 2.96 16.7 58.6 20.0 21.4 1.29 0.59 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP -1 Number ~ Loss ~ Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv (Ka) mD arm.s 3-43 173.71 0.13 4.70 400 1X5 SST f-med, mod ind, cmn ?S, sl green clay, lam, sl nat frac. 168.07 56.95 50.91 6.04 3.30 10.6 78.6 6.1 15.3 0.17 0/48 3-44 162.83 0.12 0.90 SST a/a, w/ no vis lam. 400 1X5 156.70 57.59 51.22 6.37 3.06 11.1 14 3 82,3 3.4 0,26 0.54 3-45 152.48 0 03 5.20 400 1X5 145.42 55.11 45.87 9.24 3.17 SST f-med, mod ind, mod ?S, sl green clay, sl nat frac w/ brown cmting min. 16.8 56.8 22.1 21.1 3.33 0.69 3-46 146.18 0 13 7.60 400 SST f-med, mod tnd, sl ?S, sl green clay. 1X5 134.46 58.32 46.49 11 83 2.89 20.3 64 9 23.0 12.1 3.52 ~_, 69 3-47 160.09 0 20 6 20 400 1X5 SST f-med, mod ind, cmn ?S, ?mod dtssem pyr, si green clay, frac. 151.28 55.81 46.65 9 16 3.24 16.4 68.4 16.6 15.0 FRAC 3-48 145.50 0 28 6 90 400 SST f-med, mod ind, mod ?S, occ green clay. 1X5 134.66 55 68 44.09 11 59 3 05 20.8 60 1 25.4 14.5 13.9 0.74 3-49 148.66 0 19 6 O0 400 lX5 140.61 55 31 44.08 11 23 3 18 SST f-med, mod tnd, cmn ?S, sl pyr, sl green clay, si lam, part open nat frac. 20.3 54 0 20.1 25.9 9.29 0.83 3-50 135.90 0 20 8 O0 400 SST f-med, mod ind, occ ?S, si green clay. 1X5 114 88 54 14 38.63 15 51 2 97 28.7 52.1 37.7 10.2 43.9 0.86 3-51 149.85 0 18 4 70 400 lX5 SST f, mod-w.ind, cmn ?S, sl green clay, part open nat frac. 3-52 162.00 0 03 5 80 400 SST, f-med, mod ind, cmn ?S, sl green clay lX5 143 41 55 84 48.02 7 82 2 98 154 19 57 90 49.46 8 44 3 12 14.0 60.7 17.2 22.1 4.58 0.80 14.6 69.4 13.1 17.5 0.89 ~71 3-53 154.83 0 O0 6.80 SST, a/a, w/ part open nat frac. 400 1X5 148 20 57 86 46.99 10 87 3 11 18.8 63 2 18.4 18.4 3.48 0.69 3-55 151.44 SST, a/a. 0 15 8.05 400 1X5 140 77 54 04 43.27 10 77 3 25 19.9 75.5 3.9 20.6 0.09 0.42 3-56 144.90 SST, a/a, v arg. 0 21 5.55 40O lX5 137 70 55 95 47.59 8 36 2.89 14.9 67.1 13.2 19.7 0.41 0.65 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP~ -1 Number ~ Loss ~ Extracted cc Initially ¢c Methanol cc ~ o¢ cc cc cc % % pv % pv % pv (Ka) mD atmo~ 3-57 146 13 0.04 5 35 400 SST, f-med, mod ind, mod ?S, ccc green clay. 1X5 136.97 56.94 46.85 10.09 2.92 17.7 53.6 30.3 16.1 10.3 0.'84 3-58 145 67 SST, a/a. 0.16 4 75 400 1X5 138.65 57.37 47.47 9.90 2.91 17.3 48.5 25.5 26.0 4 52 0.73 3-59 145 33 0.15 4 80 400 SST, f, mod-w.ind, mod calc, ccc green clay, si 1X5 139.57 56.02 49.75 6.27 2.80 11.2 77.3 7.3 15.4 0 11 0.45 4-1 146 72 0.00 5 10 SST, a/a, w/ ccc patchy pyr. 400 lX5 141.16 57 43 69.81 7.62 2.85 13.3 67.6 6.1 26.3 0 12 4-2 137 63 0.17 5 40 400 1X5 126.99 56 18 44.32 11.86 2.86 SST, f-med, mod ind, mod ?S, ?carbonate cmtd fracs, part open nat fracs. 21 1 46.0 31.1 22.9 113 0.91 4-4 164 59 0.06 8 45 ?SST, f-med, mod-w.ind, v cmn ?S. 400 1X5 154.79 57.50 47.69 9.81 3.25 17 1 87.0 7.2 5.8 2 32 0.62 4-5 141.47 SST a/a. 0.12 6.35 400 1X5 133.49 56 04 47.58 8.46 2.81 15 1 75.8 7.7 16.5 1 06 0.55 4-6 133.15 0.08 5.00 SST f-med, mod ind, mod ?S, frac. 400 1X5 4-7 143.10 SST a/a. 0.15 6.50 400 1X5 4-8 148.30 0.18 6.35 400 1X5 SST f-med, mod ind, cmn ?S, si calc, ?carbonate cmtd nat frac. 124.60 54 09 43.23 10.86 2.88 132.39 56 78 45.87 10.91 2 88 138.96 55 97 45.87 10.1 3.02 20 0 19 2 18 1 46.5 36.7 16.8 FRAC - 60.2 33.3 63.5 18.4 6.5 FRAC 18.1 13.8 '72 4-10 140.62 0.06 6.50 400 SST f-med, mod tnd, v calc, si ?S, si green clay. 1X5 132.90 56.27 47.72 8.55 2.79 15 2 76.8 10.0 13.2 0.23 0.48 4-11 154.63 0.35 3.30 400 SST f, mod-w.ind, v calc, mod ?S, carbonate cmtd fracs. 1X5 150.83 56.70 50.57 6.13 2.98 10 8 54.4 8.7 36.9 0.07 0.37 4-12 149.65 0.03 5.55 SST, f, mod-w.ind, mod calc, ccc ?S. 400 1X5 143.21 57 99 51.12 6.87 2.80 11 9 81.6 3.4 15.0 0.07 0.37 Weight on Volume of Volume of Pipette Dry Bulk Grain Pore Grain Water Oil Sample Depreservtn Grain Water Methanol used Volumes of Weight Volume Volume Volume Density Porosity Saturation Saturation Gas Permeability RMP. -1 Number ~ Loss g Extracted cc Initially cc Methanol cc ~ cc cc cc cc % % pv % pv % pv (Ka) mD atmqs 4-13 143.39 SST, a/a. O. 16 7 35 400 1X5 133.82 57.36 47.46 9.9 2.82 17.3 75.0 8.9 16.1 2.66 0.'70 4-14 147.09 0.09 4 95 400 SST, f, mod-w.ind, mod ?S, mod calc, tr nat frac. 1X5 140.94 55.40 49.61 5.79 2.84 10.5 86.3 10.4 3.3 0.20 0.46 4-15 143.86 0.01 3 70 SST, f, mod-w.ind, mod ?S, mod talc. 400 1X5 139.86 55.21 50.04 5.17 2.79 9.4 72.3 5.7 22.0 0.08 0.37 4-16 145.87 0.10 5 50 SST f, mod ind, mod 400 lX5 138.24 56.59 48.31 8.28 2.86 14.6 67.1 13.9 .19.0 2.17 ~___~62 4-17 148 18 SST a/a. 0.11 5 90 400 lX5 140.41 57.41 48.64 8 80 2.89 15.3 67.7 11.0 21.3 4.73 0.74 4-18 145 77 0.00 4 90 SST a/a, w/ si calc ?biocl. 400 1X5 139.24 58.51 47.96 10 55 2 90 18.0 46.9 16.9 36.2 29.0 0.77 4-19 153 54 0.17 6 50 SST a/a, w/ cmn calc biocl. 400 1X5 145.35 56 O1 47.25 8 76 3 07 15.6 74.9 5.2 19.8 12.3 0.86 4-19F 66.97 0 3.30 SST a/a, w/ cmn calc btocl. 400 1X5 62.98 24 79 21.20 3 59 2 98 14 . 5 92.8 0 7 . 2 FRAC 4-20 160.78 0.02 7.20 400 1X5 SST f, mod ind, mod ?S, mod calc btocl, lams w/ cmn dissem pyr. 152.58 58 00 50.23 7 77 3 04 4-21 1.63.83 0.02 4.60 400 1X5 158.41 57 13 50.61 6 52 3 13 SST f, mod ind, cmn?S, cmn calc biocl, occ iron oxide st, sl green clay, lem. 13.4 11.4 93 6 713 1.9 4.5 0.22 0.47 9.0 19.7 1.91 -62 4-22 147.49 0.15 4.50 400 1X5 142.04 54 34 48.86 5.48 2.91 SST f, sl arg, mod ind, cmn calc btocl, mod ?S, sl green clay, tr iron oxide st, lam. 10 . 1 82.9 5.1 12.0 0.39 0.60 4-23 154.71 0.10 5.70 SST a/a, w/ patchy dissem pyr. 400 1X5 148.27 58 O0 51.90 6.10 2 86 10.5 94 4 0 5.6 0.34 0.57 4-24 159.33 SST, a/a. 0.05 3.55 400 1X5 155.06 57 65 53.29 4.36 2 91 7.6 82.2 6.9 10.9 0.08 0.45 Weight on Volume of Volume of Pipette Dry Sample Depreservtn Grain Water Methanol used Volumes of Weight Number ~ Loss $ Extracted cc Initially cc Methanol co ~ 4-25 148.43 0.05 4.20 400 1X5 SST, f, mod-w.tnd, v calc, mod green clay, ccc ?S, sealed nat frac. 141.81 4-26 159.22 0.01 4.3 SST, a/a, w/ sl iron oxide st. 400 1X5 154.66 4-27 150.65 0.07 6.8 SST, a/a, w/ mod calc biocl. 400 1X5 143.72 4-28 141.90 0.00 3.55 400 SST, f, mod ind, mod ?S, mod green clay, sl calc biocl. 1X5 137.30 4-29 155.50 0.08 6.70 400 1X5 148.11 SST, f, mod ind, v calc, mod green clay, mod red st, sl calc biocl, MDST, lam. Bulk Grain Pore Grain Volume Volume Volume Density Porosity cc cc cc cc % 55.82 49.78 6.04 2.85 10.8 58.02 53.20 4.82 2.91 8.3 57.20 49.91 7.29 2.88 12.7 55.38 48.62 6.76 2.82 12.2 57.60 50.08 7.52 2.96 13.1 Water Saturation Z pv Oil Saturation Gas Permeability RMP Z pv % pv (Ka) mD atm,:s 70.2 7.1 22.7 0.13 0:39 90.1 0 9.9 0.02 0.37 94.2 0 5.8 0.11 0.45 53.1 17.0 30.0 0.97 .--~-J~.. 71 90.0 1.7 8.3 0.42 0.57 Pt: McIntyre #9 RE~X~T~~~~="'RoUtine Core Analysis BP Exploration, 1991 Prepared by:. Robertson Group plc Petroleum Division Unit 5 Wellheads Crescent Tr~-:EStat~e Wellheads Industrial Estate :,~.~ --'-'.!'!~' Dyce Aberdeen AB20GA" '""-' ~ . :-": ::" Maf~h i99]. . /Robertson Groupplc CONTENTS 1. INTRODUCTION 2. METHODS , , CONVENTIONAL CORE ANALYSIS DATA- ALASKAN'SA_NIPLES i'~i'i i- _ , STATISTICAL ANALYSIS - ALASKAN SAMPLES - Histograms Statistical Summary for Horizontal Permeability (Air) Statistical Summary for Helium Porosity - Crossplots, Helium Porosity Vs Horizontal Permeability (Air) / , ]Robertson Group pic INTRODUCTION At the request of BP Petroleum Development conventional core analysis has been carried out on 134 Alaskan core samples. All plug samples were received fully preserved in zeit foil bags. The results of all analyses are presented in a tabulated format in Chapter 3 of this report. Graphical representations of the data take the form of crossplots, histograms and statistics, and may be found in Chapter 4. ' lRobertson Groupplc METHODS Dean and Stark Analysis All apparatus to be used including extraction thimbles and solvent, was fully dewatered prior to analysis. The samples were carefully depreserved, weighed and placed in extraction thimbles which had also been weighed. Water extraction then proceeded by refluxing the samples using dewatered toluene as the solvent. The water removed from the samples was collected in a sidearm and accurately measured. After all water had been extracted, the samples (still in the extraction thimbles) were placed into individual soxhlets and refluxed in &watered methanol until a silver nitrate test showed the samples to be clean of salt. All volumes of methanol used were recorded. After methanol cleaning any samples displaying fluorescence under UV light were returned to the soxhlets and cleaned in toluene until all hydrocarbons were removed. From the Helium porosity values (see below) it was possible to calculate the residual oil and water content. Drying of samples The samples and extraction thimbles together were dried to constant weight in a dry oven at 95°C. After removing the samples the thimbles were reweighed separately to check for any significant weight gain ie. grain loss from the samples. Petrophysical Measurements Permeabilities were measured using a calibrated steady state permeameter with dry Nitrogen as the flowing medium. The Hassler pressure for sealing the samples was 400 psi. The grain volumes of the samples were calculated using a calibrated Helium gas volume expansion meter. Bulk volumes were calculated by Mercury displacement on a Ruska porometer cell fitted with a linear transducer. These data used in combination with the weights of the samples yielded porosity and grain density data. All analysis was carried out following BP instructions. ___ Robertson Groupplc Well :Alaska II Company :BP Research Report :C1/407 Report Interval : GORE ANALYSIS DATA SAMPLES BEGINNING 2 3 13644.20 FRAC 12.0 2.71 5 13646.20 FRAC 10.6 2.70 6 13647.20 FRAC 7 13650 20 8 13651 20 9 13652 20 10 13653 20 11 13654 20 12 13655 20 13 13656 20 14 13657 20 15 13658 20 FRAC FRAC 22 96 3 59 < O1 67 42 .74 9 6 11 4 20 0 O0 99 80 12 2 6 30 0 O0 93 70 10 4 27 90 14 80 57 30 16 5 11 70 47 60 40 70 13 1 7 30 6 40 86 30 4. 6 12 90 17 4.0 69 70 13 8 5 60 0 O0 94 40 14 2 3 70 0 O0 96 30 13 4 1 20 0 O0 98 80 2.72 3.05 2.71 3.16 2 95 2 86 3 29 2 79 2 81 2 69 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : CORE ANALYSIS DATA 16 13659.20 FRAC 17 13660.20 .54 18 13661.20 CHIP 19 13662 20 20 13663 20 21 1366'4 20 22 13665 20 23 13666 20 24 13667 20 25 13668 20 26 13669 20 27A 13669 80 27B 13670 20 6 4 22 O0 8.80 69 20 3.31 13 3 1 10 3 60 95 30 2.71 .69 32 11 5 15 0 13 2 14 50 21 20 17 O0 24 60 4 70 23 10 60 90 74 10 59 90 3.18 2 67 2 67 25 21 1 20 13 5 12 8 15 7 3 O0 1.3 60 20 10 25 70 22 70 15 70 71 30 63 70 64 20 2 69 2 70 2 68 16 10.9 12 30 23 30 64 40 2 68 11 11.4 5 10 8 20 86 70 2 71 26 12.3 25 70 13 80 18.8 17.4 10 40 22 80 19 50 34 00 70 10 34 50 43 20 2 70 45 50 2 68 20 O0 2 68 Well :Alaska II Company :BP Research Report :G1/407 Report Interval : CORE ANALYSIS DATA 27C 13671 20 28 13676 50 29 13677 20 30 13678 50 31 13679 20 32 13680 20 33 13681 20 34 13682 30 35 13683 20 36 13684 20 36 13684 20 37 13685 20 13.60 14 17 5 17.50 36.70 45.80 2.67 05 11 7 14 10 24 70 61 20 2.70 O4 16 5 10 60 34. 80 54 60 3.19 32 95 650 50 93 O0 2.74 1 32 11 2 4 80 4 O0 91 20 2.75 64 16 9 15 20 28 90 55 90 3.12 71 20 2 16 20 18 60 65 20 3.05 DAM 18 2 8 20 9 40 82 40 2.88 .O3 16 7 17 60 12 70 69 70 3.12 .26 17 3 7 90 7 30 84 80 3.36 1.38 15 6 9 50 14 70 75 80 2.91 38 13686.20 .05 19 7 15 70 17 30 67 O0 3.18 16 8 14 20 6 50 79 30 3.23 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : CORE ANALYSIS DATA 40 13688 20 41 13689 20 42 13690 40 43 13691 20 44 13692 60 45 13693 30 46 13694 O0 47 13695 20 48 13696 30 49 13697.40 50 13698.40 51 13699.50 FRAC 22.4 .95 15.4 8.99 25.5 76.20 23.9 97.40 26.2 3.44 23.0 8.35 26.40 02 6 45 9 68 1 33 52 13700.30 45 50 23 5 28 7 13 8 21 6 23 5 19 0 23 2 12 80 17 O0 6 60 19 30 14 70 22 40 '1.5 70 12 50 17 20 27 2O 16 90 8 70 28 O0 12 50 12 70 24 50 26 30 36 80 19 6O 22 40 32 80 5 60 21 20 20 50 23 90 20 30 74.70 70 30 68 90 54 40 48 50 58 O0 61 90 54 70 77 2O 51 60 62 60 67 40 51 70 3 02 3 15 2 83 2 92 2 89 3 08 2 86 3 O0 3 20 2 92 2 99 2 86 2 96 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : GORE ANALYSIS DATA SAMPLES BEGINNING 3 1 13702 20 2 13703 40 3 13704 20 4 13705 30 5 13706 20 6 13707 50 7 13708 30 8 13709 20 9 13710 20 10 13711 20 11 13712 30 12 13713 40 8.05 FRAC 23.70 8.53 17 5 10 2 21 7 16 5 3.63 20 6 2 19 62 1 O0 27 O0 11 80 2 18 3 68 ].9 4 18 2 15 8 2]. 2 21 1. 2O 5 19 8 39 70 1 O0 24 00 14.40 9O 27 90 50 39 90 21 70 1.8 60 14 70 14 20 29 50 15 70 15 60 14 70 13 60 14 60 10 70 25 70 22 40 31 O0 16 40 26 10 45 90 98 10 48 10 59 60 64 70 66 80 74 60 60 10 48 10 53 30 68 O0 59 20 2.89 3.28 3.16 3.10 3.01 3.13 3.03 2.95 3.05 2.85 3.00 2.93 Well :Alaska II Company :BP Research Report :G1/407 Report Interval : GORE ANALYSIS DATA 1.3 13714 20 14 13715 20 15 13716 60 16 13717 40 17 13718 40 14.60 1.36 .88 FRAC 69.70 18 13719 40 165.00 19 13720 30 435.00 20 13721 20 21 13722.50 49.10 22 13723.40 .50 23 13724.10 2.09 24 13725.30 7.02 25 13726.20 55.80 FRAC 22 4 ].7 90 37 40 44 70 17 7 18 10 22 20 59 70 14 9 28 50 9 50 62 O0 14 4 15 10 54 80 30 10 19 1 21 80 56 60 21 60 20 5 11 80 63 70 24 50 20 9 19 50 54 10 26 40 16 9 7 50 50 70 41 80 17 8 4 30 53 50 42 20 10 6 26 50 31 40 42 10 11 6 12 70 34 70 52 60 16 8 15 60 30 50 53 90 16 8 21 70 38 20 40 10 2.91 2.95 2.85 3.21 2.90 2.82 2.72 2.98 2.95 3.06 3.18 2.95 2.96 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : CORE ANALYSIS DATA 26 13727 80 27 13728 30 28 13729 20 29 13731 80 30 13732 30 32 13734 20 33 13735 60 34 13736 30 37 13739 20 38 13740 80 39 13741 20 40 13742 20 41 13743 60 ClIlP 9.63 51.30 .78 1.52 .41 FRAC 4 94 3 76 5 22 68 40 18 40 4 96 15 0 19 6 18 9 11 1 13 3 11 6 13 6 15 5 13 9 11 4 20 2 21 5 16 6 28.00 30.20 16 20 10 90 18 50 19 80 18 10 8 40 20 20 28 80 19 10 18 50 13 70 29 80 44 20 48 30 13 30 14 40 17 80 17 80 20 10 22 40 20 20 36 10 35 60 41 80 39 60 40 80 68 20 65 80 64 10 73 80 59 70 48 80 60.70 45.40 50.70 27.50 42.70 3.08 2 85 2 86 3 25 2 95 3 32 3 28 3 04 2 94 3 09 2 97 2 76 3 02 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : GORE ANALYSIS DATA 42 13744 20 43 13745 20 44 13746 20 45 13747 10 46 13748 40 47 13749 20 48 13750 20 49 13751 20 50 13752 20 51 13753 60 52 13754 2O 53 13755 20 55 13757 20 1.29 1.6.7 21.40 .17 10.6 .26 3.33 3.52 FRAC 13 90 9 29 43 90 4 58 11 1 16 8 20 3 16 4 20 8 20 3 28 7 14 0 89 14:6 3 48 18.8 15 30 3 40 21 10 12 10 15 00 14 50 25 90 10 20 22 10 17 50 18 4O 09 19.9 20 60 20 O0 6 10 82 30 22 10 23 O0 16 60 25 40 20 10 37 70 17 20 13 10 18 40 3 90 58 6O 78 60 14 30 56 8O 64 90 68 4O 60 10 54 O0 52 10 60 70 69 40 63 20 75 50 2.96 3.30 3.06 3.17 2.89 3.24 3.05 3.18 2.97 2.98 3.12 3.11 3.25 Well :Alaska II Company :BP Research Report :G1/407 Report Interval : CORE ANALYSIS DATA 56 13758.30 .41 57 13759.40 10.30 58 13760.40 4.52 17.3 26.00 25.50 48.50 2.91 59 13761.30 .11 11.2 15.40 7.30 77.30 2.80 SAMPLES BEGINNING 4 1 13762 20 2 13763 20 4 13765 20 5 13766 30 6 13767 20 7 13768 20 8 13769 10 10 13771 30 14.9 19.70 13.20 67.10 2.89 17.7 16.10 30.30 53.60 2.92 .12 2.32 1.06 FRAC FRAC 13.80 .23 13 3 26 30 6 10 67 60 21 1 22 90 31 10 46 O0 17 1 5 80 7 20 87 O0 15 1 16 50 7 70 75 80 20 0 16 80 36 70 46 50 19 2 6 50 33 30 60 20 18 1 18 10 18 40 63 50 15 2 13 20 10 00 76 80 2 85 2 86 3 25 2 81 2 88 2 88 3 02 2 79 Well :Alaska II Company :BP Research Report :C1/407 Report Interval : CORE ANALYSIS DATA 11 13772.20 12 13773.40 13 13774.20 14 13775.20 O7 O7 2 66 2O 15 13776.20 08 16 13777.20 17 13778.50 18 13779.20 19 13780.10 2 17 4 73 29 O0 12 30 19 13780.10 FRAC 20 13781.40 .22 21 13782.20 1.91 22 13783.20 .39 10 8 36 90 11 9 15 00 17 3 16 10 8.70 54.40 2.98 3.40 81.60 2.80 8.90 75 O0 10 5 3 30 10 40 86 30 9 4 22 O0 5 70 72 30 14 6 19 O0 13 90 67 10 ,15 3 21 30 11 O0 67 70 18 0 36 20 16 90 46 90 15 6 19 80 14 5 7 20 13 4 4 50 11 4 19 70 10 1 12 O0 5 30 74 90 0 O0 92 80 1 90 93 60 9 O0 71 30 5 10 82 90 2.82 2.84 2.79 2.86 2.89 2.90 3.07 2.98 3.04 3.13 2.91 Well :Alaska II Company :BP Research Report :G1/407 Report Interval : CORE ANALYSIS DATA _ ::'~'::::;';;;:":: : ;:':.':::';::: '.:. :'::;::::':;.,'.:::;.'.::':',;.: ".',:I:'':. ' : : ".i :. ::; .'.'': . ;'::: .................... I:~ AmPI~'l:~Depth'~l'~/"P~rmeability': 'Permeability, IHei'i~m~':::l~,Resid~ii:!:S'A~:~ii~i::?l'O~:{~?~il~i~!~{~°i~i { ~::~ i ::.i:.!i::I 23 13784 20 24 13785 20 25 13786 20 26 13787 20 27 13788 40 28 13789 20 29 13790 20 34 O8 13 02 11 97 42 10 5 7 6 10 8 8 3 12 7 i2 2 1.3 1 5.60 10 90 22 70 9 90 5 8O 30 O0 8 30 0 O0 6 90 7 10 0 O0 0 O0 17 00 1 7O 94 40 82 20 70 20 90 10 94 20 53 00 90 00 2 86 2 91 2 85 2 91 2 88 2 82 2 96 Well 'Alaska II Company 'BP Research Report 'C1/407 Depth range '13644.20 - 13790.20 Feet STATISTICAL SUMMARY FOR HORIZONTAL PERMEABILITY - AIR MEANS Arithmetic : 13.94 md Geometric : 1.68 md Harmonic : .27 md STANDARD DEVIATION Arithmetic : 45.84 md NO OF SAMPLES 114 GROUPING OF RANGES RANGE md SAMPLES MEANS md geom. arith. FREQUENCY CUMULATIVE ( % ) FREQUENCY ( % ) 1 2 5 10 20 4O 81 163 327 01 02 - 04 - 08 - 16 - 32 64 - 1 28 - 2 56 - 5 12 - 10 24 - 20 48 - 40 96 - 81 92 - 163 84 - 327 68 - 655 01 0 02 0 04 3 08 5 16 9 32 11 64 11 28 14 56 12 12 14 24 10 48 9 96 5 92 8 84 1 68 1 36 1 1 3 7 13 26 56 97 165 435 0.00 0.00 .02 .05 .11 .22 .42 85 71 86 99 46 30 37 40 00 O0 0 00 0 00 02 06 11 22 43 87 1 75 3.92 8.12 13.61 26.36 57.49 97.40 165.00 435.00 0,00 0.00 2.63 4.39 7.89 9.65 9.65 12.28 10.53 12 28 8 77 7 89 4 39 7 02 88 88 88 0.00 0.00 2.63 7.02 14.91 24.56 34.21 46.49 57.02 69.30 78.07 85.96 90.35 97.37 98.25 99.12 100.00 / - /Robertson I Groupplc CUT OFF md 01 02 04 08 16 32 64 1 28 2 56 5 12 10 24 20 48 40 96 81 92 163 84 327 68 655 36 Total capacity · CAPACITY '~_~£ FOR SELECTED CUTOFF VALUES ELEMENTS lost remaining 0 114 0 114 3 111 8 106 17 97 28 86 39 75 53 61 65 49 79 35 89 25 98 16 103 11 111 3 112 2 113 1 114 0 CAPACITY % lost 0 O0 0 O0 2 63 7 02 14 91 24 56 34 21 46 49 57 02 69 30 78 07 85 96 90 35 97 37 98 25 99 12 100 00 remaining 100.00 100.00 97.37 92.98 85.09 75~.44 65 79 53 51 42 98 30 70 21 93 14 04 9 65 2 63 1 75 88 0 00 MEANS md geom. 0.00 0.00 .02 .04 .07 .11 .16 .24 .35 .54 .73 .95 1.12 1.48 1.54 1.60 1.68 arith. o.oo 0.00 .02 .04 .08 .13 .22 .39 .64 1.22 2.00 3 06 4 19 8 03 8 83 10 21 13 94 1589.28 ___ Robertson Grouppic WELL ~RLRSKR II COMPANY %BP RESEARCH REPORT :C]/qO? DEPTH RANGE =196qq.20 - 13790.20 FEET HORIZONTRL PERHERBILITY - AIR VS. FREQUENCY DISTRIBUTION lOO 9o 8o 7O 6o 3o 2O Il ll 2 1o I I 1 .O1 ,Oq , 16 , 6l[ 2.56 10 41 16~[ 655 HORIZONTAL PERMEABILITY - AIR (MD) 2621 10~t86 CUMULATIVE FREQUENCY GEOMETRIC MEAN GEOMETRIC MEAN = 1.68 MEDIAN - 1,27 / /Robertson Group pic Well :Alaska II Company 'BP Research Report 'C1/407 . Depth range 13644 20 13790 20 Feet STATISTICAL SUMMARY FOR HELIUM POROSITY MEANS Arithmetic : 15.92 % Geometric : 15.27 % Harmonic : 14.55 % STANDARD DEVIATION Arithmetic : 4.49 % NO OF SAMPLES 134 GROUPING OF RANGES RANGE % SAMPLES MEANS % geom. arith. FREQUENCY (8) 2 00 - 4 00 - 6 00 - 8 00 - 10 00 - 12 00 - 14 00 - 16 00 - 18 00 - 20 00 - 22 00 - 24 00 - 26 00 - 28 O0 - 2 00 4 00 6 00 8 00 10 00 12 00 14 00 16 00 18 00 20 00 22 00 24 00 26 00 28 00 30 00 2 4 24 19 19 23 15 16 7 1 1 2 0 00 0 00 4 60 6 97 9 18 11 01 13 09 15 01 17 02 18 97 20 77 23 12 25 50 26 20 28 70 0.00 0.00 4.60 7.00 9.20 11.02 13.10 15.02 17.02 18.98 20.78 23.13 25.50 26.20 28.70 0 00 0 00 75 1 49 2 99 17 91 14.18 14.18 17.16 11.19 11.94 5.22 .75 .75 1.49 CUMULATIVE FREQUENCY (%) 0.00 0.00 .75 2.24 5.22 23.13 37.31 51.49 68.66 79.85 91.79 97.01 97.76 98.51 100.00 Robertson Groupplc CUT OFF % 2 O0 4 00 6 00 8 00 10 00 12 00 14 00 16 00 18 00 20 00 22 00 24 00 26 00 28 00 30 O0 Total capacity : CAPACITY ~ f FOR SELECTED CUTOFF VALUES ELEMENTS lost remaining 31 5O 69 92 107 123 130 131 132 134 0 134 0 134 1 133 3 131 7 127 103 84 65 42 27 11 4 3 2 0 CAPACITY % los~ 0.00 0.00 75 2 24 5 22 23 13 37 31 51 49 68 66 79 85 91 79 97 01 97.76 98.51 100.00 remaining 100.00 100.00 99.25 97.76 94.78 76.87 62.69 48.51 31.34 20.15 8.21 2.99 2.24 1.49 0.00 MEANS % geom. 0.00 0.00 4.60 6.07 7.69 10.15 11.18 12.13 13.20 13.89 14.63 15.00 15.06 15.12 15.27 arith. o.oo 0.00 4.60 6.20 7.91 lO.32 11.38 12.38 13.54 14.30 15.14 15.57 15.65 15.73 15.92 2133.80 ___ Robertson Groupplc HELL : ALASKA COMPANY ~BP RESERRCH REPORT ~C1/~07 DEPTH RANGE ~136q~.20 - ]3790.20 FEET HELIUM POROSITY VS. FREQUENCY DISTRIBUTION loo 9O 8O 'lO 6O 50 qO 3O 15 t8 7 I 2 I 1 2 0 0 2 q 6 8 10 12 ]u~ 16 18 20 22 2u, 26 28 30 32 3q :)6 ~18 LIO Li2 U, tI ti6 [18 50 HELIUM POROSITY [X) CUMULATIVE FREQUENCY RRITHMETIC HERN ARITHMETIC MEAN = 15.92 MEDIRN - 15.65 HELL ~ALASKA 1] COHPANY :BP RESEARCH REPORT ~C1/q07 lO000 LO00 .tO .01 HELIUH POROSITY VS. HORIZONTAL PERHEABILITT - AIR X ,, X ( X /"/ Xxx X// X XXx~ Xxx X ?K x x I i i i i i i i i i i i I i i i i I i i i I I I I I I I I i i i i i i i i i -~ 0 5 lO 15 20 25 30 35 riO 45 50 HELIUM POROSITY COEFFICIENTS LEAST SOUARES FIT GROUP REGR. LINE SLOPE T ZNTERCEPT DEPTH INTERVAL FEET X .15~ -2.285 136q~.20 -13790.20 _ Robertson Groupplc HALLIBURTON RESERVOIR SERVICES Anchorage, Alaska CUSTOMER: WELL NAME: FIELD: AREA: INTERVAL: TEST DATE: TEST: BP Exploration (Alaska) Number 9 Point McIntyre North Slope, ALASKA N/A February 23 - March 5, 1991 SURFACE WELL TEST (POST-STIMULATION) ORIGINAL A as~a Oi! & Gas Cons. Commission I nc. Anchorage HRS report copies have been sent to the following companies and\or individuals' COPIES RECIPIENT iBP Exploration (Alaska) C/O Chartie l'iichet 900 East Benson Blvd. :'.lnchorage, Alaska '99503 ~907> 561-511i Inco HRS 3000 (-' Street Suite Anchorage, Ak 99503 ,'907>. ~"61- v-50. 200 T;~ 007340 FILMED >!arch '.-6, 199i ~Ir. Chartie Michel BP Exploration (Alaskat incorporated 900 East Benson Blvd. Anchorage, Alaska 99503 re: Well Test of February 23 - March 5, 1991 Number 9 Well Point McIntyre Field North Slope, Alaska Surface Well Test (Post-Stimulation) Dear Mr. Michel, Please find enclosed 't:n~' e summarized reports of the above .reference tests. The data was ,gathered electronically by HRS for processing and reporting. The oil rates are based upon tank gauge readings (and separator meter readings when applicable) and reported in ::,.rock tank barrels (separator barrels when applicable) at 60 degrees Fahrenheit. The gas rates are reported in thousands of standard cubic feet per day (MSCFD), oil rates in stock tank barrels of oil per day (STBOPB). The standard conditions used are: 14.73 psis and 60 degrees Fahrenheit. The gas ra'tes are calculated accordin~ to the Gas Measurement Committee Report No. 3 - 1969. The reported sa!.inities were determined by titration method and gas o'ravities= are measures wizh a. o-.=a,~ gravitometer. The oil weathering factors ( shrinka~'e fac ~o~ ,~ ) ar rm us' ca e t ~' '~ e dete ined lng a librat d tes cell that is attached to the separator vessel. At the conclusion of the well 'test data report on page 2.17 there is a table of averao' _~e separator and tank rates along with their, respective cumulative volume totals. These volumes and rates are corrected to 60 degrees fahrenheit for comparison. These averages represent onl): th.e periods when reasonable stab'[lized 'flow through the separator was achieved, which occurred three times over the coarse of 'the referenced test. Our review of the data indicates seven specific hourly readings during the separator flow periods that are likely questionable. These seven readings have ;.a minimal impact on the accuracy of' the data and are attributed to both well conditions and operational limits of the equipment. The maximum average rage achieved during the ~es~ was 1207.'S STBOPD on a !28/64ths inch choke with an average flowin~ well head pressure of 155. i psis. The oil flow rates an~ cumulative volumes reported are correcnem 'co s~andard conmitions based on an estimated average stock tank ~empera~ure of 80 degrees fahrenheit. This test includes separator oil flow rates and they to are corrected to standard conditions basem on an average separanor oil temperature of 112 degrees fahrenheit. We appreciate the opportunity to assist you on this project. Please do not hesitate to contact us at (907)26t-77~0 if you ha~e any questions concerning this or any other project. Sincerely, //oames C. Li~. Reservoir Engineer JCL/.jcl J7340CL Test Summary Date Real Delta Time Time WHP (psiq) Oil Water Choke Rate Rate 64ths) iSTBPD) (STBPD) Gas Rate (MSCFD) 02/2-t 12:20 0_;> / .', '~ 5 14:02 02/26 12'58 18:45 02/27 05: O0 O2/28 '20:22 23:23 03/01 01:!5 22:00 03/02 05:!5 <)3/O3 09 · 42 03/Oi O7 · 20 03/05 17:11 15.60 6.3 Open well for firsn posn-frac flow 39.77 25.8 Close well 41.31 348.8 Open well n/a 39.8 60.2 n/a 64.~'~4 11.1 n/a Close well Wire-line operations 70.03 1113.8 Open well 329.1 0.0 n/a Divert through separator (Flow period no. .I) 119.64 167.3 Close well Perform step-rate 122.65 2355.5 Open well · ;8 ~61.1 675.4 419.8 injection test Divert through separator (Flow period no. 2) 145.27 155.7 48 765.5 3.5 Close well Inject diesel with emulsifier ].52.52 887.0 Open well 180.97 !39.5 .!28 Close well Perform acid treatment 183.47 ill~ ~. 5 Open well 576.9 '788. 1 7.2 n/a Divert through separator (Flow period no. 3 ) =36.45 172.4 128 !-t46.1 72.7 Close well 905.0 Page 1.1 HRS Well Head Point Mcinfyre No. Pressure Vs. Time 9, Test #6 Post Frac 3000q ..................... I I Pressure Test ,-., 2500 il,iii Open Well With N2 Head · 5000-i,~~ ........ 0 5O ~~~.~ Step rate Injection Pumping IDiesei · 100 Test Open Well After Acid Treatment 150 200 Time (Hours)' 250 Page 1.2 HRS - Oil Rates Vs. Time Poinf Mcinfyre No. 9, Tesf #6 Posf Fr~c ~', 2500 · 2000- +- 1500 ~ 0 '- 1000 - 13 o 500 ~ O~ 02/23 02/25 02//24 --1600 02/27 OS/02 05/04 02/26 02/28 05/05 05/05 Real Tesf Time -1400 .... 1200 --1000 -"800 -600 -~400 -200 13.. Tank ~ Separafor 23 FEB 91 TICKET NO. 007340 PAGE ICOMPANY ' BP EXPLORATION {ALASKA), INC. IWECL NAME: POINT MCINTYRE NO. IAREA ' PRUDHOE BAY, ALASKA TIME DATA I WELL HEAD DATA REAL I DELTA DATE TIME I TIME WHP I iAP WHT ;CHK ICOMPANY REP : CHARLIE MICHEL iSEPARATOR : 42" X 15' 80 MMSC¥D 8000 BPD iTEST NO. : SIX (POST FRAC) :GAS METER RUN: 5.761" W/BARTON 202A RECORDER IiNTERVAL TESTED : N/A ILIQfflD METERS: 2" OIL, 1.5' OIL, 1" WATER ' WATER DATA I GAS DATA OIL DATA , RATE I C~M RATE i C~M IRATE I CUM T~K M?R ITOTAC ~OR I ' ' CUM ' ' TNK : TNK I~C TEMPi RATE (MSCF, SEP , SEP TNK i TNK (~PD) : (BSLI !~PD) i (~BL) ; (~PD): (S~L) (BBn) (F) I(MSCFD)/STB)i(M~CF) COMMENTS 02/23 20'43:45 02/23 21:00:00 02/23 21:30:00 02/23 22:00:00 02/23 22:42:45 02/23 23:01:30 02/23 23:30:00 02/24 00'00:00 02/24 00:30:00 02/24 01:00:00 02/24 01:30:00 02/24 02:00:00 02/24 02:30:00 02/24 03:00:00 02/24 03:30:00 02/24 04:00:00 02/24 04:30:00 02/24 05:00:00 02/24 05:30:00 02/24 06:00:00 02/24 06:30:00 02/24 07:00:00 02/24 07:30:00 02/24 08:00:00 02/24 08:30:00 02/24 09:00:00 02/24 09:30;00 02/24 10:00:00 02/24 10:30:00 02/24 ll:O0:O0 02/24 11:30:00 0,000 0,271 0,771 1,271 i.783 2,296 2,771 3.271 3,771 4.27I 4,771 5.271 5,711 6,271 6,771 7,271 7.771 8,27i 8.771 9,271 10.271 I0.771 11,271 11.771 12,271 12,771 13.271 13.771 14.271 14,771 '69.7 2.4 2.2 2,6 5~3,t 6,3 5~3.~ :57.3 5.1 610,3 160.7 4.8 647,6 162,8 484,8 654.0 155.5 '54.7 482,3 1659.3 481 482 466 160 161 161 162 162,6 162.7 7,9 8,0 7,9 2762,0 5,5 4.9 47 36 4O 32 33 4,3 7,8 ,6.6,8 55,6 8 1654.5 56,3 01652.9 56,6 6{648,5 56,0 51646,6 56,! 8 {647,5 56,1 01646,3 56,1 646,1 55,4 645,9 {55.2 645,6 160,2 647,8 162,5 643.6 )64,I 642,9 55.0 4645,1 61,3 {644,0 {644,4 64,8 1642.9 66,0 :641,3 67.8 {638.8 I69.9 1637.9 168.4 1637.0 {33.0 STAR? DATA ACOUISI?iO~ 23 FEB 91 TICKET NO. 007340 PAGE NO. 2.2 ICOMPANY ' BP EXPLORATION (ALASKA), INC. :COMPANY REP ' CHARLIE MICHEL :SEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD :WELL NAME: POINT MCINTYRE NO. 9 iTEST NO. · SIX (POST FRAC) :GAS METER RUN ' 5.761" W/BARTON 202A RECORDER :AREA ' PRUDHOE BAY, ALASKA :INTERVAL TESTED ' N/A :LIQUID METERS ' 2" OIL, 1.5" OIL, 1" WATER ,' TIkE DATA : WELL HEAD DATA : OIL DATA : WATER DATA ', GAS DATA ' ' REAL DELTA ' ' :HTR ' RATE : CUM : RATE CUM RATE , , , , , , ' CUM : TMX hTR TOTAL ,cuK SEP TNK TNK TNK I TNK : iNC TEMP RATE :(MSCF ' COM :(MM/DD):(HH:MM:SS) (HOURS) (PSIG)I(PSIG): (F):(64): (BPD):(BBL):(BPD) (BBL) (BPD):(BBL):(BBL) (F) (MSCFD):/STB):[MSCF) COMMEtiTS o2/24 o2/24 02/24 02/24 02/24 02/24 o2/24 o2/24 02/24 02/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 o2/24 02/24 o2/24 o2/24 o2/24 02/25 o2/z5 o2/25 02/25 02/25 o2/25 12:00:00 12:20:00 12:30:00 13:00:00 13:30:00 14:00:00 14:30:00 15:00:00 15:30:00 16:00:00 16:30:00 17:00:00 17:30:00 18:00:00 18:30:00 19:00:00 19:30:00 20:00:00 20:30:00 21:00:00 21:30:00 22:00:00 22:30:00 23:00:00 23:30:00 00:00:00 00:30:00 01:00:00 01:30:00 02:00:00 02:30:00 i5.271 15,604 15,771 16.271 16,771 17.271 17,771 18,271 18,771 19.271 19,771 20,271 20,771 21.271 21,771 22,271 22,771 23.271 23,771 24,27! 24,771 25.271 25.771 26,271 26,77i 27.271 Z7,771 28.271 28,771 29,271 29.771 0,0 6,3 31.2 184,7 86.7 127,6 I13, 156, 81. 97. 35,2 58,0 98,8 92,2 99,5 105,5 112,8 71,9 56,5 109.1 111 1 146 7 64 176 7 162 5 133 2 183 6 171 8 179 7 181.3 192.9 635.4:49,4 612,3 {51,3 629.6 119,7 694,6 {33,7 762,6 35,2 819,5 37,1 7 568,4 39,2 0 667,1 40.5 1]715,6 40.4 1:744,0 39,9 775.5 136 0 787 5:37 4 804 8:39 2 809 4:387 816 5138 9 822 8 {38 0 829 1138 2 828 0136 3 821.6 36,0 1817.9 37.4 :816,1 37,0 :821.3 38,5 {823.4 31.6 {830,9 37,7 {844.4 38,6 :853.0 36.8 1864,1 138,~ 1865.1 137.8 1866.5 137.8 1870.8 138.3 :873.6 138.4 0.0 0.0 123,4 127.2 253.? 374.3 392.1 714.9 92.3 0.0 0,0 0,0 0,0 5,1 i0,4 21,0 36.6 81.6 111.3 115.2 1561.7 1055.5 6ii,3 601,2 607.2 513,0 185,2 273.6 500.8 286.2 521,8 67,3 0,0 142.8 208.8 234,2 259,3 284.6 306,0 313.7 325,1 345.9 35?,9 379,6 382,4 OPEN WELL TO SAND SEPARAiOR :CTU RIH INJECTING N2 @50Oscf/min, BLEED CASING DOWN N2 RATE=3§O$cfm 23 FEB 91 TICKET NO. 007340 PAGE NO, 2,3 TIME DATA REAL DELTA DATE TIME TIME ,'COMPANY ' BP EXPLORATION (ALASKA), INC. iCOMPAfiY REP ' CHARLiE MICHEL {SEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD :WELL HAME' POINT MCINTYRE NO. 9 {TEST NO. ' SlX (POST FRAC) :GAS METER RUN ' 5.761" W/BARTON 202A RECORDER {AREA ' PRUDHOE BAY, ALASKA iIRTERVAL TESTED ' N/A ILIOUID METERS ' 2' OIL, 1.5" OIL, 1" WATER + ...................................................... f ............... f ............... + ....................... + ...................... + ......................................................... ' OiL DATA ' WATER DATA ' GAS DATA WELL HEAD DATA , , , ,~ ,'HTR { RATE CUM RATE CUM RATE CUM ' SEP HEP 'TNK THK TNK TNK WHP I IAP WHT {CHK , (MM/RD) (HH:MM:SS)(HOURS) (PSIG)I(PSIG) (F)I464)I {BPD) {BBL) {BPD) {BBL) (BPD) (BBL) i 02/25 02/25 o2/25 02/25 o2125 o2/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/25 02/2§ 02/25 02/25 02/25 02/25 o2/2~ o2125 02/25 02/25 02/25 03:00:00 03:30:00 04:00:00 04:30:00 05:00:00 05:30:00 06:00:00 06:30:00 07:00:00 07:30:00 08:00:00 08:30:00 09:00:00 09130:00 10:00:00 10:04:00 10:30:00 I1:00:00 11:30:00 12:00:00 12:30:00 I3:00:00 13:30:00 14:00:00 14:02:15 14:30:00 15:00:00 15:30:00 16:00:00 16:30:00 17:00:00 30.271 30.771 31,271 31,771 32,271 32,771 33,271 33.771 34.271 34,771 35.271 35,771 36,271 36.77I 37.271 37,337 37,771 38,271 38.771 10 ~qt 40.27! 40,??1 41,271 41,308 41,771 42,271 42,771 43,271 43,771 44,271 id3.i 837.4 138.5 193.1 876.8 138.3 136.2 877.3 ~,36,6 178,8 879.6 38.2 73.1 1870.0 33.6 4.0 {852,4 31.5 30.1 ',839.3 32.3 76.4 {827.3 31.4 38.3 {823.5 35.9 43.6 4818,4 36.6 i13,2 4813,8 37.3 56,0 {808.1 33 7 97,8 819 8 ',37 2 73.5 8253 4356 229,3 856 6 'n ,.8 6 231,4 859 I {38 2 i9,8 860 6 133 0 6.4 845 3:32 3 4.8 831 5 {36 3 56.5 830 9 {37 3 25.8 823 6 34 3 6,5 816 9 34 5 3,2 800 4 43,0 8,8 786.9 48.8 347,8 4780.1 33,3 100,6 {780.6 36.5 10?,5 1794,4 36,2 I35,3 {803.9 35,6 80,3 {825.0 34,2 83.4 {826.3 33,3 4?.5 {83?.9 32,0 299.3 i55.5 0.0 i55.5 246.6 .... 32d.0 i91.0 383.9 20~.I 98.0 2i! 9 i31.2 217 3 39.~ 21~ 2 0.~ 218 2 450,3 236,2 457.3 ~" 250.5 265.7 84.2 218.8 372.8 420,9 492.9 580.5 148.1 0.0 680.~ 691,3 378.7 3~5.9 402.7 4ii.9 411.9 427.4 444.9 465.5 491.3 497.0 505,3 506,6 506.6 533,~ 562.? 5?8.4 THK HTR TOTAL IGOR , ' CUM INC TEMP RATE I(RSCF , {BBL) (F) {MSCFD):/STB){(MSCF) ..............·~ ....... ~ ...... . ....... COMMENTS BSW=37.0%, N2 RATE=2OOsch ,BS{:3,0% IPh:6.5, SALINIT¥=i?,OOOppz ISTOP H2 INJECTION {CTU P.O.O.H. ICLOSE WELL-FREEZE ~ROTECT LIHE£ OPEN WELL TO SAND SEPARATOR 23 FEB 91 TICKET NO, 007340 PAGE liO, 2.4 t ..................................................................... :COMPANY ' BP EXPLORATION (ALASKA), iHC. :COMPANY REP ' CHARLIE MicHEL :SEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD IWEL~ NAME: POINT MCINTYRE NO. 9 '. ,TE:T NO. ' SiX (POST FRAC) {AREA ' PRUDHOE BAY, ALASKA ',u,~,,, , ,,,,~,~ TEHTZD ' N/A {LIQUID MEYERS ' 2" OIL, 1.5 OIL, 1" WATER + ........................... + ......................... + ............... + ....... ~ ....................... { ...................... +- TIME DATA ,' WELL HEAD DATA I OIL DATA ....... + .......... + ........ + ....... ~ ...... + ..... + .... + ....... + ....... ~ ....... ~ ....... REAL DELTA ' ' 'HTR DATE TINE TIME I WHP i IAP WHT :CHK (MM/D) (HH:MM:SS)(HOURS):(PSIG)I(PSIG) (F) ....... + .......... + ........ + ....... + ...... + ..... + .... ' WATER DATA ' GAS DATA ~ ....... + ....... + ....... + ....... + ....... ~ ...... + ........ 02125 02125 02125 02125 02/25 02/2~ 02125 02/25 02/Z5 02/2§ 02/25 02/25 02/25 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 02/26 Oz/Z~ 02/26 02/26 02/26 02/26 17130'00 18100100 18130100 19100100 19130100 20:00:00 20:30:00 21100100 21130100 22:00:00 22:30:00 23:00:00 23:30:00 00100100 00:30:00 01100100 01130100 02:00:00 02:30:00 03:00:00 03:30:00 04:00:00 04:30:00 05:00:00 05:30:00 06:00:00 06:30;00 07:00:00 07:30:00 08:00:00 08:30:00 44.771 45.271 45.771 46.271 46.771 47.271 47.771 48.271 48 771 49 271 49 771 50 271 50 771 51 271 51 771 52 271 52 771 53.271 53.771 54,271 54,771 55,271 55.771 56.271 56,271 57.271 ~2,271 §8,271 58,771 59.271 59,771 91,2 39.7 52,9 109.6 34.7 5.3 48.0 50 9 31 6 48 8 8O i 66 4 7O 0 46 9 54.0 28,9 27.7 63.8 21.4 4.4 56,2 50,0 0.0 16.9 41.3 103,6 87,5 65,5 95,5 87,5 I 831.6 133.4 827.4 431.9 826.i 131.5 823.3:33.0 824.3 28.i 820.1 30.5 1814.5 31.7 {806.5 29.8 4802.I 30.9 {798.5 31.0 :802.3 32.5 1812,1 33.1 1823.1 34.1 1824,4 32.I 833 9 31 8 841 8 {31 8 845 5{30 1 845 6:31 5 849 0131 2 850i130 6 840 6{30 4 838 3:33 2 835 3132 8 826 1131 3 831 9{30 1 824.5 33 5 1828.0 33,4 :838.5 34,6 {856.3 33,3 {862.0 34,4 {867.9 33,5 'CUM TNK MTR RATE CUM RATE CUM RATE, SEP HEP TNK TNK TNK i TNK INC TEMP (BPD) (BBL) {BPD) (BBL) (BPD} { (BBL) (BBL) (F) ........ t ........................ + ....... {. ....... + ....... + ....... d93.? 34.7 589.7 ~67.i 661.5 ~08.~ 203.5 186.7 322.3 935,1 639,3 360.7 593.5 306.0 339.3 363.8 400.0 427 5 448 7 471 3 479 a §01 0 540 0 ~66,6 i02.4 5.i 6!.4 i28.0 1i4,9 88.4 91.3 35.4 32.4 56.0 39.3 26.9 597.7 598,0 600.3 602.9 606.5 61i.8 616.6 620.3 624.2 625.7 627.0 629.4 631.0 632.1 'gOR { TOTAL, RATE {(NSCF{ CUM {MSCFD):/STB) {(MSCF) COMMENTS ' BSW=6.0% OIL GRAV=24.1 APl IBSW=iO,0%, OIL GRAV=2?.2 APl BSW=3.0% BSW=2.0% WELL BLOWING GAS WELL BLOWING GAS, OIL GRAV=31.~ A?I ;fELL BLO{ING GAS BSW=20.0% OIL GRAV=25.8 APl 23 FEB 91 TICKET NO, 007340 PAGE NO. 2,5 ICOMPANY : BP EXPLORATION (ALASKA), INC. ICOMPAN¥ REP ' CHARLIE MICHEL :SEPARATOR ' 42' X 15' 80 MMSCFD 8000 BPD IWELL NAME: POINT MCINTYRE NO. 9 :TEST NO. ' SiX (POST FRAC) :GAS METER RUN ' 5,761" W/BARTON 202A RECORDER :AREA : PRUDHOE BAY, ALASKA :iNTERVAL TESTED ' N/A ILIQgID METERS ' 2" OIL, 1.5" OIL, l" WATER t ........................... + ......................... + ............... f ............... + ....................... ~ ...................... + ....... ' TIME DATA i WELL HEAD DATA ' OIL DATA : WATER DATA ' GAS DATA ~ CUM RATE CUM RATE CUM , ,' REAL I DELTA :HTR I RATE , ' ' INC I TEMPi RATE (MSCF ' CUM I DATE TIME I TIME WHP IAP WHT :(MM/DD) (~:MM:SS)I(~OURS) (?SIC) (PSIS) (F) CONMENT5 .... ~ .... ~ ....... ~ ....... ~ ....... ~ ....... r ....... ~ ....... ~ ....... ~ ....... + ....... ~ ...... ~ ......................................................... ' 02/26 02/26 o2/26 o2/26 o2/26 o2/26 o2/26 o2/26 o2/26 o2/26 02126 02/26 02/26 02/26 02126 02/26 02/26 o2/26 o2/26 o2/26 o2/26 o2/26 02/26 02/26 02/26 o2/26 o2/z6 02/26 0~/2~ 02/26 02/26 09:00:00 09:30:00 10:00:00 10:30:00 11:00:00 11:30:00 12:00:00 I2:30:00 12:58:00 13:00:00 13:30:00 14:00:00 14:30:00 15:00:00 15:30'00 16:00:00 16:30:00 17:00:00 17:30:00 18:00:00 18:16:00 18:30:00 18:45:30 19:00:00 19:30:00 20:00:00 20:30:00 21:00:00 21:30:00 22:00:00 22:30:00 60.271 60,771 61.271 61 77i 62 271 62 771 63 271 63 771 64 237 64 271 64 771 65 271 65 771 66 271 66 771 67 271 67 771 68 27i 68,771 69,27I 69.538 69,77! 70.029 70,271 70.771 71.271 71,771 72,271 72,771 73,271 73.771 89 i07 30 78 124 24 26 2 66 2 Ii 1 42 72 46 3,0 1,1 0,2 0,2 0,2 0,2 0,2 0,2 1076.0 1104,5 11!3,8 452.8 335,3 272.8 250,8 187,1 169,4 142,4 148,3 I { 11879,5 3:883,5 3:871,o I{883,0 2:881,9 3:876.9 {869.3 :870.3 ]870,6 {871.o ~7, ~43, 833, 821, 808. 771 729 710 697 687 678 659 680 70~ 787 825 ~34 33.9 34.5 32.8 34.7 35.7 32.! 34.3 34,6 33.5 133.9 6',31.3 6',42.6 9',48,3 5:52,1 4 ',54,2 8:57o o:~05 1:6o~ 6[620 9{633 8:~72 o:3~5 4{360 6{367 9:370 8:37! 9{371 9{373 744.3 706.2 601.2 457.2 329.1 999.2 11948.4 1477,2 } I 597,6 : 3i.3 627,1 ~ ? 671.2 0.0 684.4 0,0 236.1 42.0 817.3 0.0 837,2 0,0 633.4 634.7 635,7 635.7 635.7 63§.7 637,9 637,9 637.9 CLOSE WELL OPEN WELL TO MANIFOLD :OPEN WELL BSW=4.0% {BSW=TRACE, OIL CRAV=31.4 APl BHW=O.0% BSW=O.0% 23 FEB 91 TICKET NO. 007340 PAGE [;0, 2.6 ICOMPANY : BP EXPLORATION (ALASKA), iNC. :COMPANY REP : CHARLIE MICHEL :SEPARATOR : 42" X 15' 80 MMSCFD 8000 BPD IWELL NAME: POINT MCINTYRE NO, 9 :TEST NO. : SIX (POST FRAC) :GAS METER RUN: 5.761" W/BARTON 202A RECGRDER :AREA : PRUDHOE DaY, ALASKA :INTERVAL TESTED : N/A :LIQUID METERS: 2" OIL, 1.5" OIL, 1" WATER + ...........................+ .........................+ ............... + ............... ~ ....................... + ...................... + ....... + ................................................. I TIME DATA : WELL HEAD DATA : OIL DATA : WATER DATA : GAS DATA i ' ~ REAL DELTA ' ' 'HTR ' RATE I I i I i i :DATE I TIME TIME WHP {iAP :WHT :CHK: SEP JlM~/DD)lfH~:MM'SS) (HOURS) (PSIG):(PSIG)r (F) (64): (BPD) + ....... + .......... + ........ t ....... + ...... + ..... + .... + ...... 02/26 02/26 o2/27 02/27 02/27 02/27 oz/27 o2/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 oz/z7 02/27 02/27 02/27 o2/27 23:00:00 23:30:00 00:00:00 00:30:00 01:00:00 01:30:00 02:00:00 02:30:00 03:00:00 03:30:00 04:00:00 04:30:00 05:00:00 05:30:00 06:00:00 06:30:00 07:00:00 07:30:00 08:00:00 08:30:00 09:00:00 09:30:00 10:00:00 10:30:00 11:00:00 11:30:00 IZ:O0:O0 12:30:00 13:00:00 13:30:00 14:00:00 74.271 74.771 75.271 75.771 76 27i 77 271 77 771 78 271 78 771 79.271 79,771 80,271 80,771 81,27i 81,771 82,271 82,771 83.271 83,771 84,271 84.771 85,271 85 771 86 271 86 771 87 271 87 771 88 271 88 771 89,271 138.5 843 5 'n' . i~0.7 17.6 854.I 39,4 55,0 845.3 40,8 226 4 846.9 38.6 155 2 1879.1 39.1 153 7:904.4 39,0 137 21911.6 39.8 135 0 1445 8 38.2 141 9 453 8 :37.8 129,1 460 6 438.1 121,7 465 0 {37.9 141,5 471 8:38.4 159.7 480 6 139.0 128,1 4910 38.7 159,6 501.5 39.6 158.0 512.0 39,6 1711 522.3 39,8 1757 529.4 40.1 I69 I :537,8 40,5 177 7 {545,4 40,6 174 8 {553,6 40,2 1817:556.9 40,5 169 6 {557.8 39,9 170 2:560.9 40.9 147 5 {561,9 39.2 127 2 {560.3 39.5 137,3 172,1 118.4 90.9 130.5 56 56 2O 56 56 56 42 48 48 48 48 48 48 48 48 48 48 48 48 48 48 6O 128 !81 181 18i ;559.6 139.8 ;181 1561.0 139.6 1181 1559.9 138.? 56 1561.9 138,9 56 :565.0 138.9 56 0.0 6i5.2 742.5 11048.5 972,1 $89,3 809.7 '/47,5 669,6 805,9 ' C~H ' RATE ' CUM ' TNK MTR CUM RATE , , , , ' TNK { TNK ]INC TEMP SEP TNK ~ TNK ~ (BBL) (BPD) ~ iBBL i {BPD) { (BBL) : (BBL) (F) ....... + ....... + ....... + ....... + ....... + ....... t ....... J I RATE i(M$CF I CUM , (MSCFD)I/ST8) llMSCF) I COMHE~TS ....... + ...... + ....... ~ ................................................. 0.0 25,6 56.6 i00.3 140.8 211.5 242.'/ '~70,6 304,2 775.5 869.5 i39.3 875.3 II)2.9 925,0 696.0 954.0 725.3 984,2 713 7 607 4 944.7 1ii0.8 ~]4.i 1i5i.3 964.3 855.0 i227.2 t,~.~ 1259.5 ~1~,~ 12~9,~ 639.8 1316.1 41348,9 0.0 0,0 0.0 30.5 22,2 39.7 0.0 7.9 7,3 6.5 8.0 637.? 637.9 637.9 637.) 639.2 640.i 641.1 641.9 643.5 643.5 643,5 643,5 643.9 644,Z 644.4 644,8 0.0 90.6 i07.2 104.4 10i 4 107 7 100 0 .116 8 121 9 0.0 0,000 480.2 0,291 525,i 0,556 558,4 0.573 628.4 1o.652 518.0 529.d {0,681 44Z,} I0,61[ I 471.8 Io.73'/ I 394,3 I0,501 153,4 173.5 195.3 218.6 244.8 266.4 288.4 326.5 343.0 BSW=O.0% DECREASE CHOKE BSW=TRACE, OIL GRA¥:27,~ ~?i, iNCREASE CHOKE DECREASE CHOKE INCREASE CHOKE, BLEED CASING BSW=4.0% DIVERT THROUGH SEPARATOR'2-~HAHIIIG GAS GRAV-0,770 BSW=3,0%, 0G=26,5 APl BSW:4,0%, GG:0,754 SALINITY=24,000ppm INCREASE CHOKE INCREASE CHOKE BSW=.O.%, 0G:27,3 APl, INCRZASE CHO~E DECREASE CHOKE 23 FEB 91 TICKET NO. 007340 PAGL [{0. 2.1 ICOMPAN¥ ' BP EXPLORATION (ALASKA), INC. :COMPANY REP ' CHARLIE MICHEL :SEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD :WELL NAME' POINT MCINTYRE NO. 9 :TEST NO. ' SIX (POST FRAC) :GAS METER RUN ' 5.761" W/BARTON 202A RECORDER :AREA ' PRUDHOE BAY, ALASKA :INTERVAL TESTED ' N/A :LIQUID METERS ' 2" OIL, 1.5" OIL, 1" WATER + ...........................+ .........................f ............... ~ ............... f ....................... + ...................... + .......................................................... , TIME DATA ' WELL HEAD DATA : OIL DATA ' WATER DATA ' GAS DATA DATE (MM/DD o2/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 02/27 o2/27 o2/27 o2/27 02/27 o2/27 o2/27 02/27 02/Z7 02/27 02/27 02/28 o2!28 02/28 o2/28 o2/28 02128 02/28 o2/28 o2/28 o2/28 02/28 ' ' :HTR REAL DELTA , , TIME TIME WHP I IAP ',WHT :CHK (HH:MM'SS) (HOURS) (PSIG)',(PSIG): (F):(645 (BPD) (BHL) : {BPD} (BBL) {HPD) I (BBL) (BBL) I (F) ........... {' ........ + ....... {' ......+ ..... f .... {' ....... + ....... + ....... t ............... {- ....... {- ....... {- ....... 14:30:00 89.771 15:00:00 90.27! 15:30:00 90,771 16:00:00 91,271 16:30:00 91,771 17:00:00 92,271 17:30:00 92,771 18:00:00 93,271 18:30:00 93,771 19:00:00 94,271 19:30:00 94,771 20:00:00 95,27i 20:30:00 95,771 21:00:00 96,271 21:30:00 96,771 22:00:00 97,271 22'30:00 97,771 23:00:00 98,271 23'30:00 98.77i 00:00:00 99,271 00:30:00 99 771 01:00:00 100 271 01:30:00 100 771 02:00:00 101 271 02:30:00 I01 771 03:00:00 lOZ 271 03:30:00 102 771 04:00:00 103 271 04:30:00 103,771 05:00:00:104,271 05:30:00 1104.771 70.0 ;568.! 105.2 {565.5 139.0:569.5 123.3 1577.3 102,0 1581,0 51,7:567,9 123,6 557 98.7 561 91.7 562 80,0 563 75.5 566 50,4 560 134,9 563 95.0 575 6 i73,2 589,8 49,8 598.5 99.8 587.8 116 4 579,4 839:565.9 68 7:555.1 52 5:540.8 101 I {528,3 1712 {536,5 1240{545.4 129 7:550 6 132,8 558 0 123,9 563 3 116.6 565 5 113.8 565 6 126.4 566 9 38.6 38.5 38.8 38.9 38.2 40.9 9 37 3 5137 1 01367 1{371 6138 0 61434 6 38 3 38 6 39.6 39,9 37.1 37.1 37,2 37,4 37,6 40,7 37,7 37.0 :37.4 137,5 137.6 137.2 137.7 :37.6 56 56 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 RATE CUM : RATE CUM RATE : CUM TMK : MTR :TOTAL:GOR : ' RATE :(MSCF ' CUM SEP SEP I TNK TNK TNK { TNK INC I TEMP , , :(MSCFD):/STB) :(MHCF) COMMENTS ~ ....... + ...... + .......................................................... 722.9 801,3 410,1 272.5 664.9 318,8 859 ? 862 3 560 4 524 9 z~z I 699 4 944,6 863,4 3J4,3 367,7 354,8 3~6.1 423.8 437 i 472 9 5O8 9 532 2 554 I 564 2 593,3 632.7 668.6 - 698.2 69~.7 137~.i 767.5 14i0.0 383.8 1426.0 659 3 ' . ,14,6.0 301,9 805.3 825,0 ~46,? :i579.3 218,8 '1608,7 715.7 795.3 :i671.7 815.3 11705,7 6%.0 {1734,7 ?.i 7.8 3.9 6.7 26.5 58,6 134.4 59.3 68,6 12,5 108,0 !5.4 12.5 7.7 645,i 645.4 645,6 645,8 646.i 647,2 649.6 655,2 65?,? 660.5 66i.i 665,6 666,2 666,7 667,0 2.4 5.6 2.5 2.9 0,5 4.5 0.6 0.5 0.3 153.4 112.3 124,4 111,8 108.2 98,5 96.9 97.3 11~.3 1i3.6 i12.6 109.4 105.2 103.0 108.5 505,1 0,723 507,~ 0,462 480.7 11,253 I 357.5:0,660 392,2 0,595 278.9 0,924 383,1 0.476 542,9 0,658 435,2 453,9 0,932 263,2 i,203 309.5:0,432 545.0 10,685 499.8 10.613 466,9 10,671 364,0 385.2 405,2 709,2 DECREASE CHOKE GG:O.730 ~17:15 BYPASS SEPERATOR I~17:24 DIVERT TO SEPERA~OR:2-PHASIHG 420,i, { 436.4 :BSW=I.0%, GG:O,706 I 1 448.1 {BSW=S% :E/L RIH, BEGIN 3-PHASING THE SEPARATOR 464.0 IBSW=20.0%, GG=0.728, 0G=28.9 APl 486.6 504.8 523.7 534.7 BSW=4.0% BSW=6.0%, GG=0,748, 0G:27.9 APl BSW=3.0% BSW:20,0%, CHLORIDES=2i,O0 p~z 547.5 :BSW=l.5%, GG=0,676, 0G=26.4 APl i 570.3 :BSW=O.?5%, GG=0,768, 0G:27,7 APl 591.1 610.5 IBSW=0.2§%, GU=0.770, 0G=26.7 APl I 23 FEB 91 TICKET NO. 007340 PAGE IiO. 2.8 ICOMPANY ' BP EXPLORATION (ALASKA), iNC. :COMPANY REP ' CHARLIE MICHEL :SEPARATOR ' 42' X 15' 80 MMSCFD 8000 BPi {WELL NAME: POINT MClNTYRE NO. 9 {TEST NO, ' SIX (POST FRAC) :GAS METER RUN ' 5.761" W/BARTON 202A RECORDER IAREA ' PRUDHOE BAY, ALAHKA IINTERVAL TESTED · H/A ILIQUID METERS ' 2" OiL, 1.5" OIL, 1" WATER + ........................... + .........................+ ............... + ............... + ....................... + ...................... + ........................................................ ' TIME DATA ' ' OiL DATA , , WELL HEAD DATA , i , GAS DA~A + ....... + .......... + ........ + ....... + ...... + ..... + .... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ...... + ....... REAL DATE TIME (NM/DD) (HH:RM:SS 02/28 06:00:00 02/28 06:30:00 02/28 07:00:00 02/28 07:30:00 02/28 08:00:00 02/28 08:30:00 02/28 09:00:00 02/28 09:30:00 02/28 10:00:00 02/28 10:30:00 02/28 11:00:00 02/28 11:30:00 02/28 12:00:00 02/28 12:30:00 02/28 13:00:00 02/28 13:30:00 02/28 14:00'00 02/28 i4:30:00 02/28 15:00:00 02/28 15:30:00 02/28 16:00:00 02/28 16:30:00 02/28 17:00:00 02/28 17:30:00 02/28 18:00:03 02/28 18:30:00 02/Z8 19:00:04 02/28 19:30:00 02/28 20:00:00 02/28 20:22:00 02/28 21:00:00 DELTA TIRE ......... + ....... + ...... + ..... + .... ~ ....... 105.271 105.771 106.271 106.771 107.271 {108.271 {108,771 {109,771 1110.271 1110.771 111 271 111 771 112 271 112 771 113 271 I13 771 114.271 114.771 1115,271 {115.771 :116.271 {116.771 :117,272 1117,771 1118.771 :119,271 {120,271 I I 'lAP WHP, (PSIG) :HTR:RATE { CUM :RATE : CUM :RATE { CUM 'CHK: SEP ' SEP ' TNK ' (F) I(64)', (BPD): (BBL}{ (BPD) : (BBL) i (BPD): (BBL) TNK INC (BBL) MTR YEMP (F) 0.6 103.9 i02.8 119.7 TOTAL:GOR RATE I(MSCF (MHCFD),/HTB) CUM (MSCF) '37 102.2 1569,3 82,4 568.6 137 147,3 569,9 137 61.4 565,6 139 5 1i7.0 554.8 :37 7 88.5 556.! {36 8 83.4 553.8 37.2 139,7 561.3 37.6 128.2 569.4 38.0 136,8 578.0 37.9 124.4 583,9 37,9 122.0 584,8 37.9 117.3 {583,6 37,9 124.9 1584.0 38.0 122.5 {584,0 38.9 97.7 1581.1 37 150,4 585 3 101,0 585 3 137 9 85,4 579 9 138 4 82,8 576 0:38 2 127,5 579 8 137 8 88.0 581 3 {38 1 104,2 579 S {37 8 99,6 578 0:37 4 134.9 582 8:37 124.6 582 131,4 579.4 137 0 148,{ 585,3 37.6 167,3 592,4 38,0 278,8 568,8 29,1 48 762.6 48 48 696.8 48 48 371,5 48 48 548.2 48 48 941.5 48 48 816.7 48 48 722.9 48 48 761.7 4S 48 733.0 48 48 527.3 48 48 652.3 1013,1 48 48 6i8.0 1038.8 48 48 739.2 :1069.7 48 tU f06.0 I10~0,8 I 48 48 785.6 48 ' I i I ii,4 667.6 CORMEHTS ...+ ....... + ...... + .......................................................... 631.4 BSW=TRACE 646.2 BSW=0.4% 735.7 i765,3 636,2 179!.3 730.0 759.0 798.3 $37,5 871,5 901,7 933,4 963.9 935.) 501.2:0.681 '0.559 355.3, 358,5 {1.061 536.7 11828.3 904,5 11866.0 745.5 1897.0 735,7 I'~27.7 457.2 { i i?2,o 8 :z~o~, I i 875.8 :2142,2 461,i {2149,3 ! 34.I 8,1 669.1 672.7 675.4 0.4 1.1 3.6 2,7 111.5 98,0 107,3 120.2 121.8 ii0.8 130.5 122.5 i29.7 119.8 127,1 117.4 394.6 0,735 425.2 0.470 495.2 0.664 503.1:0.684 514 6" . ~0.,~6 456 4 471.3 41.031 393,0 0.638 460.4 0.827 424,6 0,578 40~.5 0,858 397,2 0.453 41},8 0.}10 661.2 :BSW=6.0%, GG=O,?32, 0G=26.7 APl 677.6 {BSW=7.0% 'BSW=4.0% 695.3, 716,0 IBSW=4,0%, SALINITY=27,000ppm 736.9 758.4 BHW=I.O%, SALINITY=27,000ppm BSW=I.5% 777.4 797.0 813,4 832.6 BSW=5.0%, GG:0.728, 0G:26,9 APl BSW=2.6% BSW=5.0% BSW=4.0% 850,3 BSW=2,0% 867,3 IBSW:8,5{, U8:0,758 883.9 8}0,3 CLOHE WELL FOR 8YEP RATE INJECTION TEST FREEZE PNOTECTING 23 FEB 91 TICKET NO, 007340 PAGE NO. 2,9 {COMPANY ' BP EZPLORATiOR {ALASKA), iNC. 'COMPA}{T REP · CHARLIE MICHEL iSEPARATOR · 42" Z 15' 80 MMSCFD 8000 I~ELL NAME: PO!HT MCINTYRE NO. 9 ~ZST !}0, ' SIZ {POST FRAC) iGAH METER R~N ' 5,761" W/BARTON 202A RECCRDER {AREA ' PRUDROE BAY, ALASKA iINTERVAL ?ES~£D ' N/A iLIOUID METERS ' 2" OIL, !.5" OIL, i" WATER ~ ........................... * .......................... ? ............... t ............... T ....................... T ...................... + ......................................................... : TIME DATA ' ~ELL HEAD DATA ~ n" , ~=~ DATA WATER DATA I GAS DATA + ....... + .......... + ........ ~ ....... t ....... ~ ..... t .... t ....... + ....... ~ ....... r ....... t ....... + ....... + ....... ~ ....... ~ ....... T ...... ~ ....... ' REAL DELTA i i TiHE TIRE DATE , (MM/~D):(H~:MM:SS} (~OURS) 02/28 OZ/Z8 O2/28 02/28 02/28 o2/28 o2/28 02/28 03/0i 03/01 03/01 03/01 o3io~ 03/01 03/01 03/01 03/01 03/01 o3/o~ 03/0! o3/o~ 03/01 03/01 o3/ol 03/01 03/01 o3/ol 0310! 03/01 03/01 03/01 21:30:00 i120.7~i 22:00:00:121,271 22:30:00 1121.77i 22:44:30 1i22,012 23'00:00 ' ~ ~ 23:23:0~ 1122,654 23'30:00 122 771 23'51:00 123 12! 00:00'00 123 271 00:22:00 i23 638 00:30'00 i23 771 01:00,00 124 271 01:I5:00 124 521 01:30:00 I24.77! 02:00:00 1125,271 02:30:00 II25,~z 03:00:00 4126,271 03:30:00 Ii26,77i 04:00:00 1127,271 04:30:00 1127.771 05:0~:00 1!28,27i 05:30:00 1128,771 06:0~:00 1i29.27I 06:30:00 1129.771 07:00:00 1i30,271 07:30:00 4130.771 08:00:00 }131,271 08:30:00 1131.771 09:00:00 1132.271 09:30:00 1132.771 10:00:00 4133.271 ~HP lAP i WHT {PSIG) ~ ....... ~ .... ~'-T ..... i053.0 1014,0 14.6 62,4 2181 2355 !22 i? i6 16 293.3 181.2 243.3 i32.4 i82.2 113.8 97,1 122.3 !44.7 126.0 !31.I 119.5 104.8 129 7 136 6 iZ9 1 132 8 127 7 141 3 132 8 49i.3 ;39.6 460.9 '44,5 '48.9 i574.4 , ~84,9:19 3 0 i782 3 149 6 9:1744 1 {47 8 9 1444 4 47 i 381,8 45.0 402,6 41.7 421,1 42.2 438,6 40.9 448,5 40.6 459,9 39.5 474,4 40,4 483 4 39 2 490 4:38 9 496 4 238 7 50i 8 i~8 4 507 i :38 7 509 6138 4 510 ~ 138 ~ 516 3 138 5 52Z 3538 { 525 3 138 5 527 9 38 4 531 § 38.4 535.9 38.5 {6491 (BPD) i {HHL) ? .... + ....... ~ ....... . ....................... 4~ 56 43 48 0,0 4~ 48 48 ~8 48 ~8 ~ -~,, ' CUM ' TNK RATE P~" ' RATE , TNK } T~K ~ TNK :. TNK I iNC (BPD) ii45,0 i184.9 i220.5 ~6Z,0 1315,2 669,3 £343.1 847.2 {1378.4 0.0 924.5 2'~= ~ ~64o3 2215.3 ~94.3 2255.6 ~95.3 4222,5 0.0 725.7 12404.8 775,3 '2437.i 835.0 835.5 835.5 I 16.31839,5 I { 4.1 i MTR TOTAL:GOR TERP RATE :(MSCFI CUM (F) (MSCFD)',/HTB)i{MSCF) 123.0 !08.6 i10,3 113.2 ii5.4 ~8.7 111.5 0.0 0,605 612.4 568.2 0,635 549,8 i0.69I 512.2 40i,4 454.5 483,5 390,~ 907,3 933.3 )§7.0 979.9 O,ddO 1001.2 .0,72I :10i7.9 I ,' .626 11056.6 ,' .624 41076.7 COMMEHT£ OPEN WELL - EST, BLEED CASING OFF. OiL 70 SHRFACE - =t .... " " BS~=6,0%, 0G=26,9 A~i HHW=?RACE BSW=0.25%. OG=27.d A?i BSW=O.0%, GG:0,764 BSW=2.O{ BSW=3.5%, 0G=27.6 APl BHW=i.§) 23 FEB 91 TICKET NO. 007340 PAGE NO, 2.10 {COMPANY : BP EXPLORATION (ALASKA), INC. ICOMPANY REP ' CHARL!E MICHEL {SEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD IWELL NAME' POINT MCIRTYRE NO. 9 iTEST NO. ' SIX (POST FRAC) IGAS METER RUN ' 5.761" W/DARTON 202A RECORDER {AREA ' PRUDHOE BAY, ALASKA {INTERVAL TESTED ' N/A {LIQUID METERS ' 2' OIL, 1.5' OIL, 1" WATER + ........................... + .........................t ............... + ............... + ....................... + ...................... + ......................................................... ' TIME DATA ' ' , , WELL HEAD DATA , OIL DATA 4 WATER DATA ' GAS DATA + ....... + .......... + ........ + ....... + ...... + ..... + .... + ....... + ............... v ....... + ....... + ....... + ....... + ....... + ....... + ...... T ........ ' ' ' TNK ' MTR ' TOTAL ' ' ' '~ ' RATE CUM RATE i CHH , RATE I CUM , , , REAL DELTA { , , ,HTR , ~ ' ' ' CUM ' {HP ~ lAP ' WHT {CHK: HEP ~EP TNK ' TNK i TNK { TNK { DATE TIME TIRE , , ~., ' ' INC 4 TERP , RATE {(MSCF {(MM/DD) (HH:MM:SS)(HOURS){(PSIG)I(PSIG){ (F){(64){ (BED) (BBL) (BPD) : {BBL) i (BPD) { (BBL) { (BBL) { (F) {(RSCFD){/STB){{MSCF} COMMENTS + ....... + .......... + ........ + ....... + ...... + ..... + .... + ....... + ............... + ....... + ....... + ....... + ....... + ....... + ....... + ...... + ......................................................... o3/ol o3/oi o31o! o3/oi o3/o! o3/ol o3/ol o3/ol 03/01 o3/ol 03/01 03/01 o3/01 03/01 o3/o! 03/01 03/01 03/01 03/01 03/01 03/01 03/0! 03/01 03/01 03/01 03/01 03/01 03/02 03/02 03/02 03/02 10:30:00 II:00:00 11:30:00 12:00:00 12:30:00 13:00:00 13:30:00 14:00:00 14:30:00 15:00:00 15:30:00 16:00:00 16:30:00 17:00:00 17:30:00 18:00:00 18:30:00 19:00:00 19:30:00 20:00:00 20:30:00 21:00:00 21:30:00 22:00:00 22'30:00 23:00:00 Z3:30:00 00:00:00 00:30:00 01:00:00 01:30:00 I 4133.77i ,z34.zTz 4135.271 4135.771 {136 271 i36 771 137 27I 137 771 138 271 138 771 139 271 139 ?' 140,271 1141,771 1142,171 1143,271 ,143,i?~ {144,271 4144.771 i145,271 146,771 147.271 147,771 148.2V1 14~.771 114.4 118.7 130.5 114.7 95.8 118,3 127,0 i03,7 111,0 106,9 141.8 98.6 140,2 136.0 165,3 107,6 I77,1 106,4 61,1 138,3 156,6 169,3 84.2 155.7 76 50 2 42 4 4O 1 38 4 37 8 37 5 I 540.1 {38.4 544.1 }38.2 551.5 38.0 554.1 38.8 552,9 38.6 553.9 38.2 559.5 39.0 {560.6 39.3 560,6 138.4 559.I 137 6 565,8 {38 i 571,8 {37 5 5?8,0 138 4 584,3 {39 0 595 5{39 4 600 4:38 8 597 4:40 7 600 8:39 1 588 8 43.8 587 6 38,8 600.8 39,8 611.3 39,9 ]612.5 38.9 1611.8 39.5 {594.6 51,8 {572.6 80.5 ]797,9 77,4 1664.8 ?6,4 1388.0 75,4 {264.9 75,6 4173.9 {75.9 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 812.0 11412.3 795.3 {24?0.2 845 3 11447 5 815 0 ,~n~ 2 . , , I { 636.4 {1474,0 654.0 1501.2 639.7 1527,9 876.4 1544,4 850.3 1599.8 900.8 1637.4 810.6 I1671.2 576,? 2 806.5 626.2 2579.5 82§.0:2613.9 i 785.3 12446.6 864.8 26~? 7 i ,0, 3 , ,=715, ~3~ 0 '~ ' . ,~.3 ~, 546 2 { { { . , 48 41091 9 41738 9 41033 I 815.3 {i?72.9 745.5 2313.1 31.5 3.5 848.1 849.i 115.5 I16.3 i18.6 119.9 8.5 i15.1 101.6 90.7 107,3 110.5 1.0 L 115.5 !03.9 111.I 490.6 529.8 0.650 438.4 0.760 449,2 {0.74i 438.8 {0.?01 524.6 {0.636 I 0.6i7 :1097.2 1119.2 1i37.5 i156.2 1174.5 1196.4 BSW=0,5% BSW=0.3% BSW=4,0% BSW1.5% :BSW=6.0%, GG=O.140 501,9 578,6 583.2 439,3 542,3 576,9 0.639 41217,3 I I 0.669:1241,4 0.743 I1265.7 {BSW=0.S% I 0.~04 41284.0 {BSW=I.0%, GG:O.744, 0G:25.4 APl 0.524 1306.6 0,754 1330.6 CLOHE WELL - FREEZE PROTECT 23 FEB 9I TICKET NO. 007340 PAGE I;0, 2.11 ICOMPANY : BP EXPLORATION (ALASKA), INC. ICOMPAN¥ REP ' CHARLIE MICHEL ISEPARATOR ' 42" I 15' 80 MMSCFD 8000 BPD IWELL NAME' POINT MCINTYRE NO. 9 iTEST NO. ' SIX (POST FRAC) IGAS METER RUN ' 5.761" W/BARTON 202A RECORDER IAREA : PRUDHOE BAY, ALASKA IINTERVAL TESTED ' N/A {LIQUID METERS : 2" OIL, 1.5" OIL, I" WATER ........................... + ......................... f ............... + ............... + ....................... f ...................... f .......................................................... TIME DATA ' WELL HEAD DATA { OIL DATA , , , WATER DATA GAS DATA ....... + .......... + ........ } ....... + ...... ~ ..... + .... } ....... ~ ....... + ....... + ....... + ....... } ....... f ....... } ....... + ....... ~ ...... + ........ ,' REAL DELTA : ,' ,' IHTR RATE CUM RATE : CUH RATE CUH TNK HTR TOTAL : GOR i WHP '/AP : WHT :CHK SEP SEP TNK , :(MM/DD):(Hf:MM:SS) (HOURS):(PSIG):(PSIG): (F):(64) (BPD)(BSL) (SPD):(~n) (~PD) (~DL)(BBL)(F)(MSCFD):/m) {MSCF) COMHENTS ....... + .......... } ........ ~ ....... + ...... } ..... ~ .... f ....... t ....... f ....... + ....... + ....... } ....... ~ ....... ~ ..................... ~ ....... ~ ................................................. o3/o2 03102 03/02 o3/o2 o3/o2 03/02 o3/o2 o3/o2 o3/o2 03/02 o3/o2 03/02 o3/o2 o3/o2 o3102 o31o2 o31o2 03/OZ o3/02 03/02 o3/o2 o3/o2 o3/02 o3/o2 03102 o3/o2 o3/o2 o3/o2 03/02 03/02 o3/o2 I I 02:00:00 1149.271 02:30:00 1149.77! 02:32:00 1149.804 03:00:00 1150.271 03:30:00 04:00:00 1151.271 04:30:00 I51 771 05:00:00 152 271 05:15:00 152 521 05:30:00 152 77! 06:00:00 153 271 06:30:00 153 ?71 07:00:00 1154.271 07:30:00 {154.77i 08:00:00 1155.27I 08:30:00 {155,771 09:00:00 1156,271 09:30:00 1156.77i 10'00:00 {157,271 10:30:00 1157,771 11:00:00 {158,271 11:30:00 1158.771 12:00:00 {159.271 12:30:00 {159.771 13:00:00 {160.271 13:30:00 1160.771 14:00:00 161.271 14:30:00 161.771 15:00:00 162.271 15:30:00 162.771 16:00:00 163.271 3?.2 37,2 36.9 1006.5 951 3 921 8 9O3 8 891 8 88? 0 12 4 10,0 9,3 9,2 8.7 8.4 8,3 8,6 8.4 8.3 8,3 8,8 O0 24 11 2 13 1 25 0 61 ~ 102 6 110 8 113 2 69 6 112.8 30.3 28.4 23.2 22,2 21.4 21.4 20,6 19,1 27.3 130 6 155 6 173 8 187 3 199 0 208 4 215 5 1221.3 {225.3 {233,0 {234,9 1253.o I265,8 1311,1 {35?.8 1388.9 14oo.5 I I :76.3 176.7 :77,2 ?6,8 ?6,9 ?7.2 ?7.2 52.0 5O 6 :4e 5 1477 1471 46 5 45 9 45,3 44,8 44.2 43.? 43,1 43.8 42,5 33.0 25,7 42.2 42.6 41.9 {42,9 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 48 128 128 :120 :120 0,0 28i3.1 0.0 2813,1 0.0 12813.I 0.0 12813 1 0 0 ,?,l~ I , 0.0 12813 2 i 0.0 }2~i3.i 0.0 {2813.1 0.0 128i3.1 0.0 {2813.1 14.3 12813,7 [ 75.1 {28!6.9 I 158.7 {2823.5 0,0 849.1 1763,5 867.5 561.1 879.2 561,1 890.8 56i.1 902.5 3?0.? 9i8.0 330.? 931.8 320.~ 945,1 300,5 957.6 661.2 985.2 i60.3 988.5 320.6 995.2 707.0 1024.7 1437,3 1084,6 411.3 II101,? OPEN TO MANIFOLD MONiTORiNG PUMPING I :EST. 150 BBLS DIESEL AND 220 BBLS H20 PUMPED }OPEN WELL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEL FLOWING 100% DIESEC FLOWING 100% DIESEL FLOWING 100% DIESEL BSW=IO0.0% (50:50 H20:DIESEL) OIL YO SURFACE START INJECYING N2 ~ 2006cf/min, BSW=98.01 H20 BSW=95.0% 'BSW=72.0% 23 FEB 91 TICKET NO. 007340 PAGE NO, 2.12 ICOMPANY : BP EXPLORATION (ALASKA), INC. ICOMPAN¥ REP ' CHARLIE KICHEL ISEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD IWELL NAME' POINT MCINTYRE NO. 9 ITEST NO. · SIX (POST FHAC) IGAS METER RUN ' 5.761" W/BARTON 202A RECORDER IAREA : PRUDHOE BAY, ALASKA IiNTERVAL TESTED · N/A ILIOUID METERS ' 2" OIL, 1.5" OIL, 1" WATER q ........................... q ......................... + ............... ? ............... + ....................... + ...................... + ....... ~ ................................................. ' TIME DATA ' WELL HEAD DATA , , , , , , OIL DATA WATER DATA GAS DATA ,' REAL DELTA I ,' ,' IHTR RATE CUM RATE I CUM RATE I CU~ THE ~TH TOTAL I GOR ' THE T~K I THE I~C TE~P ~ATE :(~SCF (ltK/DD)I(HK:Ifl(:SS) (HOURS)J(PSIG):(PSIG): (F):(64) (BPD) (DBL) (BPD): (BBL) (BPD): (BBL) (BBL) (F) (HSCFD)J/STB) (HSCF) COMMENTS 03/02 16:30:00 03/02 17:00:00 03/02 17:30:00 03/02 18:00:00 03102 18:30:00 03/02 19:00:00 03/02 20:00:00 03102 20:30:00 03102 21:00:00 03/02 21:30:00 03102 22:00:00 03102 22:30:00 03/02 23:00:00 03102 23:30:00 03/03 00:00:00 03103 00:30:00 03/03 01:00:00 03/03 0I:30:00 03/03 02:00:00 03/03 02:30:00 03~03 03:00:00 03103 03:30:00 03/03 04:00:00 03/03 04:30:00 03/03 05:00:00 03/03 05:30:00 03101 Q6:QQ:QO 03/03 06:24:00 03/03 07:08:00 03/03 08:00:00 03/03 08:02:45 I I 4163.771 1164,271 1164.?71 1165,271 165.?71 166 271 167 271 167 771 168 271 168 ??1 169 271 169 ??! I70 271 170 ??I 1171,271 4172.271 1172.?71 1173.27i 1173.771 1174.?7i 1175.271 1175,?71 1176.271 1176,??1 1I??,671 1178,4o4 1179,271 86.7 59.9 81.? 445,1 115.8 1455.9 41.1 1460,6 { { !88,2 151i,o 156.4 1530,3 99,1 1540,8 95.6 1543,8 117.2 1547,5 I I I I 411.3 141,3 1128 432.8:41.4 1128 40.? 128 42.2 128 41.1 128 128 42.7 I28 41.2 128 41.1 128 41,6 128 i10,5:553,9 140.6:128 79,2 555 8140 190.3 569 1142 170,3 580 9:42 102,4 585 0139 26,5 586 8:38 122,1 593 5140 107.2 595 4 39 128,8 5974 407 182,5596.8 41,7 114,8590,8 40,2 0,0 582.4 40.4 87,8 5?5.8 39,0 84,9 576.9 39.0 176.7{621,448,5 3?6,81610,844,5 39,5 1610,939,1 I I I I 50.? [564.9 3?.4 1:128 1:128 41128 74128 o:128 84128 5 128 128 128 128 128 128 128 I28 128 128 128 128 I I I I 435.4 12841.6 I 282,3 12853.4 I I 304,2 2866.1 465,2 2885.4 715,8 2915,3 536.8 2937.6 536.8 2960.0 1014.0 {3002.3 I I 345.7:3016.7 I I 841.1 13051.7 638.? {3078.3 I I 515.7 13099.8 I 656.3 43127.1 :1368.3 3184.2 312.6 3198.9 249.9 3207.9 I t I 292.6 11113.9 426.8 1131.? 374.7 1147.3 573.1 1171.2 180.4 1178.7 180.4 J1186.2 I 180.4 J1193.? { { 180.4 J1201.2 { 47.5 11203.2 I I 94.2:1207.1 8~.8 {1210.8 I 51.4 11212.9 49.8 1215.0 103.8 1219.3 3.2 1219.5 2.3 I219.6 :BSW:40.O{ BSW=60.O% BSW=55.0%, DATA ACOUISITION ON LINE BSW=20.0% BSi:25.0% 'BSW:25.0% BSW=I5.0% BSW=I2.0% BSW=IO,0% {BSW:I2.0%, STOP N2 INJECTION BHW:9.0% BSW:?,0% BSW:?.Ot OEIEIATON DOW! SHUT DOWN SCAN BSW=i.0% SCAN BACK ON LINE 23 FEB 91 TICKET NO. 007340 PAGE NO. 2.13 ICOMPAN¥ : BP EXPLORATION (ALASKA), INC. ICOHPAN¥ REP ' CHARLIE MICHEL ISEPARATOR : 42' X 15' 80 lflISCFD 0000 BPD IWELL NAME: POINT MCINTYRE NO. 9 ITEST NO. ' SIX (POST FRAC) IGAS METER RUN :'5.761" W/BARTON 202A RECORDER IAREA : PRUDHOE SAY, ALASKA IINTERVAL TESTED ' N/A ILIQUID METERS ' 2' OIL, 1.5' OIL, 1' WATER } ........................... } ......................... + ............... + ............... + ....................... + ...................... + ....... ~ ................................................. " TIME DATA ~ WELL HEAD DATA ~ , , OAS DATA ~ ~ , OIL DATA ' WATER DATA ~ ~ REAL DELTA I ,~ ," IHTR RATE CUM RATE CUM RATE I CUH TNK HTR I TOTAL I GOR I (MM/DB I(HH:MM:SS)(HOURS)I(PSIC)I(PSIG)I (F)I464) (BPD) (BBL) (BPD) (m) (BPD) I(m)(BBL)(F) I(MSC~O)I/STB)I(USC~) o3/o3 03/03 o3/o3 03/03 03/03 o3/o3 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 03/03 o3/o3 o3/o3 o3/o3 o3/o3 03/o3 03/03 03/03 03/03 03103 O31O3 08:30:00 09:00:00 09:30:00 09:42:00 10:00:00 10:30:00 i1:00:00 11:30:00 I2:00:00 12:i2:00 12:30:00 13:00:00 13:30:00 14:00:00 14:30:00 15:00:00 15:30:00 16:00:00 16:30:00 17:00:00 17:30:00 18:00:00 18:16:00 18:30:00 19:00:00 19:30:00 20:05:00 20:30:00 21:00:00 21:30:00 22:00:00 I I 1180.771 1180.971 1181.271 181.771 182.271 182.771 183.271 183,471 183.771 184.271 1184.?71 9185.271 1185.771 1186,271 1186,771 1187.271 187.771 188.271 188,771 189 27i 189 538 189 771 190 271 190 771 191 354 191 771 192 271 192 771 193.271 I4,8 559.6 8,9 546.5 83.6 539.8 139.5 539.6 1.6 1684.1 1,6 {665,5 1,8 1585,1 2.2 4510.0 2.1 389.6 11112.5 355,0 241,0 342.9 184,5 404,8 54,1 474,5 2,8 515.0 2,8 523.4 100,8 527,4 69,4 566,1 33 14609.1 109 5{638.8 50 2{688.0 77 6 1688,8 71 8 [685.6 )? 0]688.3 149 5{693.0 123 2 4712.9 318 3{749.4 235,5 275.5 257.3 232,2 235.9 I I I I 136.9 4128 {38.7 4128 37,4 I28 3?.6 128 48.2 60.6 67.8 :72.5 174.5 16o 3 149 ? 48 {46 4 96 144 81128 148 o1128 157 71128 42 3 128 41,2 128 36.7 128 35,2 128 43.4 128 42,9 128 41.1 128 42,9 128 39.8 128 40,9 128 45.5 1128 18o8,3 144,5 llZ8 1864.0 147,3:128 1894,3 147,2 1128 1918.1 {46.9 1128 {948,1 {46,0 4128 I I I 384.1 13224.0 788.i }3246.9 0,0 3246,9 2633.3 {3334.7 544.0 {3357.4 } 662.6 13385,0 11206.8 13435,3 '3449.8 347.9, 535,9 3472.1 1105,4 11564,7 3588.8 { { 41422,8 3643.1 { 11272,4 43696.1 I , I t 3.5 {1219.7 7.2 1219.9 0.0 11219.9 I 13,3 41220.4 I 2.8 11220.5 3.4 11220,6 6.1 1220.9 1052.1 1264.7 231.5 1274,4 2?8.5 1286.0 235.? ! I 358.5 41310.3 I I 320.6 41323,7 COMUHTS ' BSW:O.9% CLOSE WELL FOR ACID TREATREHT I I I IEST. 77 BBLS ACID,15 BBLS SEAWATER,5? BBLS DIESEL, {AND 22 BBLS METHANOL PUMPED {OPEN WELL - POSY ACID TREATNENT {INCREASE CHOKE {BSW=0.5%, INCREASE CHOKE BSW:O.5% :BSW:O.5% BSW=0.SI BSW=75,0% BSW=30.0% START INJECTING N2 t 200scf/min IBSW=20.0% I I I { {BSW=20.0% {CTU P.O.O.H. IBsw=2o.ot 23 FEB 91 TICKET NO, 007340 PAGE NO. 2.14 ICORPAN¥ : BP EXPLORATION (ALASKA), INC. ICOMPAN¥ REP ' CHARLIE HICHEL ISEPARATOR ' 42' I 15' 80 MMSCFD 8000 BPD IWELL NAME: POINT MCINTYRE NO. 9 ITEST NO. ' SIX (POST FRAC) IGAS METER RUN : 5.761" W/BARTON 202A RECORDER {AREA : PRUDHOE BAY, ALASKA IINTERVAL TESTED ' N/A ILIQUID METERS ' 2" OIL, 1.5" OIL, 1' WATER ~ ~ WELL HEAD DATA I OIL DATA " ~ ~ TIME DATA ~ , WATER DATA , GAS DATA REAL DELTA ,~ IHTR RATE CU~ RATE ,~ CUM RATE CUM TH ~TR TOTAL IGOR (~/DD)i(HH:MH:~S) (HOURS) (PSIS)I(PSIG) (~)I(64) (BPD) (BBL) (BPD) I(Bn) (BPD) (m) (m) (~) (MSC~D)I/m) (MSC~) COMMENTS ~ ....... ~ .......... ~ ........ f ....... ~ ...... ~ ..... ~ .... f ....... + ....... + ....... f ....... ~ ....... ~ ....... ~ ....... f ....... f ....... f ...... + ....... + ................................................. 03103 03~03 03~03 03104 03/04 03/04 o3/04 o3/o4 03104 03/04 o3/o4 o3/o4 o3/o4 o3/o4 o3/o4 03/o4 o3/o4 o3/o4 o3/o4 o3/o4 03104 03104 03104 o3/o4 o3104 03/04 03/04 03/04 o3104 o3/o4 03104 22:30:00 193,771 23:00:00 194.271 23:30:00 1194.771 00:00:00 1195.271 00:30:00 1195,771 01:00:00 1196.271 01:30:00 1196,771 02:00:00 197,271 02:30:00 197,771 03:00:00 198.271 03:30:00 198.771 04:00:00 199:271 04:30:00 199,771 05:00:00 200,271 05:30:00 200,771 06:00:00 201,271 06:30'00 201,771 07:00:00 202,271 07:20:00 1202,604 07:30:00 1202.771 08:00:00 1203,271 08:30:00 1203.771 09:00:00 1204,271 09:30:00 1204,771 10:00:00 1205.271 10:30:00 1205,771 I1:00:00 1206.271 11:30:00 1206,771 12:00:00 1207.271 12:30:00 1207.771 13:00:00 1208,271 181.1 205.2 168,0 145.1 145.0 160.3 20 9 143 4 167 1 157 2 I67 3 163 8 139 1 155 6 163,0 157,1 156.5 162,7 159,2 176,1 159,0 158.0 163,8 138,5 162,2 142,6 125,2 154,4 165.6 150.8 154.6 I I 964,9 147,0 1128 971.8 {45.8 1128 978,3 144,7 1128 979.9 {44.5 1128 986.8 44,6 128 995,1 44.9 128 1417,5 41.4 128 {424,8 44,1 128 {432,8 45.2 128 {446,0 45,0 I28 1451,6 46.3 128 1465,3 45.5 128 479,4 44.4 {128 490,6 44.6 1128 505,6 {45,3 1128 504,I 147.1 1128 517,1 {44,9 1128 527,1 {46 01128 534,3 {45 81128 534,6 {48 61128 545 3{45 71128 5541{46 11128 560 8{46 01128 565 5145 01128 569 0{46 61128 573 3145.8 1128 576.5 145.2 128 581.0 146.1 i28 584,5 46,7 128 588,9 45,8 128 {592.9 46.4 128 I { I I ,'118!,0:3745,4 { { 11136 2 ~?. , lilT. 7 f t I I 11037.8 13835,9 944,4 3875,3 1127,4 3922.3 1262.2 3974.9 I262.2 4027.4 1114.5 4073,9 1390,1 14131,8 I 0,0 1772.9 1013,2 14174,0 { 896,0 11810.2 1283,9 {4227,5 11278,7 11863,5 11221,5 14278,4 I I I I I I 11~13.Z {19~8,Z 11Z63,6 14331,~ I I {1330.2 II~73.7 {1270.0 4384,o 11287.0 12027,3 11233,5 4435,4 I I I I 12,0 11324.2 { { 127.2 11329,5 116.2 1334,3 50,1 1336.4 126.3 1341.6 110.6 1346,3 110.6 11350.9 { I 59.i 11353.3 { I 121,8 11358.4 I 20.8 11359,3 I I 88,5 11363,0 I I 51.3 11365,1 48.9 1367,1 71,7 1370,1 79.4 1373.4 122,0 114.7 69,1 108.8 110.1 0.0 892.4 936,8 792,6 803,6 894,9 11330,6 0.695 11392,6 0.767 11431.6 I I 0,6ZV j1464.6 0,632 {1498.1 { { 0,726 11535.4 INJECTING {BSW:i.0% BHW=IO.0%, BLEED CAHING BSW=5,0% BSW=IO,0% BSW=8.0% ] :BSW=5,0% I I {BSW:8.0% {DIVERT TO SEPERATOR:2-PHAHING { 185W=2,0%, GG:0,758, 0G:27,1 APl { IBSW=6,4% {BSW:4.0% { } :BHW:3,7% BSW:5.3% BSW:6.0% 23 FEB 91 TICKET NO. 007340 PAGE NO. 2,15 {COMPANY : BP EXPLORATION (ALASKA), INC. {COMPANY REP ' CHARLIE MICHEL {SEPARATOR ' 42" X 15' 80 MNSCFD 8000 BPD {WELL NAME: POINT MClNTYRE NO. 9 ITEHT NO. ' SIX (POSY FRAC) IGAH METER RUN "5.761" W/BARTON 202A RECORDER IAREA : PRUDHOE BAY, ALASKA {IHTERVAL TESTED ' N/A {LIOUID MEYERS ' 2" OIL, 1.5" OIL, 1" WATER + ...........................+ ......................... + ............... + ............... + ....................... + ...................... + ....... + .................................................. { ' TIME DATA ' WELL HEAD DATA , ~ , GAS DATA , , OIL DATA ' WATER DATA ' + ....... + .......... + ........ + ....... + ...... + ..... + .... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ....... + ...... + ....... REAL DELTA , HTR RATE CUM RATE CUM {RATE CUM TNK MTR I TOYALIGOR DATE TIME TIME { WHP IAP {HT CHH SEP SEP TNK TNK i TNK TNK INC TEMP iRATE I(MSCF CUM (MM/DD) (HH:MM:HS)(HOURS){(PSIG) (PHIG) (F) (64) (BPD) (BBL) (BPD) {BBL) { (BPD) (BBL) (BBL) (F) I(MHCFD){/STB) (MHCF) COMMENTS + ....... + .......... + ........ + ....... + ...... + ..... + .... + ....... + ....... + ....... T ....... + ....... + ....... + ....... ~ ....... + ....... + ...... + .......................................................... 03104 o3/o4 03104 o3/o4 o31o4 o3/o4 o3/o4 o3/o4 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 03/04 o3/o5 o3/o5 o3/05 o3/o5 o3/o5 o3/o5 o3~05 03~05 03/05 13:24:00 208.671 13:30:00 208,771 14:00:00 209.271 14:30:00 209.771 15:00:00 9210.271 15:30:00 9210.771 16:00:00 9211.271 16:30:00 9211.771 17:00:00 9212,271 17:30:00 9212.771 18:00:00 213 271 18:30:00 213 771 19:00:00 214 271 19:30:00 214 771 20:00:00 215 271 20:30:00 215 771 21:00:00 1216,271 21:30:00 9216,771 22:00:00 9217.271 22:30:00 1217.771 23:00:00 9218,271 23:30:00 1218,771 00:00:00 1219.271 00:30:00 9219,771 00:57:00 9220.221 01:00:00 1220,271 01:30:00 9220,771 02:00:00 9221.271 02:30:00 221.771 03:00:00 222,271 03:30:00 222.771 160.6 595,5 162.9 595.5 149.1 595,6 144,3 585.6 145.6 582,6 134,9 57?,3 135,6 569,6 129,4 573,1 158,0 573.6 144.9 575,8 162.6 {580,0 152,7 {592,3 116.4 1601,5 162,0 9606,1 945191z8 {45 29128 {44 59128 {43 6{128 J43 99128 43.3 44.0 45.0 44.7 47,0 46.7 44,8 46.5 153,4 614.3 45.2 135,8 6159 {44.7 160.4 6150 {45.6 149,9 6148 {45,4 144,1 617 5{45.4 159,0 620 0{47.0 156,3 629 9 46,0 121.9 633.6 45,7 154.6 {622,8 45,6 164,7 {627.3 46,6 139.6 {635.4 45,5 150,4 {635.0 46.3 127,5 9631,1 44,8 146.9 {624,3 45,2 160.0 {628.4 45.5 143.5 {627,4 45,0 165,8 9621,6 45,1 { [ I 1253,0 2079,5 1230.9 14486.? 685,8 92108,1 9!059.2 {4530.8 { I I I 128 91022,9 92150,? 997.7 14572.4 I 1289 , , 128 91255,1 {2203.0 91198.1 {4622.3 128 128 91282.4 {2256,4 i253.4 {4674.6 128 , 1158 91321,9 2311,5 1388.5 4732.4 {lZ8 9128 1338.4 236?.3 1199.2 4782.{ 1128 J128 1202.8 2417.4 I141.5 {4829.9 9128 {1Z8 1207.5 2467.7:1179,9:4879.i J1292,4 J4906,0 128 91252.0 92519,9 91170.5 {4930,4 128 { , , 128" ,t110.6 12566.1 91107.0 4976.5 128 { 128 { , 128 11361.1 12622.9 91272.8 5029.6 ' 128 91054.3 {2666,8 1014.9 5071.9 128J - 128 11246,6 Z?lB.? 1179,9 51z1.0 {1281 51,7 {1375,6 44.5 11377.4 I I 36.5 11379.0 I 34.8 J1380.4 ] I 39.1 1382.0 43.3 !383.8 43.8 {1385.? I I g1.7 J1387.4 I I 43,1 {1389.2 0.0 91389.2 42.8 {1390,1 46.5 1392.0 39.7 1393.7 39.3 1395.3 43,1 1397,! 113.2 112.6 119.0 99.9 102.4 139.8 106.5 110.4 109.6 109.3 107.3 106.0 108.6 'I00,9 I I {ElL { 793,6 {0,645 J1568.5 JBSW:4.0% { I 849.6 0,802 11603.9 ID[W=4,0% { 690.7 0.692 11632.7 {BSW=3,5%, GG=0.732 0G:26.7 APl 735.7 0.614 1663.3 BSW=2,8% 1694,1 I729,5 738.6 {0.589 I I 849,2 J0,612 813.6 j0.678 I I 783,6 J0,686 1796.0 BHW:3,S% 790,5 0,670 91829.0 BHN:3.5% I 770.6 0.6[8 {1861.1 BSW=3.§% I 735.7 0.~65 11891.7 ~-[INE 0.0.~,, ~:0.730, 0G:27.6 API E/L RIH 837,5 J0.658 1926.6 BSW:3.0% I I * ! JBSW:3.7% 673.7 {0.664 1954.7 , I I I I 777.1 {0,659 1987.1 {BSW:3.St I I I I BSW=3,0% BSW=3.0% 1763.4 {BSW:3.5%, 0G:0.222 23 FEB 9I TICKET ~0. 007340 PAGE NO. 2,16 ICOMPANY : BP EXPLORATION (ALASKA), INC. ICOMPANY REP ' CHARLIE MICHEL ISEPARATOR ' 42" X 15' 80 MMSCFD 8000 BPD :WELL NAME: POINT MCINTYRE NO. 9 :TEST NO. · SIX (POST FRAC) :GAS METER RUN ' 5.761" W/BARTON ZOlA RECORDER {AREA : PRUDHOE BAY, ALASKA :INTERVAL TESTED : N/A :LIQUID METERS ' 2" OIL, 1.5* OIL, 1" WATER ' TIME DATA ' WELL HEAD DATA ' OIL DATA i WATER DATA ' GAS DATA | ~ ~ | } ....... + .......... + ........ } ....... + ...... } ..... } .... + ....... + ....... + ....... + ....... } ....... + ....... ~ ....... ~ ....... + ....... ~ ...... ~ ....... (MM/DD) (HH:MM:SS)I(HOURS) (PSIC) (PSIC) (F)I46471 (BPD) (BDL) (BPD) I(BBL):(BPD) (BNL) (BBL) (F) (MSCFD)I/STD):(MSCF) COMMENTS % ....... ~ .......... + ........ + ....... + ...... } ..... ~ .... } ....... ~ ....... } ....... + ....... + ....... } ....... + ....... + ....... + ....... } ...... + .......................................................... o3/o5 o3/o5 o3/o5 o3/o5 o3/o5 03/05 03/05 03/05 o3/o5 o3/o5 o3/o5 03~05 o3/o5 o3/o5 03/05 o3/o5 o3/o5 03/05 03/05 03~05 03/05 03~05 o3/o5 o3/o5 03~05 o3/o5 o3/o5 03/05 04:00:00 04:30:00 05:00:00 05:30:00 06:00:00 06:30:00 07:00:00 07:30:00 08:00:00 08:30:00 09:00:00 09:30:00 I0:00:00 10:30:00 11:00:00 11:30:00 12:00:00 12:30:00 13;00:00 13:30:00 14:00:00 14:30:00 15:00:00 15:30:00 16:00:00 16:30:00 17:00;00 17:11:00 223.271 223.771 224.271 224.771 225,271 4225.771 {226.271 1226,?71 Iz2?.l?l :z2?.??l 1228,271 II29.z71 130 271 230 771 231 271 Z31 ?71 232 Z?I 232 ?71 233 271 Z33 ?71 234 271 234 771 235 271 235 771 1236,27i 1236,454 I { 160.2 1627.0 187,3 1628.4 162,3 635.4 138,6 642,3 146, 175.7 647,9 {47. 184.8 654.! !49.4 662.8 146. 130,4 668,4 146. 164.8 671.1 46,2 i87.6 674.4 48.6 197.6 1674,1 48,0 140.8 1674,3 46.6 1564 {673,8 46,9 175 84673,1 49.0 i68 8{676,0 48.1 i50 71673.5 46,1 108 94661,4 49.0 176 9{666.0 48.9 129 5 669,5 47,2 i66 8 669.4 48.4 I80 5 672,6 {49.0 195 5 675,1:49 4 142,2 678.9:480 181,0 682.5 {47 4 180.9 683.9:49 3 123.1 685,1 147 Z 142.3 888.3 146 172,4 690,6 147 Z I I 45.9:128 47.1 1128 47.8:128 7:128 ?:128 51128 z1128 54128 128 128 128 128 128 118 128 128 128 128 [128 4ii8 :128 i128 1128 1207.7 1365.9 I351,6 2?69.0 2826.0 2882.3 1153,3 1324,9 1289,1 5169,1 5224,3 5278,0 1402,1 12940,7 11306,3 15332,1 :1237,2 ' ~, , , I I i I I I I 11307.6 13046.? 11197.9 15434,8 I 11167.z 13095.4 I {1280.7 43148,7 41095.2 3194,4 11362.0 3251.1 1264.? 3303.8 1292.2 1286.5 1Z06,4 0,0 3357.6 3411,3 i135,6 5482.1 1165.4 5530,7 1041.4 5574.1 1333.0 5629.6 i165.6 5678.2 1301,7 5732.4 1233.6 5783,8 3461,5 {I19Z,9 {5833,5 3461.5 41446.1 {5844.6 29,8 I398,4 27,3 1399,5 33.3 11400.9 { 16.0 11401,6 { 52,9 41403.8 45.1 1405.6 47,7 1407.6 47.7 1409,6 32,5 1411.0 19.1 1411.8 37.6 41413.3 I 40.6 I1415.0 { 18.9 11415.8 i I 80,0 11(18,3 72.7 41418.9 98.1 95~7 112,9 126.7 124.9 112.4 111,2 109,3 111.1 104.3 102,7 132.4 108.5 125,3 725,8 787.4 850,4 905.9 903.4 880.1 829,1 815.1 721,7 731.5 741.2 863.8 815.1 ~05,0 905,0 t I 10,629 2017,3 { {0,594 2050.1 { I {0,660 {2085.5 I I 0,693 :2123.3 0,717:2160.9 { 0.735 42197.6 0,730 223Z.2 10.699 2266.1 I I {0,6~3 I I 1o.54~ Io.636 I [0.664 2393,5 I I I I 0,75~ 12465,2 0 626 12472 i BSW=2.§%, GG=0,698 BSW=2.0% BSW:2,54 BSW=I.24 BSW=4,0% BSW=3.64 BSW=4,0% BSW=3,94 2296,2 BSW=3,0% 2326,7 BSW=I,44 2357,5 IBSN=3,1%, GG=0,720 BSW=3.0% BSW=l,54 BSW:(.SI CLOSE WELL FOR BUILDUP, STOP DATA ACOUISITION L L 23 FEB 91 TICKET NO, 007340 PAGE UO. 2,17 COMPANY : BP EXPLORATION (ALASKA), INC. ICOMPANY REP ' CHARLIE MICHEL ISEPARATOR : 42" X 1§' 80 MMSCFD 8000 BPD WELL HAME: POINT MCINTYRE NO. 9 ITEST NO. ' SIX (POST FRAC) IGAS METER RUN ' §.761" W/BARTON 202A RECORDER AREA ' PRUDHOE BAY, ALASKA IINTERVAL TESTED : N/A {LIQUID METERS ' 2" OIL, 1.5" OIL, 1" WATER ............................ + ......................... ~ ............... + ............... t ....................... + ...................... + .......................................................... TIME DATA ' WELL HEAD DATA I OIL DATA ' WATER DATA ' GAS DATA f ....... + .......... + ........ } ....... ~ ...... } ..... % .... ~ ....... + ....... ~ ....... ~ ....... ~ ....... } ....... } ....... ~ ....... + ....... ~ ...... + ........ I' REAL DELTA ," ," IHTR RATE CUM RATE CUM I RATE I CUM TNK MTR TOTAL I GOR DATE I TIME TIME WHP I IAP I WH~ ICHK SEP SEP TNK TNK I TNK I TNK IHC TEMP RA?E I(~SCF CUM (HH/DD)I(HR:HM:SS)(HOURS) (PSIG)I(PSIG)I (F)I(64) (BPD) (BBL} (BPD) (BBL) i (BPD) I (BBL) (BBL) (F) (HSCFD)I/STB) (HSCF) COMMENTS ~ ....... ~ .......... ~ ........ + ....... ~ ...... ~ ..... + .... + ....... ~ ....... + ....... + ....... } ....... + ....... } ....... ~ ....... ~ ....... i ...... ~ ........................................................ I I I I I I I I ! I ~ I I I I I I I I I I I I I I I [ I i I I I I I I I SEPARATOR AVG CUM AVG CUM VOL METER AVG AVG C~ FLOW Qo(sep) SEP Qo(tnk) TNK FACTOR FACTOR Qg GOR GAS PERIOD BPD~60 BPD@60 BPD960 BPD860 Cf If Hscfd Mscf/BB Mscf 1 693.4 1066,9 676.3 1031,5 0,9754 0.}903 445.9 0,?1§ 688.5 2 80§,2 627.~ 762,0 594,8 0.9464 0,9608 §Ol,t 0.676 397,3 3 i228,1 16§1,3 1207,6 1606,0 0,9834 0,9983 807.§ 0.669 1072.6 Cf=Vt/Vs=Wf*Mf Where: Cf:Volume Correction Factor (~ep bbl@60 => stock tnk bbl@60) Vt=Volume by tank at 60 degrees F Vs=Volume by separator meter at 60 degrees F Wf=O.98~=Weathering factor by arinkage te~ter Mf=Meter efficiency factor (determined hperically) 3SOH 14V31S 3(IV'dO 3113~V .2. ...... 3SOH ~13§gr/d 30v~9 311O~v ,,£ lsd 000~ .,~ I~d 000~ ,,£ m lsd O00q ,, £ mm 0N3~39 99V~ . 1 X ,£ ¥ 30G93NI V3~V 6J~3§ ~OJ 'MIO 99V :310N ,,g/l ~,gOg x .q£ X ,19 ~3VIS 3~Vl~ .0~' /Hgl~dn ,9~ X ,9£ ,,0,0G I oo1::. ,gL x ,~9 ,88 X ,09 dl,-lfld ~3J~N¥~dl ~J3ggn~13.s ,Ol x .9£ ,9 X ..9£ ,,0.0g 93NYd 311n¥~OAH /311V~Jfl3Nd ASS dNfld '£141 H3H3 ~3(]¥3H VIVO OlOJINVN ,,g/I ~,Ogl d~4DD N:I9 I 8311V81 AON39~3143 ] ,,0,001 LIST OF PERSONNEL Name Dathan Bulot Curtis Istre Tim Loisel (Gonzo) Dave Peterson John Gibb Robert Richey Dan Dugas Alvis Washington Danny Jones Perry Gross Title Specialist Specialist Specialist Operator Operator Specialist Supervisor Operator Specialist Operator Position Separator Manifold Data Acquisiton Separator Tank Farm Boiler Data Acquisition Separator Manifold Tank Farm Manifold Separator Boiler ;CO. NAME I B.P. EXPLORATION NO. PT. McINTYRE ~9 DATE [ N0. SERIAL CO. 90 [ 1 CONTRACTOR AUDI RIG ~3 EVEREHT PO~TER BBL~ SIM]:. 6 3/4" x 4" x 60' INNER BBL. TYPE FIBERGLASs MUD TYPE WATER BASE FORMATION ~HOLE i ANGLE 35* AV~CORE LENGTH CO IFIDENTIAL ORIENTED HAROLD ~ERSON CORING SUMMARY 12/1: 2 !2/1~ 3 ~/1:4 I SC-777 SC-777 RC-412 RC-412 0116448 0116448 0116451 0116451 DEPTH 13,544 ' - 13,593' i3,642 ' - 13,702 ' 13,702' 13,762' 13,762'- 13,812' Fr. CORED ACCUM 49 49 60 109 60 169 50 219 I ERS. CORED [ COPE I 1.1[ 22.1 [ 28.2 I I. REC. ACCUM 44 104 164 192.2 I REC. I ROP. ACCUM I Er/HR 90 10C lOC 56 90 [3.7 [3.7 95 18.9 [5.45 97 [60 8 88 I 42 [ 9.9 i I I I I I Wr.0.B. [ ' 15O/ 5/30 8O 8/25 8O 10/12 80 12 80 GPM PSI 310 310 1450 310 1350 340 1500 COMMENTS JAP~ED 1450 FIBERGLASS I.T. FULL C/BBL FIBERGLASS I.T. EXCESSIVE TORfTJE HAD TO PICK UP q~D RESTART 4 TIMES ADDED GLASS BF~DS q~ ~]D ~U.T. ~/RRr. VTR~Rf-3.A~q T ~_ EXCESSIVE TORQUE INCREASED GPM FIBERGLASS I.T. J. BP EXPLORATION; Point Mc~ntyre #9 Core No, 1= 13544'~13593' 24O 22O 2OO 180 180 .................... 100 8O 80 ROP, WOB, PS~/IO, 8PM TORQ, MAX TORe 1200 ........ : ......... 1000 ............................................. ; ........................ 900 40 i 700 0 800 13540 13550 ~3560 13570 18580 13590 13800 1,3810 18820 TORQUE 8P~ BP NO, Point Mc~ntyre #9 13642'-13702' 24O 22O 2OO 180 t80 I40 ROP, WOB, PSi/10, SPM MAX TORQ 1200 1100 1000 120 ...................... : ....................................................................... 900 100- 80 ~ 40 ' ' 700 0 L ~ 800 13640 13660 18680 18870 13880 13690 13700 13710 13720 ~A× TORQ TORQUE ROP BP EXPLORATION: Point Mc~ntyre #9 Core No, 3:13702'~13762' 24O ROP, WOB, PS~/IO, SPM 220 180 140 h 60 40 ~0 0 13700 13710 13720 13730 TORQ, MAX TORE , 1200 1000 900 800 ~ L j 800 13740 13750 13760 13770 13780 ~ MAX TO~Q ~ WOB :x- TORQUE SPM ¢/~L~ LOQG~NG, P81/I0 BP EXPLORATION: Point Mc~ntyre #9 13783'-13812' 240 220 200 I80 ROP, WOB, PS~/10, SPM MAX TORQ (Thousands) 1.2 t20~- iO0 -- 20 13760 13770 0.9 ................. 0~6 13780 13790 13.800 13810 13820 MAX TORQ ~ WOB TORQUE SPM , NFIDENTIAL 'ORIGINAL ~URVEY ~ UIDANCE [~ONTINUOUS IooL Company BP EXPLORATION, Well Nam® PT. MC INTYRE //9 (535' Fleld/LocatlonPT. MC INTYRE, NORTH II FNL,1048' FWL,SEC 14,T12NaR14E)_ SLOPE~ ALASKA , Job Reference No. 74268 Lo<~c~ed BT FORMICA Date, 22-DEC-90 Computed Ely; KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEy CUSTOMER LISTING FOR BP EXPLORATION PT. MCINTYRE #9 TOOL LOCAT[ON= INTERPOLATION: VERTICAL SECTION= PT. MCINTYRE NORTH SLOPE, ALASKA SURVEY DATE= 22-DEC-90 ENGZNEER= JEFF FORMICA TANGENT]AL- Averaged deviation and azimuth LZNEAR HORIZ. DIST. PROJECTED ONTO A TARGET AZXMUTH OF NORTH 18 DEG 26 MIN EAST BP EXPLORATION PT. MCINTYRE #9 PT. MCINTVRE NORTH SLOPE, ALASKA COMPUTATION DATE: 6-jAN-91 PAGE 1 DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL~DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION ~:SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 -40.45 0 0 N 0 0 E 0.00 0.00 100.00 99.95 59.50 0 3 S 62 40 E -0.04 0.00 200.00 199.95 159.50 0 4 N 62 52 E -0.04 0.10 300.00 299.95 259.50 0 5. N 36 7 W 0.07 0.00 400.00 399.95 359.50 0 9 N 67 35 W 0.13 0.00 500.00 499.95 459.50 0 10 N 67 5 W 0.14 0.08 600.00 599.95 559.50 0 26 N 25 36 W 0.36 0.76 700.00 699.90 659.45 3 0 N 3 23 W 2.69 2.80 800.00 799.65 759.20 4 54 N 0 29 E 9.29 1.16 900.00 899.16 858.71 6 33 N 4 53 E 18.75 2.10 0.00 N 0.00 E 0.07 S 0.07 E 0.09 S 0.17 E D.02 N 0.16 E O. 14 N 0.01 E 0.23 N 0.26 W 0.56 N · 0.52 W 3.15 N 0.96 W 10.15 N 19.97 N 0.00 N 0 0 E O. 10 S 47 14 E 0.20 S 61 22 E 0.17 N 84 10 E 0.14 N 4 22 E 0.35 N 48 4 W 0.76 N 43 14 W 3.30 N 16 54 W 1.07 W 10.21 N 6 2 W 0.62 W 19.97 N 1 46 W 1000.00 998.36 957.91 8 3 N 7 48 E 31.10 2.22 1100.00 1096.99 1056.54 11 0 N 11 49 E 47.34 3.13 1200.00 1194.78 1154.33 12 56 N 14 28 E 68.15 1.87 1300.00 1291.77 1251.32 15 17 N 15 10 E 92.43 2.41 1400.00 1387.66 1347.21 17 32 N 15 30 E 120.72 1.82 1500.00 1482.50 1442.05 19 35 N 16 38 E 152.39 2.44 1600.00 1576.07 1535.62 21 44 N 17 34 E 187.64 2.60 1700.00 1668.26 1627.81 23 46 N 16 50 E 226.37 1.88 1800.00 1759.26 1718.81 25 9 N 16 36 E 267.80 1.50 1900.00 1849.01 1808.56 27 15 N 15 59 E 311.86 1.97 32.51 N 0.80 E 32.52 N 1 25 E 48.68 N 3.65 E 48.82 N 4 17 E 69.01 N 8.48 E 69.53 N 7 0 E 92.50 N 14.78 E 93.68 N 9 5 E 119.83 N 22.26 E 121.68 N 10 31 E 150.31 N 30.96 E 153.46 N 11 38 E 183.96 N 41.47 E 188.58 N 12 42 E 220.96 N 52.95 E 227.22 N 13 29 E 260.67 N 64.86 E 268.61 N 13 58 E 303.02 N 77.12 E 312.68 N 14 17 E 2000.00 1937.25 1896.80 28 46 N 15 54 E 358.85 1.60 2100.00 2024.10 1983.65 30 45 N 13 14 E 408.29 2.09 2200.00 2108.89 2068.44 33' 6 N 13 11 E 461.05 0.71 2300.00 2192.35 2151.90 34 2 N 13 35 E 515.93 2.28 2400.00 2273.90 2233.45 36 55 N 14 4 E 573.60 3.61 2500.00 2351.87 2311.42 40 34 N 14 16 E 636.02 3.69 2600.00 2425.64 2385.19 44 15 N 14 35 E 703.33 3.08 2700.00 2495.86 2455.41 46 24 N 14 49 E 774.37 2.25 2800.00 2563.01 2522.56 49 27 N 15 9 E 848.32 3.24 2900.00 2625.82 2585.37 52 46 N 15 27 E 926.00 3.00 348.22 N 90.12 E 359.69 N 14 31 E 396.21 N 102.47 E 409.25 N 14 30 E 447.83 N 114.48 E 462.23 N 14 20 E 501.42 N 127.25 E 517.32 N 14 14 E 557.59 N 141.09 E 575.16 N 14 12 E 618.27 N 156.44 E 637,76 N 14 12 E 683.63 N 173.23 E 705.23 N 14 13 E 752.49 N 191.28 E 776.42 N 14 16 E 824.05 N 210.45 E 850.50 N 14 20 E 899.10 N 230.93 E 928.29 N 14 24 E 3000.00 2685.23 2644.78 53 48 N 15 51 E 1006.34 3100.00 2744.33 2703.88 53 40 N 15 44 E 1086.92 3200.00 2803.78 2763.33 53 27 N 15 32 E 1167.23 3300.00 2863.39 2822?94 53 17 N 15 14 E 1247.42 3400.00 2923.59 2883.14 52 47 N 14 40 E 1327.12 3500.00 2984.15 2943.70 52 36 N 14 26 E 1406.51 3600.00 3045.07 3004.62 52 20 N 14 1 E 1485.60 3700.00 3106.47 3066.02 52 0 N 13 40 E 1564.27 3800.00 3168.24 3127.79 51 53 N 13 13 E 1642.61 3900.00 3229.93 3189.48 51 51 H 13 22 E 1721.0D 0.47 976.54 N 252.69 E 1008.70 N 14 30 E 0.66 1054.16 N 274.64 E 1089.35 N 14 36 E 0.39 1131.62 N 296.24 E 1169.75 N 14 40 E 0.61 1209.02 N 317.58 E 1250.04 N 14 43 E 0.67 1286.17 N 338.19 E 1329.88 N 14 44 E 0.63 1363.18 N 358.19 E 1409.46 N 14 43 E 0.94 1440.06 N 377.66 E 1488.76 N 14 42 E 0.67 1516.70 N 396.54 E 1567.69 N 14 39 E 0.42 1593.20 N 414.77 E 1646.30 N 14 36 E 0,99 1669.80 N 432.83 E 1724,99 N 14 32 E BP EXPLORATION PT. MCINTVRE #9 PT. MCINTYRE NORTH SLOPE, ALASKA COMPUTATION DATE: 6-JAN-91 PAGE 2 DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORD]NATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000.00 3292.13 3251.68 51 2 N 13 17 E 1798.98 4100.00 3354.83 3314.38 51 37 N 13 12 E 1876.56 4200.00 3416.05 3375.60 52 57 N 13 5 E 1955.30 4300.00 3476.32 3435.87 52 50 N 13 41 E 2034.78 4400.00 3535.95 3495.50 53 55 N 13 40 E 2114.78 4500.00 3594.19 3553.74 54 50 N 13 23 E 2195.77 4600.00 3650.88 3610.43 58 25 N 13 10 E 2277.82 4700.00 3705.11 3664.66 57 40 N 13 2 E 2361.47 4800.00 3757.76 3717.31 58 35 N 12 59 E 2446.10 4900.00 3810.53 3770.08 57 36 N 13 46 E 2530.71 5000.00 3864.89 3824.44 56 42 N 13 57 E 2614.38 5100.00 3919.07 3878.62 57 35 N 14 17 E 2698.19 5200.00 3973.18 3932.73 56 39 N 14 10 E 2782.06 5300.00 4029.74 3989.29 54 36 N 13 55 E 2864.26 5400.00 4089.08 4048.63 52 49 N 14 23 E 2944.52 5500.00 4149.15 4108.70 53 46 N 14 34 E 3024.28 5600.00 4207.01 4166.56 54 57 N 15 1 E 3105.66 5700.00 4264.59 4224.14 54 40 N 16 11 E 3187.33 5800.00 4321.56 4281.11 56 14 N 16 22 E 3269.45 5900.00 4376.03 4335.58 57 52 N 16 16 E 3353.25 I .61 0.53 1.46 1.13 1.10 0.76 2.35 1.13 0.48 0.66 1745.99 N 450.89 E 1803.27 N 14 29 E 1821.84 N 468.66 E 1881.15 N 14 26 E i898.84 N 486.64 E 1960.20 N 14 22 E 1976.47 N 505.09.E 2039.99 N 14 20 E 2054.46 N 524.12 E 2120.26 N 14 19 E 2133.49 N 543.13 E 2201.53 N 14 17 E 2213.65 N 562.11 E 2283.90 N 14 15 E 2295.49 N 581.13 E 2367.90 N 14 12 E 2378.32 N 600.25 E 2452.90 N 14 10 E 2460.97 N 619.85 E 2537,83 N 14 8 E 0.32 2542.45 N 639.97 E 2621.76 N 14 8 E 0.42 2623.97 N 660.44 E 2705.81 N 14 8 E 1.67 2705.45 N 681.25 E 2789.90 N 14 8 E 1.66 2785.51 N 701.00 E 2872.36 N 14 8 E 0.75 2863.56 N 720.66 E 2952.85 N 14 8 E 2.09 2940.95 N 740.70 E 3032.79 N 14 8 E D.92 3019.84 N 761.39 E 3114.34 N 14 9 E 0.54 3098.55 N 783.51 E 3196.07 N 14 11 E 1,67 3177.43 N 806.57 E 3278.20 N 14 15 E 2.28 3257.92 N 830.08 E 3362.01 N 14 18 E 6000.00 4427.95 4387.50 59 28 6100.00 4478.61 4436.16 59 28 6200.00 4529.91 4489.46 59 16 6300.00 4580.90 4540.45 58 54 6400.00 4634.02 4593.57 56 51 6500.00 4689.17 4648.72 56 27 6600.00 4745.04 4704.59 55 42 6700.00 4801.02 4760.57 55 58 6800.00 4857.62 4817.17 55 0 6900.00 4916.30 4875.85 53 34 N 15 54 E 3438.65 N 15 45 E 3524.77 H 15 32 E 3610.51 N 15 44 E 3696.42 N 15 26 E 3781.04 N 15 29 E 3864.35 N 15 33 E 3947.17 N 16 3 E 4029.94 N 16 20 E 4112.32 N 16 19 E 4193.24 I .04 2.77 1.38 2.48 3.27 1.30 1.64 1.10 2.10 1.22 3340.01 N 853.87 E 3447.42 N 14 20 E 3422.96 N 877.35 E 3533.61 N 14 23 E 3505.63 N 900.46 E 3619.43 N 14 24 E 3588.48 N 923.60 E 3705.43 N 14 26 E 367D.08 N 946.38 E 3790.14 N 14 28 E 3750.50 N 968.58 E 3873.55 N 14 29 E 3830.41 N 990.77 E 3956.47 N 14 30 E 3910.18 N 1013.20 E 4039.31 N 14 32 E 3989.32 N 1036.26 E 4121.71 N 14 34 E 4067.02 N 1059.05 E 4202.65 N 14 36 E '7000.00 4976.53 4936.08 52 55 N 16 34 E 4273.01 7100.00 5037.66 4997.21 51 49 N 16 52 E 4352.12 7200.00 5099.58 5059.13 52 9 N 17 1 E 4430.62 7300.00 5161.94 5121.49 50 29 N 17 48 E 4508.77 7400.00 5224.70 5184'.25 51 57 N 17 32 E 4586.61 7500.00 5284.93 5244.48 53 57 N 17 10 E 4666.42 7600.00 5343.47 5303.02 53 57 N 18 6 E 4747.48 7700.00 5401.89 5361.44 55 2 N 16 56 E 4828,63 7800.00 5458.36 5417.91 55 57 N 16 12 E 4911.11 7900.00 5514.59 5474.14 55 25 N 17 27 E 4993.76 1.42 4143.61 N 1081.55 E 4282.43 N 14 38 E 0.73 4219.36 N 1104.44 E 4361.52 N 14 40 E 0.71 4294.48 N 1127.34 E 4439.98 N 14 43 E 0.26 4369.06 N 1150.73 E 4518.06 N 14 45 E 2.20 4443.24 N 1174.36 E 4595.81 N 14 48 E 1.90 4519.42 N 1198.16 E 4675.55 N 14 51 E 0.96 4596.75 N 1222.54 E 4756.54 N 14 54 E 2.68 4673.99 N 1247.43 E 4837.59 N 14 57 E 0,51 4753.17 N 1270.69 E 4920.09 N 14 58 E 2.17 4832.36 N 1294.48 E 5002.74 N 15 0 E COMPUTATION DATE: 6-JAN-91 PAGE 3 BP EXPLORATION PT. MCINTYRE #9 PT. MCINTVRE NORTH SLOPE, ALASKA DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT[ON SEVERITY NORTH/SOUTH EAST/WEST D[ST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG BO00.O0 5572.16 5531.71 54 10 8100.00 5631.32 5590.87 53 56 8200.00 5689.69 5649.24 54 23 8300.00 5748.39 5707.94 53 57 8400.00 5807.34 5766.89 53 38 8500.00 5866.84 5826.39 53 26 8600.00 5926.00 5885.55 53 55 8700.00 5984,35 5943,90 54 41 N 19 11 E 5075.52 N 18 22 E 5156.14 N 16 41 E 5237.31 N 16 46 E 5318.23 N 16 39 E 5398.98 N 16 52 E 5479.32 N 17 24 E 5559.91 N 17 41 E 5641.12 8800.00 6041.06 6000.61 56 19 N 17 39 E 5723.47 8900.00 6096.38 6055.93 56 6 N 17 I E 5806.76 9000.00 6152.58 6112.13 56 11 N 15 43 E 5889.41 9100.00 6207.52 6167.07 56 49 N 15 1 E 5972.85 9200.00 6262.61 6222.16 56 43 N 14 15 E 6056.10 g300.O0 6316.63 6276.18 57 29 N 13 39 E 6140.02 9400;00 6371.34 6330.89 56 13 N 12 22 E 6223.33 9500.00 6427.22 6386.77 55 57 N 12 32 E 6305.80 9600.00 6482.72 6442.27 56 59 N 12 37 E 6388.57 9700.00 6536.90 6496.45 56 52 N 12 37 E 6472.18 9800.00 6591.57 6551.12 57 9 N 12 40 E 6555.47 9900.00 6644.64 6604.19 58 34 N 12 30 E 6639.80 10000.00 6698.43 6657.98 56 10 N 12 27 E 6723.61 10100.00 6754.49 6714.04 55 42 N 12 19 E 6805.95 10200.00. 6811.05 6770.60 55 22 N 11 43 E 6887.91 10300.00 6868.80 6828.35 54 7 N 11 23 E 6968.94 10400.00 6928.46 6888.01 52 40 N 12 25 E 7048.68 10500.00 6989.11 6948.66 52 38 N 13 27 E 7127.83 10600.00 7049.11 7008.66 53 38 N 15 37 E 7207.63 10700.00 7107.23 7066.78 55 36 N 17 40 E 7288.96 10800.00 7162.36 7121.91 56 41 N 18 36 E' 7372.38 10900.00 7218.65 7178.20 54 45 N 17 58 E 7455.03 11000.00 7276.63 7236.18 54 26 N 19 3 E 7536.51 11100.00 '7335.61 7295.16 53 56 N 19 11 E 7617.25 11200.00 7394.03 7353.58 54 4 N 21 27 E 7698.36 11300.00 7453.67 7413.22 53 26 N 23 43 E 7778.42 11400.00 7512o36 7471.91 54 32 N 25 58 E 7858.87 11500.00 7570.18 7529.73 54 54 N 26 41 E 7939.68' 11600.00 7627.84 7587.39 54 50 N 27 31 E 8020.44~ 11700.00 7685.45 7645.00 54 48 N 28 6 ~ 8101.08 11800,00 7743.40 7702.95 54 36 N 28 36 E 8181.35 11900.00 7801.32 7760.87 54 41 N 27 46 E 8261.70 1.95 2.93 0.36 0.18 0.85 1 .21 0.73 0.18 2.45 2.54 4909.98 N 1320.18 E 5084.37 N 15 3 E 4986.13 N 1346.67 E 5164.78 N 15 7 E 5063.63 N 1370.86 E 5245.91 N 15 9 E 5141.18 N 1394.12 E 5326.84 N 15 10 E 5218.53 N 1417.38 E 5407.59 N 15 12 E 5295.49 N 1440.57 E 5487.94 N 15 13 E 5372.55 N 1464.26 E 5568.51 N 15 15 E 5449.96 N 1488.83 E 5649.66 N 15 17 E 5528.39 N 1513.94 E 5731.94 N 15 19 E 5607.92 N 1538.74 E 5815.19 N 15 21 E 4.37 5687.36 N 1561.77 E 5897.90 N 15 21 E 3.04 5767.87 N 1584.13 E 5981.45 N 15 21 E 1.44 5848.69 N 1604.91 E 6064.89 N 15 21 E 2.41 5930.31 N 1625.43 E 6149.03 N 15 20 E 2.47 6011.91 N 1644.09 E 6232.66 N 15 18 E 1.11 6092.89 N 1661.90 E 6315.48 N 15 15 E 0.98 6174.06 N 1680.14 E 6398.58 N 15 13 E 0.64 6256.09 N 1698.45 E 6482.55 N 15 11 E 0.54 6337.81.N 1716.70 E 6566.19 N 15 9 E 1.45 6420.51 N 1735.26 E 6650.87 N 15 7 E 1.59 6502.84 N 1753.29 E 6735.05 N 15 5 E 0.40 6583.74 N 1770.97 E 6817.77 N 15 3 E 1.11 6664.39 N 1788.20 E 6900.13 N 15 1 E 1.16 6744.40 N 1804.40 E 6981.60 N 14 59 E 0.61 6822.91 N 1821.03 E 7061.74 N 14 57 E 0.85 6900.37 N 1838.95 E 7141.21 N 14 55 E 1.74 6977.82 N 1858.96 E 7221.20 N 14 55 E 3.16 7055.74 N 1882.38 E 7302.52 N 14 56 E 1.10 7134.93 N 1908.59 E 7385.80 N 14 59 E 2.44 7213.39 N 1934.58 E 7468.30 N 15 1 E 1.39 7290.72 N 1960.26 E 7549.64 N 15 3 E 1.89 7367.07 N 1986.54 E 7630.21 N 15 5 E 2,31 1.88 1.47 0.84 0 °94 0.60 I .07 0.31 7443.18 N 2014.71 E 7711.03 N 15 9 E 7517.29 N 2045.53 E 7790.63 N 15 13 E 7590.75 N 2079.55 E 7870.45 N 15 19 E 7663.88 N 2115.74 E 7950.56 N 15 26 E 7736.59 N 2153.00 E 8030.58 N 15 33 E 7808.87 N 2191.14 E 8110.46 N 15 40 E 7880.55 N 2229.95 E 6189.97 N 15 ~8 E 7952.44 N 2268.38 E 8269.63 N 15 55 E COMPUTATION DATE: 6-JAN-91 PAGE 4 BP EXPLORATION PT. MCINTVRE #9 PT. MCINTYRE NORTH SLOPE, ALASKA .DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER= JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 12000.00 7859.46 7819.01 54 2 N 28 26 E 8341.91 12100.00 7918.14 7877.69 54 6 N 28 20 E 8421.65 12200.00 7977.40 7936.95 53 15 N 28 3 E 8501.03 12300.00 8038.27 7997.82 51 44 N 29 0 E 6579.14 12400.00 8100.89 8060.44 50 40 N 30 20 E 8655.62 12500.00 8165.20 8124.75 49 21 N 31 21 E 8730.40 12600.00 8230.88 8190.43 46 30 N 32 37 E 8803.70 12700.00 8297.84 8257.39 47 15 N 33 52 E 8675.46 12800.00 8366.89 8326.44 45 32 N 30 54 E 8945.58 12900.00 8437.66 8397.21 44 58 N 29 21 E 9014.64 13000.00 8507.21 8466.76 '46 10 N 30 13 E 9085.28 13100.00 .8578.61 8536.16 42 34 N 30 51 E 9153.67 13200.00 8653.92 8613.47 39 27 N 31 10 E 9217.84 13300.00 8732.56 6692.11 37 2 N 31 47 E 9278.05 13400.00 6812.86 6772.41 36 2 N 33 34 E 9335.B0 13500.00 8693.65 8853.20 36 12 N 34 14 E 9392.59 13600.00 8974.29 8933.84 36 34 N 34 51 E 9449.43 13700.00 9054.44 9013.99 37 2 N 35 31 E 9506.63 13800.00 9134.05 9093.60 37 24 N 35 51 E 9564.45 13900.00 9213.04 9172.59 38 20 N 35 21 E 9623.01 14000.00 9291.07 9250.62 39 2 N 33 46 E 9683.08 14100.00 9368.26 9327.81 39 62 N 32 1 E 9744.63 14200.00 9444.63 9404.08 40 46 N 30 45 E 9607.70 14300.00 9520.04 9479.59 41 1 N 30 42 E 9671.76 14375.00 9576.64 9536.19 41 1 N 30 42 E 9919.87 0.97 8024.'24 N 2306.64 E 6349.19 N 16 2 E 0.99 8095.43 N 2345.22 E 6428.29 N 16 9 E 0.83 8166.41 N 2383.29 E 8507.06 N 16 16 E 1.85 6236.13 N 2421.15 E 8564.62 N 16 23 E 2.36 8303.89 N 2459.72 E 8660.53 N 16 30 E 1.65 8369.63 N 2498.98 E 8734.74 N 16 37 E 1.17 8433.59 N 2538.92 E 8807.47. N 16 45 E 2.02 8495.62 N 2579.76 E 6876.66 N 16 53 E 2.91 8556.55 N 2618.71 E 8946.30 N 17 1 E 2.35 8617.85 N 2653.63 E 9017.21 N 17 7 E 1.93 8680.19 N 2689.54 E 9067.32 N 17 13 E 1.53 8740.39 N 2725.24 E 9155.40 N 17 19 E 2.98 8796.70 N 2759.23 E 9219.29 N 17 25 E 1.45 8849.47 N 2791.31 E 9279.26 N 17 30 E 1.47 8899.162 N 2823.49 E 9336.76 N 17 36 E 1.06 8948.51 N 2856.39 E 9393.34 N 17 42 E 1.22 8997.28 N 2889.85 E 9449.99 N 17 48 E 0.64 9046.03 N 2924.48 E 9507.01 N 17 55 E 0.35 9095.25 N 2959.68 E 9564.69 N 18 2 E 1.20 9145.04 N 2995.49 E 9623.13 N 16 B E 1.4'3 9196.54 N 3030.97 E 9683.13 N 18 14 E 1.60 9249.91 N 3065.50 E 9744.64 N 18 20 E 1.15 9305.21 N 3099.05 E 9807.70 N 18 25 E 0.00 9361.59 N 3132.53 E 9871.78 N 18 30 E 0.00 9403.91 N 3157,65 E 9919.90 N 18 34 E BP EXPLORATION PT. MCINTYRE #9 PT. MC[NTMRE NORTH SLOPE, ALASKA COMPUTATION DATE.' 6-JAN-91 TRUE SUB-SEA COURSE MEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG M~N FEET 0.00 0.00 -40.45 0 0 N 0 0 E O.OO O.DO 1000.00 998.36 957.91 B 3 N 7 48 E 31.10 2.22 2000.00 1937.25 1896.80 28 46 N 15 54 E 358.85 1.60 3000.00 2685.23 2644.78 53 48 N 15 51 E .1006.34 0.47 4000.00 3292.13 3251.68 51 2 N 13 17 E 1798.98 1.61 5000.00 3864.89 3824.44 56 42 N 13 57 E 2614.38 0.32 6000.00 4427.95 4387.50 59 28 N 15 54 E 3438.65 1.04 7000.00 4976.53 4936.08 52 55 N 16 34 E 4273.01 1.42 8000.00 5572.16 5531.71 54 10 N 19 11 E 5075.52 1.95 9000.00 6152.58 6112.13 56 11 N 15 43 E 5889.41 4.37 10000.00 6698.43 6657.98 56'10 N 12 27 E 6723.61 1.59 11000.00 7276.63 7236.18 54 26 N 19 3 E 7536.51 1.39 12000.00 7859.46 7819.01 54 2 N 28 28 E 8341.91 D.97 13000.00 8507.21 8466.76 46 10 N 30 13 E 9085.28 1.93 14000.00 9291.07 9250.62 39 2 N 33 46 E 9683.08 1.43 14375.00 9576.64 9536.19 41 1 N 30 42 E 9919.87 0.00 PAGE 5 DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATZON: 40.45 FT ENGZNEER= JEFF FORMZCA ]NTERPDLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH VERTZCAL DOGLEG RECTANGULAR COORD]NATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEG/1DO FEET FEET FEET DEG 0.00 N 0.00 E 0.00 N 0 0 E 32.51 N 0.80 E 32.52 N 1 25 E 348.22 N 90.12 E 359.69 N 14 31 E 976.54 N 252.69 E 1008.70 N 14 30 E 1745.99 N 450.89 E 1803.27 N 14 29 E 2542.45 N 639.97 E 2621.76 N 14 8 E 3340.01 N 853.87 E 3447.42 N 14 20 E 4143.61 N 1081.55 E 4282.43 N 14 38 E 4909.98 N 1320.18 E 5084.37 N 15 3 E 5687.36 N 1561.77 E 5897.90 N 15 21 E 6502.84 N 1753.29 E 6735.05 N 15 5 E 7290.72 N 1960.26 E 7549.64 N 15 3 E 8024.24 N 2306.64 E 8349.19 N 16 2 E 8680.19 N 2689.54 E 9087.32 N 17 13 E 9196.54 N 3030.97 E 9683.13 N 18 14 E 9403.91 N 3157.65 E 9919.90 N 18 34 E r',l,,I COMPUTATION DATE= 6-JAN'91 PAGE 6 BP EXPLORATION PT. MCINTYRE #9 PT. MCINTYRE NORTH SLOPE, ALASKA DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG MZN 0.00 0.00 -40.45 0 0 N 0 0 E 40.50 40.45 0.00 0 10 S 39 54 E 140.50 140.45 100.00 0 4 S 65 0 E 240.50 240.45 200.00 0 4 N I 53 E 340.50 340.45 300.00 0 6 N 45 51 W 440.50 440.45 400.00 0 10 N 73 37 W 540.50 540.45 500.00 0 12 N 45 7 W 640.50 640.45 600.00 1 5 N 15 12 W 740.62 740.45 700.00 3 51 N 1 21 W 840.96 840.45 800.00 5 25 N 2 6 E 941.58 940.45 900.00 7 7 1042.56 1040.45 1000.00 9 9 1144.36 1140.45 1100.00 12 1 1246.96 1240.45 1200.00 13 59 1350.62 1340.45 1300.00 16 31 1455.51 1440.45 14OD.OD 18 33 1561.77 1540.45 1500.00 20 51 1669.67 1640.45 1600.00 23 11 1779.25 1740.45 1700.00 24 52 1890.39 1840.45 1800.00 27 2 FEET DEG/IO0 2003.65 1940.45 1900.00 28 49 2119.06 2040.45 2000.00 31 10 2237.71 2140.45 2100.00 33 16 2358.54 2240.45 2200.00 35 31 2485.01 2340.45 2300.00 40 1 2620.77 2440.45 2400.00 44 49 2765.72 2540.45 2500.00 48 18 2924.37 2640.45 2600.00 53 23 3093.45 2740.45 2700.00 53 42 3261.55 2840.45 2800.00 53' 28 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST D[ST. AZ[MUTH FEET FEET FEET DEG 0.00 0.00 0.00 N 0.00 E 0.00 N 0 D E -0.01 0.41 0.02 S 0.01 E 0.03 S 35 38 E -0.05 0.00 0.08 S 0.11 E O. 14 S 51 41 E 0.01 0.00 0.06 S 0.20 E 0.21 S 73 29 E 0.10 0.00 0.07 N 0.12 E 0.1,o, N 60 26 E 0.13 O.OD 0.17 N 0.10 V/ 0,20 N 29 8 W 0.17 0.38 0.30 N 0.36 W 0.46 N 50 24 W 0.75 2.85 1.02 N 0.68- W 1.23 N 33 50 W 4,98 1.98 5.59 N 1.05 W 5.69 N 10 37 W 12.81 1.64 13.83 N 0.99 W 13.87 N 4 5 W N 6 15 E 23.58 N 9 25 E 37.33 N 13 19 E 56.17 N 15 8 E 79.03 N 15 17 E 106.26 N 15 54 E 137.88 N 17 35 E 173.75 N 17 9 E 214.28 N 16 39 E 259,03 N 15 58 E 307.49 N 15 52 E 360.60 N 13 5 E 418.05 N 13 23 E 481.62 N 13 53 E 549.18 N 14 16 E 626.33 N 14 39 E 717.87 N 15 4 E 822.55 N 15 35 E 945.46 N 15 44 E 1081.65 N 15 24 E 1216.60 3427.87 2940.45 2900.00 52 46 'N 14 34 E 1349.25 3592.45 3040.45 3000.00 52 22 N 14 2 E 1479.64 3755.03 3140.45 3100.00 51 47 N 13 21 E 1607.40 3917.01 3240.45 320~.00 51 46 N 13 20 E 1734.31 4076.90 3340.45 3300.00 51 24 N 13 11 E 1858.56 4240.63 3440.45 3400.00 53 4 N 13 18 E 1987.65 4407.64 3540.45 3500.00 54 0 N 13 40 E 2120.94 4591.24 3640,45 3600.00 56 0 N 13 14 E 2262.30 4766.85 3740.45 3700.00 58 28 N 13 0 E 2417.96 4955.38 3840.45 3800.00 57 O N 13 52 E 2577.16 1.41 24.90 N 3.72 38.77 N 1.68 57.34 N 2.87 79.55 N 2.14 105.87 N 2.02 136.37 N 1.96- 170.73 N 1.99 209.39 N 1.15 252.26 N 2.25 298.82 N I .69 2.34 0.55 3.04 3.57' 2.39 0.13 W 24.90 N 0 18 W 1.74 E 38.81 N 2 35 E 5.58 E 57.61 N 5 34 E 11.27 E 80.35 N 8 4 E 18.42 E 107.45 N 9 52 E 26.90 E 139.00 N 11 10 E 37.27 E 174.75 N 12 19 E 49.42 E 215.14 N 13 17 E 62.35 E 259.85 N 13 53 E 75.91 E 308.31 N 14 15 E 349.90 N 90.60 E 361.44 N 14 31 E 405.76 N 104.70 E 419.05 N 14 28 E 467.93 N 119.22 E 482.87 N 14 18 E 533.83 N 135.18 E 550.68 N 14 13 E 608.86 N 154.04 E 628.04 N 14 12 E 697.72 N 176.90 E 719.80 N 14 14 E 3.64 . 799.13 N 203.73 E 824.69 N 14 18 E 2.11 917.88 N 236.14 E 947.77 N 14 26 E 0.52 1049.08 N 273.21 E 1084.07 N 14 36 E 0.82 1179.26 N 309.42 E 1219.18 N 14 42 E 0.46 0.97 0.98 0.54 1 .23 1 .43 1 .0t 2.12 0.49 1.11 1307.64 N 343.78 E 1352.07 N 14 44 E 1434.26 N 376.21 E 1482.78 N 14 42 E 1558.79 N 406.66 E 1610.96 N 14 37 E 1682.81 N 435.92 E 1738.35 N 14 31 E 1804.24 N 464.53 E 1863.08 N 14 26 E 1930.47 N 494.04 E 1992.68 N 14 21 E 2060.46 N 525.5B E 2126.43 N 14 19 E 2198.47 N 558.55 E 2268.31 N 14 15 E 2350.77 N 593.90 E 2424.63 N 14 11 E 2506.22 N 630.99 E 2584.43 N 14 8 E BP EXPLORATZON PT. MCZNTVRE #9 PT. MCZNTYRE NORTH SLOPE, ALASKA COMPUTATZON DATE: 6-JAN-91 PAGE 7 DATE OF SURVEY: 22-DEC-90 KELLV BUSHZNG ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA 1NTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERT[CAL VERTICAL DEVIAT[ON AZIMUTH DEPTH DEPTH DEPTH DEG MZN DEG VERTZCAL DOGLEG RECTANGULAR COORDZNATES HORZZ. DEPARTURE SECTZON SEVERZTY NORTH/SOUTH EAST/WEST DZST. AZZMUTH FEET DEG/IO0 FEET FEET FEET DEG MZN 5139.86 3940.45 3900.00 57 27 N 14 25 E 2731.73 5318.40 4040.45 4000.00 54 10 N 14 0 E 2879.18 5485.31 4140.45 4100.00 53 37 N 14 31 E 3012.47 5658.19 4240.45 4200.00 54 48 N 15 53 E 3153.22 5834.22 4340.45 4300.00 56 44 N 16 18 E 3297.97 6024.65 4440.45 4400.00 59 35 N 15 49 E 3459.88 6220.68 4540.45 4500.00 59 27 N 15 32 E 3628.28 6411.72 4640.45 4600.00 56 38 N 15 26 E 3790.82 6591.86 4740.45 4700.00 55 38 N 15 34 E 3940.46 . 6769.94 4840.45 4800.00 55 18 N 16 18 E 4087.66 0.56 3.17 0.58 1.03 1.31 0.67 0.03 O. 68 2656.56 N 668.77 E 2739.44 N 14 8 E 2800.03 N 704.61 E 2887.32 N 14 7 E 2929.49 N 737.73 E 3020.95 N 14 8 E 3065.74 N 774.07 E 3161.96 N 14 10 E 3204.81 N 814.59 E 3306.72 N 14 16 E 3360.45 N 859.68 E 3468.67 N 14 21 E 3522.78 N 905.23 E 3637.22 N 14 25 E 3679.53 N 948.98 E 3799.93 N 14 28 E 2.16 3823.93 N 988.96 E 3949.74 N 14 30 E 2.09 3965.64 N 1029.33 E 4097.05 N 14 33 E 6940.30 4940~45 4900.00 52 48 N 16 19 E 4225.47 7104.51 5040.45 5000.00 51 47 N 16 52 E 4355.66 7266.05 5140.45 5100.00 51 3 N 17 36 E 4482.49 7425.71 5240.45 5200.00 52 29 N 17 29 E 4606.92 7594.87 5340.45 5300.00 53 58 N 18 3 E 4743.34 7768.07 5440.45 5400.00 55 46 N 16 13 E 4884.70 7945.30 5540.45 5500.00 55 O N 18 14 E 5030.95 8115.57 5640.45 5600.00 54 14 N 18 2 E 5168.74 8286.51 5740.45 5700.00 53 54 N 16 45 E 5307.33 8455.77 5840.45 5800.00 53 24 N 16 47 E 5443.84 1.40 4097.98 N 1068.12 E' 4234.89 N 14 37 E 0.48 4222.76 N 1105.47 E 4365.06 N 14 40 E 2.19 4344.02 N 1142.73 E 4491.81 N 14 44 E 2.12 4462.61 N 1180.47 E 4616.10 N 14 49 E 1.45 4592.81 N 1221.25 E 4752.40 N 14 53 E 1.38 4727.79 N 1263.32 E 4893.67 N 14 58 E 1.98 4867.77 N 1305.88 E 5039.89 N 15 1 E 2.46 4998.10 N 1350.61 E 5177.37 N 15 7 E 0.56 5130.73 N 1390.98 E 5315.94 N 15 10 E 1.81 5261.52 N 1430.29 E 5452.46 N 15 12 E 8624.58 5940.45 5900.00 54 4 N 17 34 E 5579.79 8798.89 6040.45 6000.00 56 18 N 17 39 E 5722.55 8978.31 6140.45 6100.00 55 52 N 15 45 E 5871.45 9159.82 6240.45 6200.00 56 27 N 14 14 E 6022.68 9343.89 6340.45 6300.00 56 47 N .12 53 E 6176.73 9523.64 6440.45 6400.00 56 2 N 12 39 E 6325.29 9706.50 6540.45 6500.00 56 49 N 12 36 E 6477.59 9891.98 6640.45 6600.00 58 32 N 12 32 E 6632.99 10075.04 6740.45 6700.00 55 51 N 12 17 E 6785.43 10251.36 6840.45 6800.00 54 44 N 11 24 E 6929.72 I .48 2.68 1.64 0.38 1.97 0.83 0.40 1.97 1.81 2.45 5391.51 N 1470.23 E 5588.38 N 15 15 E 5527.51 N 1513.67 E 5731.02 N 15 19 E 5670.06 N 1556.90 E 5879.92 N 15 21 E 5816.20 N 1596.68 E 6031.39 N 15 21 E 5966.18 N 1633.88 E 6185.86 N 15 19 E 6112.02 N 1666.17 E 6335.06 N 15 15 E 6261.40 N 1699.63 E 6487.98 N 15 11 E 6413.82 N 1733.78 E 6644.03 N 15 8 E 6563.58 N 1766.57 E 6797.15 N 15 4 E 6705.65 N 1796.63 E 6942.16 N 15 0 E 10419.76 6940.45 6900.00 52 36 N 12 36 E 7064.29 10585.40 7040.45 7000.00 53 36 N 15 19 E 7195.89 10759.92 7140.45 7100.00 56 52 N 18 30 E 7338.82 10937.58 7240.45 7200.00 54 32 N 18 5 E 7485.64 11108.24 7340.45 7300.00 54 2 N 19 22 E 7623.92 11277.90 7440.45 7400.00 53 6 N 23 19 E 7760.78 11448.51 7540.45 7500.00 54 36 N 26 18 E 7898.06 11621.87 7640.45 7600.00 54 47 N 27 37 E 8038.09 11794,91 7740.45 7700.00 S4 37 N 28 39 E 8177o26 11967.45 7840.45 7800.00 54 27 N 28 9 E 8315.88 1.27 6838°24 N 1824.43 E 7077.43 N 14 56 E 1.61 6966.49 N 1855.83 E 7209.44 N 14 55 E 1.05 7103.12 N 1897.92 E 7352.31 N 14 58 E 1.40 7242.51 N 1944.03 E 7498.88 N 15 2 E 2.12 7373.36 N 1988.75 E 7636.85 N 15 6 E 2.46 7501.05 N 2038.46 E 7773.10 N 15 12 E 0.73 7626.25 N 2096.99 E 7909.30 N 15 22 E 0.47- 7752.43 N 2161.27 E 8048.06 N 15 35 E 1.07 7876.90 N 2227.96 E 8185.93 N 15 48 E 0.65 8000.97 N 2294.11 E 8323,37 N 16 0 E BP EXPLORATION PT. MCINTYRE #9 PT. MCZNTVRE NORTH SLOPE, ALASKA COMPUTATION DATE= .6-JAN-91 PAGE 8 DATE OF SURVEY: 22-DEC-90 KELLY BUSHING ELEVATION: 40.45 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN .100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG FEET DEG/IO0 12137.87 7940.45 7900.00 53 41 12303.51 8040.45 8000.00 51 41 12461.79 8140.45 8100.00 49 51 12614.42 8240.45 8200.00 48 22 12762.10 8340.45 8300.00 46 2 12903.95 8440.45 8400.00 45 3 13047.41 8540.45 8500.00 44 36 13182.50 8640.45 8600.00 40 3 13309.88 8740.45 8700.00 36 56 13434.08 8840.45 ~8800.00 35 55 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZ[MUTH FEET FEET FEET DEG 1.53 1.96 1.43 1.68 3.45 2.60 4.08 4.09 1.30 0.80 N 28 26 E 8451.79 N 29 3 E 8581.84 N 30 59 E 8702o01 N 32 49 E 8814.16 N 32 17 E 8919.15 N 29 23 E 9017.59 N 30 45 E 9118.33 N 31 12 E 9206.94 N 31 56 E 9283.83 N 33 51 E 9355.10 8122.34 N 2359.78 E 8458.19 N 16 12 E 8238.53 N 2422.49 E 8587.31 N 16 23 E 8344.73 N 2483.91 E 8706.56 N 16 35 E 8442.67 N 2544.75 E 8817.85 N 16 46 E 8533.43 N 2604.49 E 8922.04 N 16 58 E 8620.28 N 2655.20 E 9019.94 N 17 7 E 8709.32 N 2706.69 E 9120.22 N 17 16 E 8787.13 N 2753.44 E 9208.43 N 17 24 E 8854.52 N 2794.45 E 9285.01 N 17 31 E 8916.27 N 2834.60 E 9356.00 N 17 38 E 13557.96 8940.45 8900.00 36 15 N 34 28 E 9425.48 13682.49 9040.45 9000.00 36 55 N 35 39 E 9496.57 13808.05 9140.45 9100.00 37 26 N 35 52 E 9569.12 13935.03 9240.45 9200.00 38 39 N 34 48 E 9643.91 14063.83 9340.45 9300.00 39 36 N 32 40 E 9722.19 14194.62 9440.45 9400.00 40 41 N 30 46 E 9804.27 14327.04 9540.45 9500.00 41 1 N 30 42 E 9889.12 14375.00 9576.64 9536.19 41 1 N 30 42 E 9919.87 0.49 8976.76 N 2875.67 E 9426.12 N 17 46 E 1.21 9037.48 N 2918.35 E 9496.99 N 17 54 E 0.41 9099.21 N 2962.55 E 9569.34 N 18 2 E 1.13 9162.89 N 3008.03 E 9644.00 N 18 10 E 1.32 9230.37 N 3053.13 E 9722.21 N 18 18 E 1.34 9302.19 N 3097.25 E 9804.27 N 18 25 E 0.00 9376.85 N 3141.59 E 9889.13 N 18 31 E 0.00 9403.91 N 3157.65 E 9919.90 N 18 34 E BP EXPLORATION PT. MCINTVRE #9 PT. MCINTVRE NORTH SLOPE, ALASKA MARKER LAST GCT READING DRILLERS DEPTH COMPUTATION DATE: 6-JAN-91 PAGE 9 DATE OF SURVEY: KELLY BUSHING ELEVATION: 22-DEC-90 40.45 FT ENG]NEER: JEFF FORM]CA [NTERPOLATED VALUES FOR CHOSEN HORZZONS SURFACE LOCATION = 535' FNL & 1048' FWL, SEC14 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 14217.00 9457.39 9416.94 9314.76 N 3104.73 E 14375.00 9576.64 9536.19 9403.91 N 3157.65 E BP EXPLORATION PT. MCINTVRE #9 PT. MCZNTVRE NORTH SLOPE, ALASKA MARKER LAST GCT READING DRILLERS DEPTH COMPUTATION DATE= 6-JAN-91 PAGE 10 DATE OF SURVEY= 22-DEC-90 KELLY BUSH[NG ELEVAT[ON= 40.45 FT ENG[NEER= JEFF FORM[CA SURFACE LOCATION = 535' FNL & 104B' FWL, SEC14 T12N R14E MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 14217.00 9457.39 9416.94 9314.76 N 3104.73 E 14375.00 9576.64 9536.19 9403.91N 3157.65 E FINAL WELL LOCATION AT T~: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 14375.00 9576.64 9536.19 HOR[ZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 9919.90 N 18 34 E SCHLUMBEROER D I RECT I ONAL SURVEY COMPANY BP EXPLORATION WELL PT. MCINTYRE =9 F I ELD PT. MC I NTYRE COUNTRY USA RUN ONE DATE LOOOED 22 '- DEC - 90 REFERENCE ?4268 CONFIDENTIAL WELL: PI[., MCINTYRE #9 (535' FNL, 1048' FWL, SEC 14,i .2N, R14E) HORIZONTAL PROJECTION 6CIN. E -, ]/~O IN/FT 4OO0 80OTH -,4000 -6000 I, IEST . 0 2000 4000 6000 8000 100o0 CONFIDENTIAL WELL: PT. MCINTYRE #9 (535' ,FNL, 1048' FWL, SEC !4{,'r' 12N, R14E) -4OO0 -20(~3 0 0 ~ 40O0 · VERTICAL PROJECTION PRO~CTI~ 0N VERTICI:IL Pt.l:tl~ 18. - 198. ~ 1N YF. RTIC~:~ HORIZ SCI~..E · 1/2000 IN/FT CONFIDENTIAL CONFIDENT'i . . GREAT LAND DIRECTIONAL DRILLING, INC. REPORT OF SUB-SURFACE DIRECTIONAL SURVEY BP EXPLORATION POINT MCINTYRE #9 ~ !..'~...3 ~"~ ~-'~ ~ ,./ ~ ." WELL NAME A~aska Oi! 6.: O~.s 6~'~s. POINT MC I NTYRE/~ri,~:;~ KA LOCATION vo 0 It 1.6_tN&! '"" ALl190D39 JOB NUMBER DON LEJUENE NAME, MWD 12/05/90 TYPE SURVEY ' ~lDATE SUPERVISOR ~/ i ,/'" ' __x~.' ~''- TITLE SIGNATURE DEPTH INTERVAL 480 FT. 12895 FT. mm FROM TO DATE SURVEY TAKEN 11/02/90 12/05/90 FROM TO THIS IS A RECORD OF.A SUB-SURFACE SURVEY OF YOUR WELL WE HAVE RETAINED A COPY OF YOUR SURVEY REPORT IN OUR FILES FOR YOUR CONVENIENCE; HOWEVER, SHOULD YOU SO DESIRE, ALL COPIES OF THE SURVEY REPORT WILL BE FORWARDED TO YOU ON WRITTEN REQUEST. ALL SURVEYS ARE KEPT IN A LOCKED FILE AND ARE HELD IN STRICTEST CONFIDENCE. GREAT LAND DIRECTIONAL DRILLING, Client .... : BP EXPLORATION Field ..... -: POINT MCINTYRE Well ...... : POINT MCINTYRE Section at: -N,18.36,E Engineer..: DON LEJUENE #9 S MEAS INCLN C DEPTH ANGLE 3 480 0.25 3 595 0.40 3 685 2.00 3 776 4.00 3 865 5.80 VERTICAL-DEpTHS BKB SUB-SEA INC. SECTION DISTNCE 480.0 438.5 0.1 595.0 553.5 -0.1 685.0 643.5 1.3 775.8 734.3 5.7 864.5 823.0 12.8 3 956 7.50 954.9 913.4 3 1046 9.80 1043.9 1002.4 3 1136 12.30 1132.2 1090.7 3 1226 13.40 1219.9 1178.4 3 1319 15.70 1310.0 1268.5 3 1413 17.70 1400.0 1358.5 3 1507 19.70 1489.0 1447.5 3 1601 21.70 1576.9 1535.4 3 1695 23.60 1663.7 1622.2 3 1790 24.90 1750.3 1708.8 3 1884 26.80 1834.9 1793.4 3 1978 28.40 1918.2 1876.7 3 2072 30.00 2000.2 1958.7 3 2177 32.70 2089.9 2048.4 3 2270 33.00 2168.0 2126.5 3 2364 35.20 2245.9 2204.4 'Survey Codes: 3/MWD ( PM9D ) 23.0 36.3 53.4 73.4 96.7 123.7 153.8 187.1 223.3 262.3 303.3 346.8 392.6 447.1 497.4 550.1 12/11/90 Computation...: RADIUS OF CURVATURE Survey Date...: 12/05/90 RKB Elevation.: 41.50 ft Reference ..... : Magnetic Dcln.: 30.60 E RECORD OF SURVEY DIRECTION RELATIVE-COORDINATES CLOSURE BEARING. FROM-WELL-HEAD DISTNCE BEARING DL /lOO S 44.00 W 0.3 N 0.8 W 0.8 N 68.00 W 0.05 N 36.20 W 0.3 N 1.3 W 1.4 N 75.44 W 0.13 N 7.40 W 2.1 N 2.0 W 2.9 N 44.24 W 1.78 N 3.90 W 6.8 N 2.5 W 7.3 N 20.08 W 2.20 N 1.10 E 14.4 N 2.7 W 14.7 N 10.52 W 2.02 N 5.30 E 24.9 N 2.1 W 25.0 N 4.79 W 1.87 N 10.60 E 38.3 N 0.2 W 38.3 N 0.33 W 2.56 N 12.70 E 55.2 N 3.3 E 55.3 N 3.38 E 2.78 N 15.50 E 74.6 N 8.1 E 75.1 N 6.22 E 1.23 N 15.80 E 97.1 N 14.4 E 98.2 N 8.46 E 2.47 N 15.50 E 123.1 N 21.7 E 125.0 N 10.01 E 2.13~. N 17.90 E 152.0 N 30.4 E 155.0 N 11.31 E 2.}~ N 19.00 E 183.5 N 40.9 E 188.0 N 12.56 E 2' N 17.20 E 217.9 N 52.1 E 224.1 N 13.46 E 2 · N 18.60 E 255.1 N 64.1 E 263.0 N 14.12 E 1.~ N 16.50 E 294.1 N 76.5 E 303.9 N 14.58 E N 17.20 E 335.8 N 89.1 E 347.4 N 14.86 E N 14.10 E 380.0 N 101.5 E 393.3 N 14.96 E N 14.80 E 432.9 N 115.1 E 447.9 N 14.89 E N 15.50 E 481.5 N 128.3 E 498.3 N 14.92 E N 15.50 E 532.3 N 142.4 E 551.0 N 14.98 E 2. ~ POINT MCINTYRE #9 S MEAS INCLN C DEPTH ANGLE 3 2458 38,60 3 2551 42.10 3 2646 45.30 3 2742 46.80 3 2834 50.00 3 2950 53.40 3 3025 54.00 3 3118 53.40 3 3212 53.30 3 3305 53.10 3 3400 52.60 3 3492 52.60 3 3585 52.10 3 3682 51.80 3 3775 51.60 3 3868 51.90 3 3962 51.30 3 4056 51.20 3 4147 52.00 3 4246 52.70 3 4338 53.00 3 4431 54.10 3 4527 55.30 3 4615 57.00 3 4708 58.00 VERTICAL-DEPTHS BKB SUB-SEA 2321.0 2279.5 2391.9 2350.4 2460.6 2419.1 2527.2 2485.7 2588.3 2546.8 2660.1 2618.6 2704.6 2663.1 2759.6 2718.1 2815.7 2774.2 2871.4 2829.9 2928.8 2887.3 2984.7 2943.2 3041.5 3000.0 3101.3 3059.8 3158.9 3117.4 3216.5 3175.0 3274.9 3233.4 3333.7 3292.2 3390.2 3348.7 3450.7 3409.2 3506.3 3464.8 3561.5 3520.0 3617.0 3575.5 3666.0 3624.5 3716.0 3674.5 3 4802 58.40 3765.5 3724.0 'Survey Codes: 3/MWD RECORD OF SURVEY SECTION DISTNCE DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 606.5 N 16.50 E 586.6 N 157.9 E 666.6 N 16.20 E 644.3 N 174.9 E 732.2 N 15.50.E 707.5 N 192.8 E 801.2 N 15.50 E 774.1 N 211.3 E 870.0 N 17.20 E 840.1 N 230.6 E 960.9 N 15.80 E 927.3 N 256.5 E 1021.3 N 16.90 E 985.3 N 273.5 E 1096.2 N 15.50 E 1057.3 N 294.4 E 1171.6 N 15.50 E 1130.0 N 314.6 E 1245.9 N 14.80 E 1201.9 N 334.0 E N 15.80 E N 14.80 E N 14.10 E N 13.70 E N 13.70 E -. 1321.5 1394.5 1468.0 .1544.1 1616.9 1274.9 N 354.0 E 1345.4 N 373.3 E 1416.7 N 391.7 E 1490.8 N 410.0 E 1561.8 N 427.3 E 1689.6 N 13.70 E 1632.7 N 444.6 E 1763.1 N 14.10 E 1704.2 N 462.3 E 1836.2 N 13.40 E 1775.4 N 479.7 E 1907.2 N 13.00 E 1844.9 N 496.0 E 1985.3 N 14.10 E 1921.1 N 514.4 E 2058.4 N 14.10 E 1992.2 N 532.2 E 2133.0 N 14.40 E 2064.7 N 550.7 E 2211.2 N 15.10 E 2140.5 N 570.6 E 2284.2 N 14.40 E 2211.1 N 589.2 E 2362.4 N 13.70 E 2287.2 N 608.3 E 2442.0 N 13.40 E 2364.9 N 627.0 E Page 2 12/11/90 CLOSURE DISTNCE BEARING 607.5 N 15.07 E 667.7 N 15.19 E 733.3 N 15.25 E 802.4 N 15.27 E 871.2 N 15..35 E DL /lOO 3.64 3.77 3.39,--,, 1.56 3.64 962.2 N 15.46 E 3.03 1022.6 N 15.51E 1.25 1097.5 N 15.56 E 1.17 1173.0 N 15.56 E 0.11 1247.4 N 15.53 E 0.53 1323.1 N 15.52 E 0.85 1396.2 N 15..51 E 0.69 1469.8 N 15.45 E 0.71 1546.2 N 15.38 E 0.40 1619.2 N 15.30 E 0.22 1692.2 N 15.23 E 1765.8 N 15.18 E 1839.1 N 15.12 E 1910.4 N 15.05 E 1988.7 N 14.99 E 2062.1 N 14.96 E 2136.9 N 14.93 E 2215.2 N 14.93 E 2288.3 N 14.92 E 2366.7 N 14.89 E 2446.6 N 14.85 E 0.32 0.69 0.46 0 POINT MCINTYRE #9 S MEAS INCLN C DEPTH ANGLE 3 4890 57.60 3 4984 56.60 3 5079 57.60 3 5173 57.40 3 5267 55.10 3 5362 53.30 3 5455 52.60 3 5549 54..80 3 5641. 54.80 3 5736 54.70 3 5831 56.40 3 5925 58.10 3 6020 59.40 3 6109 59.20 3 6208 59.40 3 6301 59.00 3 6394 57.70 3 6487 56.30 3 6580 55.60 3 6674- 56.30 3 6767 55.50 3 6862 53.80 3 6955 52.60 3 7048 52.60 3 7143 51.50 3 7235 51.60 ~Survey Codes: VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3812.1 3770.6 2516.4 3863.2 3821.7 2595.1 3914.8 3873.3 2674.8 3965.3 3923.8 2753.9 4017.5 3976.0 2831.8 4073.1 4031.6 2908.7 4129.1 4087.6 2982.7 4184.8 4143.3 3058.3 4237.8 4196.3 3133.4 4292.6 4251.1 3210.9 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 14.40 E 2437.3 N 644.9 E N 15.10 E 2513.6 N 665.0 E N 14.40 E 2590.8 N 685.3 E N 15.10 E 2667.4 N 705.5 E N 13.70 E 2743.1 N 724.9 E N 14.10 E 2817.9 N 743.4 E N 15.50 E 2889.7 N 762.4 E N 14.40 E 2962.9 N 781.9 E N 15.50 E 3035.5 N 801.3 E N 16.50 E 3110.1 N 822.7 E 4346.4 4304.9 3289.2 N 17.20 E 4397.2 4355.7 3368.2 N 16.50 E 4446.5 4405.0 3449.4 N 16.20 E 4491.9 4450.4 3525.9 N 17.20 E 4542.5 4501.0 3611.0 N 16.90 E 4590.1 4548.6 3690.8 4638.9 4597.4 3769.9 4689.6 4648.1 3847.9 4741.6 4700.1 3924.8 4794.3 4752.8 4002.7 4846.4 4804.9 4079.7 4901.4 4859.9 4157.1 4957.1 4915.6 4231.6 5013.6 4972.1 4305.4 5072.0 5030.5 4380.4 5129.2 5087.7 4452.4 Page 3 12/11/90 CLOSURE DISTNCE BEARING 3/MWD DL /lOO 2521.2 N 14.82 E 1.22 2600.1 N 14.82 E 1.18 2679.9 N 14.82 E 1.18 ~_~. 2759.2 N 14.81E 0.57 2837.3 N 14.80 E 2.64 2914.3 N 14.78 E 2988.6 N 14.78 E 3064.3 N 14.78 E 3139.5 N 14.79 E 3217.1 N 14.82 E 1.91 1.21 2.47 0.80 0.71 3185.1 N 845.4 E 3295.3 N 14.87 E 1.86 3260.7 N 868.3 E 3374.4 N 14.91E 1.89 3338.6 N 891.2 E 3455.5 N 14.95 E 1.39 3411.9 N 913.2 E 3532.0 N 14.98 E 0.86 3493.3 N 938.1 E 3617.1 N 15.03 E 0.30 N 15.80 E 3570.0 N 960.6 E N 16.50 E 3646.0 N 982.6 E N 15.10 E 3721.1 N 1003.9 E N 16.90 E 3795.1 N 1025.1 E N 16.50 E 3869.7 N 1047.5 E 3697.0 N 15.06 3776.1 N 15.08 3854.1 N 15.10 3931.1 N 15.12 4009.0 N 15.15 N 17.20 E 3943.4 N 1069.8 E 4086.0 N 16.50 E 4017.6 N 1092.3 E 4163.4 N 17.20 E 4088.9 N 1113.9 E 4237.9 N 18.30 E 4159.2 N 1136.4 E 4311.7 N 18.30 E 4230.3 N 1159.9 E 4386.5 N 17.60 'E 4298.9 N 1182.1 E 4458.5 E 0.97 E 1.50 E 1.83 N 15.38 E N 15.18 E ~ N 15.21 E N 15.24 E N 15.28 E ~ POINT MCINTYRE #9 MEAS INCLN DEPTH ANGLE 7329 51,00 7421 52,60 7516 54,50 7608 53,80 7702 55,40 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5188,0 5146,5 4525,8 5244,8 5203,3 4598,1 5301,3 5259,8 4674,5 5355,2 5313,7 4749,0 5409,6 5368,1 4825,7. 3 7798 55,80 5463,9 5422,4 3 7892 55,50 5516,9 5475,4 3 7986 54,10 5571,1 5529,6 3 B085 54,10 5629,1 5587,6 3 8179 54,30 5684,1 5642,6 3 8273 54,10 5739,1 5697,6 3 8366 54,00 5793,7 5752,2 3 8462 53,60 5850,4 5808,9 3 8550 53,90 5902,4 5860,9 3 8645 54,40 5958,1 5916,6 3 8739 55,40 6012,1 5970,6 3 8833 56,60 6064,7 6023,2 3 8928 55,70 6117,6 6076,1 3 9022 56,60 6170,0 6128,5 3 9117 56,70 6222,2 6180,7 3 ~ 9212 57,00 6274,1 6232,6 3 9304 57,40 6324,0 6282,5 3 9398 56,50 6375,2 6333,7 3 9492 56,00 6427,5 6386,0 3 9585 56,90 6478,9 6437,4 4904,9 4982,4 5059,2 5139,4 5215,6 RECORD OF SURVEY 5291,9 5367,1 5444,6 5515,6 5592,6 5669,5 5747,4 5826,3 5904,3 5983.6 6063,0 6140,1 6218,6 6296,5 6373,8 3 9679 57.10 6530.1 6488.6 6452.3 'Survey Codes: 3/MWD DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 19,00 E '4368,5 N 1205,2 E N 17,90 E 4437,1 N 1228,0 E N 18,30 E 4509,7 N 1251.8 E N 19,00 E 4580,4 N 1275,6 E N 17,90 E 4653,1 N 1299,9 E N 16,90 E 4728,7 N 1323,6 E N 17,60 E 4802,8 N 1346,6 E N 20,80 E 4875,3 N 1371,8 E N 19,70 E 4950,5 N 1399,6 E N 17,20 E 5022,9 N 1423,7 E N 17,60 E 5095,6 N 1446,5 E N 18.30 E 5167,2 N 1469,7 E N 17,90 E 5240,9 N 1493,8 E N 18,30 E 5308,3 N 1515,8 E N 17,60 E 5381,6 N 1539,6 E Page 4 CLOSURE DISTNCE BEARING 4531,7 N 15,42 E 4603,9 N 15.47 E 4680,2 N 15,51E 4754,7 N 15,56 E 4831,2 N 15,61 E 4910,4 N 15,64 E 4988,0 N 15,66 E 5064,6 N 15,72 E 5144,6 N 15,79 E 5220,7 N 15.83 E i2/ii/9o 5296,9 N 15,85 E 5372,2 N 15,88 E 5449.6 N 15,91E 5520,5 N 15,94 E 5597,5 N 15,96 E N 17,90 E 5454,8 N 1563,0 E 5674,3 N 15,99 E N 17,60 E 5529,0 N 1586,8 E 5752,2 N 16,01 E N 17,20 E 5604,3 N 1610,4 E 5831,1 N 16.03 E N 17,60 E 5678,8 N 1633,7 E 5909,1 N 16,05 E N 15,50 E 5754.9 N 1656,3 E 5988,5 N 16,06 E N 14,10 E 5831,8 N 1676,6 E N 13,40 E 5906,9 N 1695,0 E N 13,70 E 5983,5 N 1713,5 E N 14,10 E 6059,4'N 1732,2 E N 13,70 E 6134,6 N 1750,9 E N 13,00 E 6211,3 N 1769,1 E 6068,0 N 16.04 E 6145,3 N 16,01 E 6224,0 N 15,98 E 6302,1 N 15,95 E 6379,6 N 15,93 E 6458.3 N 15.90 E DL /ioo 1,10 1,90 2.02 0,91 1,88 0,83 0,60 2,68 0,73 1,77 0,35 0,50 0.50 0.45 0,72 1,09 1,30 0.99 1,00 POINT MCINTYRE #9 MEAS INCLN DEPTH- ANGLE 9772 56,90 9864 58,40 9959 57,10 10053 55,90 10146 55,50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE RECORD OF SURVEY 6580,7 6539,2 6529,9 6629,9 6588,4 6607,3 6680,6 6639,1 6687,4 6732,5 6691,0 6765,5 6784,9 6743,4 6841,8 DIRECTION BEARING N 12,00 E N 14,10 E N 13,70 E N 12,30 E N 12,00 E 3 10240 55,10 6838,4 6796.9 6918,6 N 11,60 E 3 10334 53,50 6893,3 6851,8 6994,6 N 13,70 E 3 10427 52,90 6949.0 6907,5 7068,8 N 14,40 E 3 10520 52,60 7005,3 6963,8 7142,7 N 15,20 E 3 10614 53,60 7061,7 7020,2 7217,8 N 17,60 E 3 10707 56,00 7115,3 7073,8 7293,8 N 19,00 E 3 10801 56,70 7167,4 7125,9 7372,0 N 19,40 E 3 10895 54,80 7220,3 7178,8 7449,7 N 18,30 E 3 10990 54,50 7275,3 7233,8 7527,2 N 20,40 E 3 11102 54,10 7340,6 7299,1 7618,1 N 19,40 E 3 11196 54,10 7395,7 7354,2 7694~2 3 11291 53,50 7451,9 7410,4 7770,5 3 11384 54,60 7506,5 7465,0 7845,2 3 11477 55,10 7560,0 7518,5 7920,4 3 11570 55,10 7613,2 7571,7 7995,5 N 22,20 .E N 24,60 E N 26,40 E N 28,10 E N 28,80 E RELATIVE-COORDINATES FROM-WELL-HEAD 6287,4 N 1785,9 E 6363,2 N 1803,5 E 6441,1 N 1822,8 E 6517,5 N 1840,4 E. 6592,6 N 1856,6 E 6668,3 N 1872,4 E 6742,7 N 1889,1 E 6815,0 N 1907,2 E 6886,6 N 1926,1 E 6958,7 N 1947,3 E 7030,8 N 1971,2 E 7104,7 N 1996,9 E 7178,2 N 2022,0 E 7251,3 N 2047,7 E 7336,9 N 2078,6 E 7408,0 N 2105,7 E 7478,4 N 2136,1 E 7546,3 N 2168,5 E 7613,9 N 2203,3 E 7681,0 N 2239,7 E 3 11665 55,20 7667,5 7626,0 8072,3 N 27,80 E 7749,6 N 2276,6 E 3 11758 54,90 7720,8 7679,3 8147,4 N 28,10 E 7817,0 N 2312,4 E 3 11852 54,90 7774,8 7733,3 8223,1 N 28,80 E 7884,6 N 2349,0 E 3 11946 54,50 7829,1 7787,6 8298,7 N 28,10 E 7952,0 N 2385,6 E 3 12041 54,10 7884,6 7843,1 8374,6 N 29,20 E 8019,7 N 2422,5 E N 29.20 E 3 12132 53,90 7938,1 7896.6 8446.9 'Survey Codes: 3/MWD 8084.0 N 2458.5 E Page 5 12/11/90 CLOSURE DL DISTNCE BEARING /100 6536,2 N 15,86 E 0,78 6613,8 N 15,82 E 2,32 6694,1 N 15,80 E 1,40 6772,4 N 15,77 E 1,63 6849,1 N 15,73 E 0,48 6926,2 N 15,68 E 0,51 7002,4 N 15,65 E 2.23 7076.8 N 15,63 E 0,80 7150,8 N 15,63 E 0,63 7226,0 N 15,63 E 1.97 7301,9 N 15,66 E 2,78 7380,0 N 15,70 E 0,80 7457,6 N 15,73 E 2,17 7534,9 N 15,77 E 1,50 7625,6 N 15,82 E 0,69 7701,5 N 15,87 E 1,95 7777 5 N 15 94 E 1 75 7851,7 N 16,03 E 1.75 7926,3 N 16,14 E ~ 8000,9 N 16,26 E 8077,1 N 16,37 E ~ 8151,8 N 16,48 E ~ 8227,1 N 16,59 E ~ 8302,2 N 16,70 E 8377,6 N 16,81E ~ 8449.6 N 16.92 E ~ POINT MCINTYRE #9 MEAS INCLN DEPTH ANGLE 12226 52.90 12321 51.60 12414 50.40 12508 49.40 12601 48.50 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 7994.1 7952.6 8521.1 8052.3 8010.8 8595.0 8110.8 8069.3 8665.6 8171.3 8129.8 8735.3 8232.4 8190.9 8803.2 3 12691 47.50 8292.6 8251.1 8867.7 3 12784 45.80 8356.5 8315.0 8933.1 3 12895 44.80 8434.5 8393.0 9010.1 -RECORD OF'"SURVEY ASurvey Codes: 3/MWD DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 6 CLOSURE DISTNCE BEARING N 28.10 E 8150.2 N 2494.6 E 8523.5 N 17.02 E N 29.50 E 8216.0 N 2530.8 E 8597.0 N 17.12 E N 32.00 E 8278.2 N 2567.8 E 8667.3 N 17.23 E N 33.10 E 8338.8 N 2606.5 E 8736.6 N 17.36 E N 32.70 E 8397.6 N 2644.6 E 8804.2 N 17.48 E 12/11/90 N 34.50 E 8453.4 N 2681.6 E 8868.5 N 17.60 E N 31.70 E 8510.0 N 2718.5 E 8933.7 N 17.72 E N 30.20 E 8577.7 N 2759.1 E 9010.5 N 17.83 E DL /loo 1.30 1.64 2.05 1.26 1.00 1.55 2.39 1.12 POINT MCINTYRE #9 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/11/90 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB 500 542 0.33 542 600 642 1.23 642 700 742 3.24 742 800 842 5.33 842 900 942 7.25 942 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 N 82.63 W 0.21 N 1.04 W 0 0 N 21.32 W 0.92 N 1.65 W 0 0 N 5.22 W 4.65 N 2.31 W 0 0 N. 0.20 W 12.17 N 2.68 W 1 1 N 4.68 E 23.20 N 2.23 W 1000 1044 9.74 1042 1100 1146 12.42 1142 1200 1248. 13.95 1242 1300 1352 16.40 1342 1400 1457 18.63 1442 1500 1563 20.89 1542 1600 1671 23.11 1642 1700 1780 24.77 1742 1800 1891 26.93 1842 1900 2005 28.85 1942 2000 2120 31.23 2042 2100 2238 32.90 2142 2200 2359 35.07 2242 2300 2484 39.59 2342 2400 2619 44.39 2442 2500 2763 47.53 2542 2600 2919 52.49 2642 2700 3088 53.60 2742 2800 3255 53.21 2842 2900 3421 52.60 2942 3000 3585 52.10 3042 2 i N 10.46 E 37.93 N 0.29 W 4 2 ~N 13.00 E 57.21 N 3.72 E 7 3 N 15,57 E 79.69 N 9.55 E 10 4 N 15.70 E 105.87 N 16.91E 15 5 N 16.62 E 136.23 N 25.50 E 21 6 N 18.55 E 170.44 N 29 8 N 17.66 E 208.78 N 39 9 N 18.46 E 251.19 N 50 11 N 16.56 E 297.33 N 63 13 'N 16.32 E 347.98 N 78 15 N 14.42 E 403.62 N 97 18 N- 15.26 E 464.96 N 117 20 N 15.50 E 529.36 N 143 26. N 16.41' E 602.52 N 178 35 N 15.70 E 689.20 N 222 44 N 15.89 E 788.92 N 278 56 N 16.17 E 903.60 N 346 69 N 15.96 E 1033.76 N 414 68 N 15.18 E 1163.29 N 479 66 N 15.57 E 1290.90 N 544 64 N 14.10 E 1416.72 N 36.46 E 49.27 E 62.85 E 77.45 E 92.79 E 107.50 E 123.74 E 141.57 E 162.65 E 187.71 E 215.46 E 249.69 E 287.79 E 323.71 E 358.51 E 391.68 E POINT MCINTYRE #9 Page 8 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/11/90 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB 3100 3747 51.66 3142 605 3200 3908 51.64 3242 667 3300 4068 51.31 3342 727 3400 4231 52.59 3442 789 '3500 4397 53.70 3542.' 856 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 3600 4571 56.14 3642 929 3700 4756 58.21 3742 1015 3800 4944 57.02 3842 1103 3900 5129 57.49 3942 1187 4000 5308 54.31 4042 1267 4100 5475 53.08 4142 1334 4200 5647 54.79 4242 1406 4300 5822 56.24 4342 1481 4400 6010 59.27 4442 1569 4500 6206 59.40 4542 1665 4600 6399 57.63 4642 1757 4700 6580 55.60 4742 1838 4800 6758 55.57 4842 1917 4900 6929 52.93 4942 1988 5000 7094 52.07 5042 2052 5100 '7255 51.47 5142 2113 5200 7415 52.50 5242 2174 5300 7585 53.98 5342 2243 5400 7758 55.63 5442 2317 5500 7935 54.86 5542 2394 5600 8106 54.14 5642 2465 62 N 13.70 E 61 N 13.87 E 60 N 13.35 E 62 N 13.93 E 66 N 14.29 E 1540.39 N 1663.55 N 1784.88 N 1909.36 N 2038.09 N 422.10 E 452.18 E 481.98 E 511.46 E 543.86 E 73 N 14.75 E 86 N 13.55 E 88 N 14.80 E 84 N 14.77 E 80 N 13.87 E 2175.19 N 2327.07 N 2481.59 N 2631.41N 2776.03 N 579.87 E 617.91 E 656.43 E 695.87 E 732.99 E 67 N 15.26 E 72 N 15.57 E 75 N 17.14 E 88 N 16.23 E 96 N 16.91 E 2905.43 N 3040.55 N 3178.07 N 3330.54 N 3491.73 N 766.72 E 802.73 E 843.26 E 888.84 E 937.66 E 93 N 16.43 E 81 N 16.90 E 79 N 17.13 E 71 N 17.01 E 64 N 18.30 E 3649.95 N 3794.95 N 3936.61 N 4069.28 N 4193.59 N 983.81 E 1025.07 E 1067.72 E 1107.85 E 1147.76 E 61 N 17.89 E 61 N 17.97 E 69 N 18.82 E 74 N 17.31 E 77 N 19.07 E 4313.65 N 4432.95 N 4562.67 N 4697.32 N 4836.35 N 1186.85 E 1226.69 E 1269.55 E 1313.91 E 1357.69 E 71 N 19.14 E 4966.67 N 1405.27 E , POINT MCINTYRE #9 Page 9 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/11/90 SUBSEA MEAS INCLN TVD DEPTH DEPTH ANGLE BKB MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 5700 8277 54.10 5742 2536 71 N 17.'63 E 5098.77 N 5800 8447 53.66. 5842 2605 70 N 17.96 E 5229.37 N 5900 8617 54.25 5942 2675 70 N 17.81 E 5359.58 N 6000 8791 56.07 6042 2750 75 N 17.73 E 5495.87 N 6100 8971 56.11 6142 2829 79 N 17.38 E 5638.03 N 6200 9152 56.81 6242 2911 82 N 14.98 E 5783.31 N 6300 9336 57.09 6342 2995 84 N 13.50 E 5933.39 N 6400 9517 56.24 6442 3076 81 N 13.99 E 6079.64 N 6500 9700 57.05 6542 3159 83 N 12.77 E 6228.53 N 6600 9886 58.10 6642 3244 86 N 14.01 E 6381.29 N 6700 10069 55.83 6742 3328 83 N 12.25. E 6530.48 N 6800 10245 55.01 6842 3404 - 76 N 11.72 E 6672.58 N 6900 10415 52.98 6942 3473 69 N 14.31 E 6805.38 N 7000 10580 53.24 7042 3539 65 N 16.73 E 6932.63 N 7100 10754 56.35 7142 3613 74 N 19.20 E 7067.72 N 7200 10932 54.68 7242 3690 78 N 19.11 E 7206.62 N 7300 11103 54.10' 7342 ' 3762. 72 N 19.44 E 7337.99 N 7400 11274 53.61 7442 3832 70 N 24.16 E 7465.61 N 7500 11445 54.93 7542 3903 71 N 27.51 E 7590.55 N 7600 11619 55.15 7642 3978 75 N 28.28 E 7716.66 N 7700 11794 54.90 7800 11967 54.41 7900 12138 53.84 8000 12304 51.84 8100 12462 49.89 1447.51 E 1490.06 E 1532.53 E 1576.19 E 1620.84 E 1664.04 E 1701.33 E 1737.31 E 1773.00 E 1808.02 E 1843.24 E 1873.28 E 1904.73 E 1939.28 E 1983.96 E 2031.62 E 2079.04 E 2130.33 E 2191.02 E 2259.08 E 7742 4053 75 N 28.37 E 7842.96 N 7842 4126 73 N 28.35 E 7967.29 N 7942 4196 71 N 29.13 E 8088.12 N 8042 4262 66 N 29.24 E 8204.16 N 8142 4320 58- N 32.56 E 8309.26 N 2326.33 E 2393.74 E 2460.76 E 2524.14 E 2587.42 E 8200. 12615 48.35 8242 4373 53 N 32.97 E 8406.26 N 2650.11 E ~ POINT MCINTYRE #9 Page 10 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 12/11/90 SUBSEA MEA'S INCLN DEPTH DEPTH ANGLE '8300 12762 46.19 TVD MD-TVD VERT DIRECTION RELATIVE COORDINATES BKB DIFF CRRT BEARING FROM WELL HEAD 8342 4421 48 N 32.35 E 8496.85 N 2710.28 E POINT MCINTYRE #9 Page 11 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 12/11/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 8.62 998 957 29 N 7.89 E 31N 2000 28.77 1938 1896 357 N 16.47 E 346 N 3000 53.80 2690 2648 1001 N 16.53 E 966 N 4000 51.26 3299 3257 1793 N 13.82 E 1733 N 5000 56.77 3872 3830 2608 N 14.98 E 2527 N 1 W 31 N 2.54 W 2.6 92 E 358 N 14.92 E 1.9 268 E 1002 N 15.49 E 1.2 469 E 1795 N 15.16 E 0.5 668 E 2613 N 14.82 E 1.2 6000 59.13 4436 4395 3432 N 16.26 E' 3322 N ~ 886 E 3438 N 14.94 E 1.4 7000 52.60 4984 4943 4267 N 17.73 E 4123 N 1125 E 4274 N 15.26 E 0.7 8000 54.10 5579 5538 5071 N 20.64 E 4886 N 1376 E 5076 N 15.73 E 0.7 9000 56.39 6158 6116 5886 N 17.51 E 5661 N 1628 E 5891 N 16.04 E 1.0 10000 56.58 6703 6662 6722 N 13.09 E 6475 N' 1831 E 6728 N 15.79 E 1.6 11000 54.46 7281 .7240 7535 N 20.31 E 7259 N 12000 54.27 7861 7819 8342 N 28.73 E 7991 N 2051 E 7543 N 15.77 E 0.7 2406 E 8345 N 16.76 E 0.9 and Dipeckionag Drig/ing, <KB>O 850 t700 2550 3400 4250 5950 6800 T 7650 ¥ D asoo 9350 10200 11050 11900 12750 i3600 t4450 i5300 850 VERTICAL SECTION VIEW BP EXPLORATION POINT MCINTYRE #9 Section at: N 18.36 E TVD Scale.: 1 inch = t700 feet Dep Scale.: i inch = 1700 feet Drawn .....: 12/tl/90 ~arker I~en~ifica~ion ND TVD SECTN INCLN A] KB 0 0 0 0.00 B) TD t2B95 8435 90t0 44.B0 850 1 t700 2550 3400 4250 5t00 5950 6800 7650 8500 Section Departure Harker Identification MD N/S ~) KB 0 0 N 0 E B) TO 12995 857B N 2759 E PLAN VIEW 8P EXPLORATION POINT MCINTYRE #9 CLOSURE .....: 9010 ft N 17.83 E DECLINATION.: 30.60 E SCALE .......: t inch = 1400 feet DRANN .......: 9~00 8400 7700 7000 6300 5600 490O 4200 3500 2~00 t400 700 700 700 0 700 <- )/E~T ' EAST -> t400 2i00 2800 3500 4200 4900" 5600 6300 7000 7700 ORIGINAL I BJ BP EXPLORATION PT. MCINTYRE #9 POST FRAC REPORT RECEIVED APP, 2 2 1991 Alaska Oil & Gas Cons. Commission Anchorage RANDALL CARTER PRUDHOE BAY. AK. (907) 659-2678 FRED BURT PRUDHOE BAY. AK. (907) 659-2678 TABLE OF CONTENTS I. ANALYSIS: A. WELL INFORMATION AND POST JOB SU~IMARY B. JOB DESCRIPTION II. MINI FRAC DATA AND STEP RATE: A. SIMULTANEOUS PLOT VS. TIME 1.) SCHUMERGER BHP, STP, AND RATE VS TIME STEP RATE 2.) SCHUMERGER BHP, STP, AND RATE VS TIME MINI FRAC B. NOLTE PLOT (BEGINNING WITH XL PAD ON FORMATION) C. LFC RATE, VISCOSITY, CROSSLINKER & BREAKER RATE VS. ELAPSED TIME E. SCHLUMBERGER BHP AND STP VS. SQUARE ROOT OF TIME H. MINIFRAC DATA LISTING III. FRAC JOB DATA: A. FRAC FLUID INVENTORY B. FRAC TREATMENT LOG C. DATABASE SHEET D. SIMULTANEOUS PLOT VS. TIME E. NOLTE PLOT (BEGINNING WITH PAD ON FORmaTION) F. LFC RATE, VISCOSITY, CROSSLINKER AND BREAKER RATE VS. ELAPSED TIME G. WELL HEAD PROPPANT PROPPANT VS. SLURRY VOLUME H. FRAC DATA LISTING JOB TICKET DATE OF JOB 621998 2-20-~91 CUSTOHER WELL BP PT~ HC~ #9 DATA FN3~C BJ SERVICES FRAC F.A.C~T.S~ T 0 SJ-SEBVICES 2-2'?-9i BP EXPLORAPtON PT, HC, :~i9 DP%TA F~RAC} BJ SERVICES FRAC. F~A~CJ,T~S~ ~}A~PP~ OF JOB ~ i}P iEXPi, ORAT.~ uN EL2PSE~ TINE JO~, PICRET 8 DATE OF JOB iSP ~{iXP LORAT'i ON PT i.'~'~.Q ~ DATA FRAC ?Ai SSRI/iCES ? H JOB TICKET# DATE OF JOB 621998 7 y 2-20-91 WE,lL BP PT. MC. #9 DATA FNAC BJ SERVICES FRAC F.A.C~T~S~ F { 2~ 0 2.,9 ~8~ 88 P JOB TICKET DATE OF JOB 6o]9e8 2-20-9t BP EXPL TION PT~ HC. #9 DATA FNAC BJ SERVICES FRAC F.A~C.T.S. JOB TICKET DATE OF JOB 621998 2-20-91 CUSTOMER WEL~, BP EX] P!ON PT. HC~ ~9 DATA FRAC BJ SERVICES FRAC 188 C E~?SE~ TI~E JOB TICKET DATE OF JOB 621.998 2-20~91 CUSTOMER ~ BP ON WELL ~ PT~ HC~ #9 DATA FP~C BJ SERVICES F~S,C F~A~C~T~S~ ~88 S C L ELAPSED TIME MINUTES SLURRY RATE bpm " '00:04 0 0:00:11 3.77 0:00:18 2.11 0:00:25 1.83 0:00:43 1.83 0:00:50 0:01:07 0:01:23 0:01:39 0:01:55 0:02:11 0:02:26 0:02:42 0:02:59 0:03:15 0:03:32 0:03:49 0:04:05 0:04:22 0:04:39 2.21 2.11 2.08 0 0 0 0 0 3.24 2.48 1.97 1.42 2.29 2 2.08 0:04:56 2.29 :05:13 2.97 ~:05:30 2.83 0:05:47 2.83 0:06:03 2.95 0:06:20 0:06:37 0:06:54 0:07:11 0:07:28 0:07:45 0:08:01 0:08:18 0:08:35 0:08:52 0:09:09 0:09:26 0:09:43 0:10:00 0:10:17 0:10:34 0:10:49 ~:11:06 :11:23 :11:40 2.86 2.92 2.99 2.92 3.38 3.95 4.05 4.03 4.11 4.09 4.15 4.09 4.05 4.09 5.34 5.13 5.13 5.05 5.13 5.11 STAGE TOT 0 .2 .48 .73 1.27 1.53 .35 .92 1.32 1.32 1.32 1.32 1.32 2.02 2.8 3.43 3.91 4.42 5 5.58 6.16 6.93 7.74 8.56 9.36 10.19 11.01 11.82 12.63 13.54 14.62 15.75 16.89 18.04 19.19 20.34 21.5 22.64 23.79 25.07 26.55 27.91 29.36 30.8 32.23 SLURRY TOTAL (bbl) 0 .2 .48 .73 1.27 1.53 2.13 2.71 3.11 3.11 3.11 3.11 3.11 3.81 4.59 5.21 5.7 6.21 6.79 7.37 7.95 8.72 9.53 10.34 11.15 11.97 12.79 13.61 14..42 15.33 16.4 17.54 18.68 19.83 20.98 22.13 23.28 24.43 25.58 26.86 28.34 29.7 31.14 32.58 34.02 CALC. B.H.T.P (SV) (psig) 4860 4854 5002 5088 5088 5311 5401 5470 5579 5608 5657 5734 5822 5829 5925 5940 5939 5941 5998 6025 6019 6153 6235 6303 6309 6351 6398 6464 6496 6527 6590 6673 6723 6729 6751 6787 6809 6802 6811 6823 6856 6847 6870 6886 6897 ME.~.~URED :.P.( 4452' 4452 4573 4662 4662 4881 5004 5090 5162 5211 5257 5294 5396 5474 5529 5570 5562 5534 5587 5605 5620 5680 5771 5846 5895 5937 5974 6005 6032 6075 6155 6232 6282 6311 6334 6351 6361 6371 6379 6388 6473 6474 6484 6490 6496 STP 2 882 939 1019 1117 1117 1339 1433 1519 1583 1624 1666 1750 1850 1920 1970 1981 1955 1985 2021 2039 2087 2200 2273 2340 2383 2427 2464 2492 2519 2601 2701 2772 2815 2838 2857 2865 2876 2881 2889 3002 3017 3020 3030 3033 3034 SCHLBRGR BHT 178 178 179 179 179 179 178 178 178 178 178 178 178 177 177 177 177 176 176 176 176 176 175 175 175 175 174 174 174 174 173 173 172 172 172 171 171 170 170 169 169 168 168 167 166 ELAPSED TIME MINUTES SLURRY RATE bpm :11:57 5.03 0:12:14 5.13 0:12:31 5.07 0:12:47 5.07 0:13:22 5.07 0:13:38 5.84 0:13:55 5.94 0:14:12 5.94 0:14:29 6.61 0:14:46 6.71 0:15:03 6.8 0:15:20 7.13 0:15:37 7.17 0:15:54 7.17 0:16:11 6.32 0:16:28 8.09 0:16:44 8.52 0:17:01 8.52 0:17:18 8.44 0:17:35 8.56 0:17:52 0 ' :18:08 0 ,:18:24 0 0:18:40 0 0:18:56 0 0:19:12 0 0:19:28 0 0:19:46 0 0:20:06 0 0:20:22 0 0:20:38 0 0:20:54 0 0:21:10 0 0:21:26 0 0:21:42 0 0:21:58 0 0:22:14 0 0:22:30 0 0:22:46 0 0:23:03 0 0:23:29 0 0:23:45 0 ~:24:02 0 ~24:17 0 ~:24:39 0 STAGE TOT/~" (bbl) 33.67 35.11 36.56 37.88 40.85 42.42 44.06 45.75 47.5 49.37 51.28 53.29 55.31 57.36 59.16 61.44 63.79 66.2 68.6 71.01 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 SLURRY TOTAL (bbl) 35.45 36.89 38.35 39.67 42.64 44.21 45.85 47.54 49.28 51.16 53.07 55.08 57.1 59.15 60.95 63.23 65.58 67.99 70.39 72.8 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 CALC. B .H.T.P (SV) (psig') 6895 6926 6913 6910 6914 6951 6964 6966 6993 6998 7050 7029 7036 7038 7035 7017 7049 7093 7094 7101 6617 6452 6375 6287 6219 6142 6074 6054 5996 5967 5899 5899 5841 5812 5763 5753 5744 5724 5676 5676 5666 5598 5598 5588 5569 ME~ ~URED B.~ 3.P.( 6501 6507 6513 6517 6520 6568 6575 6582 6588 6614 6632 6639 6646 6649 6651 6668 6686 6694 6698 6700 6580 6214 6088 6001 5932 5872 5818 5761 5708 5667 5628 5593 5559 5527 5497 5467 5440 5416 5391 5368 5357 5313 5292 5274 5250 STP 2 3037 3043 3046 3046 3046 3128 3151 3157 3209 3230 3253 3277 3280 3289 3257 3355 3401 3412 3415 3415 2611 2449 2349 2275 2216 2156 2106 2065 2014 1962 1925 1891 1860 1828 1801 1769 1748 1723 1700 1678 1666 1622 1592 1593 1579 SCHLBRGR BHT 166 165 164 164 163 162 161 160 160 159 159 158 157 157 156 156 155 154 153 153 152 152 152 152 152 152 152 152 152 152 152 152 152 153 153 153 153 153 153 153 153 154 154 154 154 ELAPSED TIME MINUTES ~24:55 0:25:11 0:25:28 0:25:55 0:26:12 0:26:28 0:26:44 0:27:00 0:27:16 0:27:32 0:27:47 0:28:03 0:28:20 0:28:36 0:28:52 0:29:08 0:29:24 0:29:41 0:29:57 0:30:13 0:30:30 :30:46 ~:31:02 0:31:18 0:31:34 0:31:50 0:32:06 0:32:23 0:32:39 0:32:55 0:33:11 0:33:27 0:33:52 0:34:09 0:34:26 0:34:42 0:34:58 0:35:33 0:35:50 0:36:06 0:36:23 0:36:41 ~:36:58 ~37:15 ~:37:32 SLURRY RATE bpm 0 0 0 1.38 0 2.51 8.18 13.1 13.35 14.11 STAG~ TOT (bbl~.) 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.58 71.66 71.7 71.85 74.06 77.27 81.13 84.92 SLURRY TOTAL ( bbl ) 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.36 73.45 73.49 73.64 75.85 79.05 82.91 86.7 CALC. B.H.T.P (SV) (psig) 5520 5511 5511 5491 5443 5443 5443 5443 5443 5433 5413 5394 5365 5365 5355 5355 5355 5336 5326 5326 5316 5326 5326 5316 5316 5326 5316 5297 5268 5258 5239 5219 5210 5666 6190 5918 5744 5656 5461 5433 6058 6909 7166 7176 7192 ME/9URED B.~ £.P.( 5234 5217 5200 5191 5161 5148 5135 5122 5110 5098 5087 5076 5065 5055 5045 5036 5026 5016 5007 4999 4990 4982 4974 4967 4959 4952 4944 4938 4931 4926 4923 4917 4906 4947 5681 5756 5498 5355 5182 5133 5154 6049 6562 6732 6740 STP 2 1545 1532 1516 1509 1478 1466 1451 1442 1429 1420 1407 1397 1388 1376 1366 1358 1349 1339 1329 1322 1315 1305 1299 1293 1285 1278 1270 1261 1262 1256 1250 1241 1236 1654 2214 1948 1752 1643 1482 1438 2110 3225 3894 3929 4007 SCHLBRGR BHT 154 154 154 154 154 154 154 154 154 154 154 155 155 155 155 155 155 155 155 155 155 155 155 155 155 155 155 155 155 156 156 156 156 156 156 156 156 156 156 156 156 156 156 154 153 ELAPSED TIME MINUTES ~37:49 0:38:07 0:38:24 0:38:42 0:38:59 0:39:16 0:39:34 0:39:51 0:40:09 0:40:26 0:40:44 0:41:01 0:41:19 0:41:36 0:41:54 0:42:12 0:42:29 0:42:47 0:43:04 0:43:21 0:43:39 :43:55 J:44:13 0:44:30 0:44:47 0:45:04 0:45:21 0:45:38 0:45:55 0:46:12 0:46:29 0:46:46 0:47:03 0:47:19 0:47:36 0:47:53 0:48:10 0:48:27 0:48:44 0:49:01 0:49:17 0:49:34 9:49:51 ~50:08 ~:50:25 SLURRY RATE bpm 14.74 19.54 20.54 22.55 25.7 26.71 30.76 31.38 34.29 33.9 36.29 36.54 36.54 36.68 35.91 35.29 35.91 35.91 35.91 35.91 35.91 36.04 36.04 36.18 36.43 36.04 36.04 36.18 36.29 36.29 36.43 36.29 36.43 36.43 36.04 36.04 36.04 36.04 36.18 36.04 33.9 31.88 36.93 34.65 35.54 STAGE. TOT_/~_' (bbl) 89.09 94.49 100 106 114 121 130 139 149 158 168 179 4.28 15.03 25.68 36.16 46.5 56.98 67.4 77.75 88.09 98.12 108 118 128 139 149 159 170 180 190 200 211 221 231 241 251 261 272 282 291 300 310 320 330 SLURRY TOTAL (bbl) 90.88 96.28 102 108 116 123 132 141 150 160 170 180 191 202 213 223 233 244 254 265 275 285 295 306 316 326 336 347 357 367 378 388 398 408 418 428 439 449 459 469 479 488 497 507 517 CALC. B.H.T.P (SV) (psig) 7232 7149 7095 7075 6915 6917 6820 6848 6836 6797 6886 6888 6967 6994 6839 6756 6794 6760 6708 6699 6675 6688 6630 6651 6624 6676 6678 6703 6684 6656 6683 6718 6752 6798 6820 6820 6811 6820 6790 6801 6767 6766 6842 6860 6863 .(~. ~URED £.P.( 6737 6777 6786 6774 6799 6782 6787 6794 6792 6766 6724 6725 6704 6693 6711 6715 6760 6859 6884 6899 6909 6923 6926 6919 6920 6918 6912 6902 6892 6884 6879 6873 6866 6864 6869 6865 6838 6828 6815 6812 6787 6781 6792 6789 6823 STP 2 4030 4527 4577 4795 4961 4992 5347 5384 5591 5274 5368 5168 4957 4719 4537 4421 4504 4519 4528 4550 4568 4595 4621 4647 4675 4713 4750 4793 4823 4874 4927 4966 5012 5068 5055 5048 5038 5048 5030 5033 4856 4652 5167 4959 5046 SCHLBRGR BHT 153 154 154 151 149 147 145 141 136 133 135 135 135 135 134 133 124 117 106 100 97.55 97.5 99.36 98.36 96.36 95.68 95.13 94.72 94.47 94.12 94.19 94.02 94.18 93.97 93.61 93.27 95.77 96.33 96.85 96.53 96.44 97.29 96.56 96.83 97.27 ELAPSED TIME MINUTES :50:42 0:50:59 0:51:16 0:51:33 0:51:50 0:52:06 0:52:23 0:52:40 0:52:57 0:53:14 0:53:31 0:53:48 0:54:05 0:54:22 0:54:39 0:54:56 0:55:13 0:55:30 0:55:48 0:56:05 0:56:21 :56:41 J:56:58 0:57:15 0:57:31 0:57:47 0:58:04 0:58:21 0:58:38 0:58:55 0:59:11 0:59:29 0:59:46 1:00:03 1:00:20 1:00:37 1:00:53 1:01:11 1:01:27 1:01:44 1:02:00 1:02:16 ":02:32 :02:48 .:03:04 SLURRY RATE bpm 35.54 35.54 35.41 35.54 35.41 35.54 35.41 35.54 35.54 35.66 35.41 35.41 35.54 35.54 35.41 35.66 35.54 35.79 35.66 35.79 35.91 35.91 35.79 35.79 35.79 36.04 36.18 36.18 36.29 36.29 36.43 36.54 36.81 36.68 35.91 35.91 35.91 35.79 17.27 0 STAGE, TOT~ (bbl) 340 350 360 370 380 390 400 410 420 430 440 450 460 470 480 490 1.95 12.11 22.86 32.9 43.02 54.56 64.97 74.98 84.26 94.38 104 114 124 134 145 2.14 12.56 23 33.21 43.35 53.5 63.75 72.67 72.67 72.67 72.67 72.67 72.67 72.67 SLURRY TOTAL (bbl) 527 537 547 557 567 577 587 597 607 617 627 637 647 657 667 677 687 697 708 718 728 740 750 760 770 780 790 8O0 810 820 830 841 851 862 872 882 892 902 911 911 911 911 911 911 911 CALC. B .H.T.P (SV) · (psig) 6863 6863 6864 6853 6864 6834 6816 6785 6785 6775 6796 6786 6737 6717 6718 6707 6694 6686 6711 6734 6774 6857 6961 7033 7051 7069 7016 6937 6957 6929 6949 6910 6842 6802 7028 7205 7398 7545 6026 5825 5806 5767 5747 5747 5747 ME~.-~URED 6824 6823 6821 6821 6817 6816 6813 6807 6803 6800 6799 6798 6799 6798 6795 6793 6791 6789 6788 6785 6779 6780 6804 6817 6817 6807 6803 6771 6749 6742 6741 6740 6740 6732 6720 6713 6708 6703 6700 5973 5910 5876 5862 5856 5856 STP 2 5O55 5050 5042 5047 5044 5030 '5010 4989 4981 4974 4968 4959 4943 4928 4923 4917 4908 4901 4880 4881 4905 4919 4983 5011 5009 4980 4943 4874 4830 4786 4746 4701 4637 4580 4697 4815 5001 5165 2932 2160 2159 2136 2124 2119 2126 SCHLBRGR BHT 97.42 97.44 97.14 96.71 96.15 95.76 95.52 95.34 95.19 95.23 95.48 95.9 96.4 97.26 98.4 98.82 98.93 99.24 99.05 94.64 94.37 94.89 93.76 91.4 88.52 93.13 91.11 92.3 92.58 93.03 93.54 94.58 95.22 95.4 95.06 93.48 93.82 93.75 93.8 93.64 93.39 93.06 92.96 93.1 93.05 ELAPSED TIME MINUTES :03:20 1:03:36 1:03:53 1:04:09 1:04:25 1:04:41 1:04:58 1:05:14 1:05:31 1:05:48 1:06:04 1:06:20 1:06:37 1:06:53 1:07:10 1:07:27 1:07:43 1:08:00 1:08:16 1:08:33 1:08:50 :09:06 ~:09:23 1:09:39 1:09:57 1:10:13 1:10:30 1:10:47 1:11:04 1:11:21 1:11:38 1:11:55 1:12:11 1:12:28 1:12:45 1:13:02 1:13:19 1:13:36 1:13:53 1:14:10 1:14:27 1:14:43 1.:15:00 ~15:17 _:15:34 SLURRY RATE bpm STAGE. TOT/~' (bbl) 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72'.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 SLURRY TOTAL (bbl) 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 CALC. B.H.T.P (SV) (psig) 5757 5757 5757 5747 5757 5747 5757 5757 5747 5757 5757 5747 5757 5747 5757 5747 5738 5738 5718 5689 5679 5679 5670 5670 5670 5670 5650 5621 5602 5602 5602 5592 5592 5592 5592 5582 5582 5553 5534 5524 5514 5524 5514 5505 5475 .,~, ,~URED r.P.( 5860 5866 5872 5876 5879 5879 5878 5875 5872 5867 5863 5558 5852 5845 5839 5830 5822 5815 5806 5797 5787 5776 5764 5755 5747 5738 5729 5721 5712 5704 5696 5689 5681 5672 5665 5656 5648 5641 5635 5628 5619 5612 5606 5599 5586 STP 2 2127 2133 2142 2143 2153 2151 2147 2145 2144 2141 2135 2135 2127 2121 2115 2107 2099 2089 2085 2077 2065 2053 2044 2034 2024 2015 2005 2001 1992 1982 1974 1966 1958 1948 1942 1934 1924 1918 1911 1901 1894 1888 1881 1875 1861 SCHLBRGR B~T 93.11 93.18 93.21 93.42 93.83 94.06 94.19 94.24 94.25 94.18 94.22 94.25 94.3 94.39 94.5 94.6 94.66 94.76 94.85 94.95 95.05 95.12 95.23 95.34 95.44 95.54 95.68 95.89 96.17 96.34 96.37 96.36 96.34 96.38 96.46 96.55 96.63 96.71 96.88 97.07 97.26 97.44 97.62 97.77 97.97 ELAPSED TIME MINUTES :15:52 1:16:09 1:16:26 1:16:42 1:16:59 1:17:16 1:17:33 1:17:50 1:18:07 1:18:24 1:18:40 1:18:57 1:19:14 1:19:31 1:19:48 1:20:05 1:20:22 1:20:38 1:20:55 1:21:12 1:21:29 :21:46 ~:22:03 1:22:19 1:22:36 1:22:53 1:23:10 1:23:26 1:23:43 1:24:00 1:24:17 1:24:34 1:24:50 1:25:07 1:25:24 1:25:41 1:25:57 1:26:14 1:26:31 1:26:47 1:27:04 1:27:21 %:27:38 ~27:55 -:28:12 SLURRY RATE bpm 0 0 128 0 .37 STAGE, TOT/~ (bbl) 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.67 72.68 85.63 148 148 SLURRY TOTAL (bbl) 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 911 924 987 987 CALC. B.H.T.P (SV) (psig) 5466 5456 5446 5437 5437 5437 5437 5437 5427 5388 5359 5359 5369 5349 5349 5340 5320 5301 5301 5281 5281 5281 5281 5281 5281 5281 5252 5242 5223 5213 5213 5213 5213 5204 5204 5204 5194 5184 5165 5155 5145 5136 -5659.92 4889 4886 ME/,,qURED B.P.( 5578 5568 5559 5548 5539 5525 5514 5503 5494 5480 5469 5458 5451 5441 5433 5420 5412 5410 5401 5390 5381 5376 5367 5364 5360 5355 5350 5542 5339 5327 5323 5319 5312 5306 5302 5296 5292 5286 5278 5272 5266 5260 5255 5251 5244 STP 1857 1843 1834 1823 1813 1800 1789 1778 1767 1752 1742 1731 1720 1712 1701 1694 1681 1674 1666 1660 1649 1625 1625 1625 1625 1625 1625 1622 1622 1593 1585 1579 1572 1566 1561 1555 1549 1541 1535 1532 1524 1517 1512 1507 1505 SCHLBRGR BHT 98.15 98.27 98.39 98.61 98.83 99.09 99.36 99.63 99.85 100 100 100 100 100 101 100 100 101 101 101 101 101 101 101 101 101 101 102 ' 102 102 102 102 102 102 103 103 103 103 103 103 104 104 104 104 104 ELAPSED TIME MINUTES SLURRY RATE bpm STAGE, TOTA.'( (bbl) SLURRY TOTAL (bbl) CALC. B .H.T.P (SV) (psig) lVlE~, ~URED ( STP 2 SCHLBRGR BHT ;28:29 0 ±:28:46 0 1:29:03 0 1:29:19 0 1:29:36 0 1:29:53 0 1:30:10 0 1:30:27 0 1:30:43 0 1:31:00 0 1:31:17 0 1:31:34 0 1:31:50 0 1:32:07 0 1:32:24 0 1:32:41 0 1:32:58 0 1:33:14 0 1:33:31 0 1:33:48 0 1:34:05 0 :34:22 0 .:34:39 0 1:34:56 0 1:35:12 0 1:35:30 0 1:35:46 0 1:36:03 0 1:36:19 0 1:36:36 0 1:46:10 0 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 148 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 987 4889 4879 4889 4879 4879 4879 4879 4879 4879 4879 4870 4860 4870 4841 4831 4831 4821 4811 4811 4811 4811 4811 4811 4802 4811 4802 4802 4802 4802 4802 4802 5242 5237 5232 5229 5224 5223 5212 5208 5206 5500 5199 5196 5195 5185 5184 5181 5177 5173 5172 5169 5165 5160 5157 5155 5150 5148 5147 5146 5143 5141 5139 1499 1494 1489 1484 1480 1476 1469 1464 1459 1451 1452 1450 1447 1442 1438 1429 1426 1428 1419 1420 1419 1414 1415 1407 1401 1403 1399 1398 1392 1390 1391 104 104 105 105 105 105 105 105 105 105 105 106 106 106 106 106 106 106 107 107 107 107 107 107 107 107 108 108 108 108 108 62" ne8 2~2i~9! iBP EXPIiORATI(iN PT. HC~ #9 FRAC BJ SERVICES FRAC STG ~ FLUIF iHOEH?O~¥ (bbI} (lbs) 11{163 FEOFF~HT TOTAL ,6 PPg 188 3 P?~ 28/48 ? PPG iG/2e 9 PPg 16128 11 PPg i~ PPG 16/2~ FLUSH Date: 2/21/91 BP-ALASKA Post Frac ~ort..~ Well No.: PT. MCINYRE 9 Zone: ' N Top Perf - MD: 13,646 Top Perf - TVD: 8,979 Bottom Tubing ID: 3.958 Bottom Tubing Depth - MD: 13,150 Petrodat - TVD: 0 Max Hole Angle: 56 Bottom Perf - MD: 13,860 Top Tubing ID: 3.958 Top Tubing Depth - MD: 13,150 Petrodat - MD: 0 Casing ID: 6.276 Angle @ Perfs: 36 Pump Rate: 35 ISIP:2,450 STAGE: MINI Acid Volume Gals: 5,000 Design Frac Height: 110 PPG: 8.50 Calculated Frac Grad: 0.715 Scale Inhib Volume Gals: 0 FLUID AND PROPPANT VOLUMES Pre Pad Fluid : 50# PrePad Design bbls : 50 Pad Volume Design : 357 X-Linked bbls Design : 809 Slurry Total Design bbls: 919 % Pad of Clean Design : 44.13 % Pad of Slurry : 38.85 Flush Required bbls: 217 Frac Fluid: UFRII-5 PrePad Pumped : 75 Pad Volume Pumped : 343 X-Linked bbls Pumped: 780 Slurry bbls Pumped : 894 % Pad of Clean Pump : 43.97 % Pad of Slurry Pump: 38.37 Flushed bbls : 8 Prop Concentrations: .6 100 MESH, 1,3,5,7 20/40 7,9,1,13 16/20 Proppant Type 1:100 MESH Amount Design: 3,000 Amount Pumped: 3,000 Proppant Type 2:20/40 COL Amount Design: 19,500 Amount Pumped: 19,500 Proppant Type 3:16/20 Amount Design: 81,500 Amount Pumped: 91,600 Total Design lbs: 25,500 Total Pumped: 114,100 Prop in Form : 33,000 Comments: RAN 100 MESH PROPPANT FOR HIEGHT GROWTH. SCREEN OUT WHEN 9 PPG STAGE WAS ON FORMATION. Fresh or Seawater(F or S): S Gel Viscosity @ Hyd Time: 45 Fluid Loss Add. Typel: FLC-41 Fluid Loss Add. Type2:FLC-8 Quality control Data Cross link Time: 2:30 Water Temp: 65 Gel Viscosity @ 10 min: 51 Concentration: 50 Stage End: PAD Concentration: 20 Stage End: PAD START AT: 0.1 Stage End: PAD Breaker Schedule SLF: 0.5 Stage End: 13 PPG Tail - in: 1 + CITRIC + GBW-10 Stage End: FLUSH Mini Frac Data Fluid: UFRII-5 Pump Rate: 35 Fluid Loss Cc: .00324 Percent Efficiceny: 38 Frac Hieght: 110 Closure Psi: 5600 Closure Time: 13.7 MiniFrac ISIP: 2250 Comments: BOB HANNAH ANAYLSIS DATA BP EXPLORATION PT. MCINTYRE #9 FRACTURE STIMULATION FEBRUARY 21, 1991 JOB DESCRIPTION: The PT. MCINTYRE #9 frac was designed to stimulate approximately 110 net feet of the formation. This job was mixed using our LFC/LAS unit which gels the fluid on the fly. The fluid used is a guar base gel using a delayed borate crosslinker. Seawater was used as the base fluid. The BJ Services nomenclature for this system is Ultra Frac RII 5. An acid job was performed on Feb.19. The data frac was delayed due to problems with Schlumberger's tool and the weather. The step rate test and data frac was performed on the evening of Feb.20 with a BHTP and BHT gauge in the hole. An ISIP of 2180 psi. was observed at the shutdown following the data frac. The job was redesigned by Bob Hannah and Monte Townsend utilizing 3000# of 100 mesh sand and 19,500# of 20/40 carbolite prior to pumping 84,500# of 16/20 carbolite. This was due to an unfavorable wellbore azimuth and observed frac height growth. The pump schedule for the job was as follows: STAGE DIRTY VOLUME ( BBLS ) ESTABLISH RATE 50 PAD 357 .6 PPG 100 MESH 122 1 PPG 20/40 75 3 PPG 20/40 40 5 PPG 20/40 29 7 PPG 20/40 31 7 PPG 16/20 31 9 PPG 16/20 50 11 PPG 16/20 71 13 PPG 16/20 112 FLUSH 217 Design Proppant Total = 19,500 lbs. 20-40 COL 84,500 lbs. 16-20 COL The job screened out 8 bbls. into the flush stage. The computer calculated a total of 116,000# of proppant pumped. It was calculated that 33,000 lbs. of proppant was pumped in formation, with approximately 83,000# remaining in the tubing.No surface problems were ovserved during the job. Paul Bartel, Bob Hannah, and Monte Townsend were the BP Exploration representatives monitoring the job. BP EXPLORATION WELL INFORMATION 02-15-1991 JOB TICKET # : DATE OF JOB : TREATING FLUID: PROPPANT TYPE : CUSTOMER : REPRESENATIVE : WELL NAME : FORMATION : PERMEABILITY : POROSITY : FRAC GRADIENT : RESERIVOR PRESSURE : NET HEIGHT : YOUNG'S MODULUS : PERFORATED INTERVAL: SIZE : NUMBER B.H.T.P. MEASURED BY : PRIMARY TREATING STRING : TREATING RATE : BJ SERVICES SERVICE SUPERVISOR : BJ SERVICES SERVICE LOCATION : BJ SERVICES ENGINEER : BJ SERVICES SALES OFFICE : 621998 2-21-91 ULTRA FRAC RII - 5 SEAWATER 16-20 CARBOLITE BP EXPLORATION PAUL BARTEL PT. MC. #9 FRAC IVISHAK XXXXXX 13646-13710:0.5: 384 T 35 BPM JR. TAFT NORTH SLOPE FRED BURT NORTH SLOPE BP EXPLORATION PT. MC. #9 FRAC TIC~T NO. 621998 DATE OF JOB 2-21-91 EVENT NUMBER ELAPSED TIME EVENT DESCRIPTION 0.01 EST. RATE 3.75 START PAD 13.90 START 100 MESH 17.50 START 1 PPG 20/40 19.75 START 3 PPG 20/40 21.00 START 5 PPG 20/40 21.50 START 7 PPG 20/40 22.60 START 7 PPG 16/20 23.70 START 9 PPG 16/20 10 25.00 START 11 PPG 16/20 11 27.20 START 13 PPG 16/20 12 30.00 START FLUSH 13 30.30 SCREENOUT JOB TICKET # 621998 DATE OF JOB : 2-21-91 CUSTOMER : BP EXPL( WELL : PT. MC~ FRAC BJ SERVICES FRAC F.A.C~T~S, ? P E 0 10~ 0 20~ 0 JOB TICKET # DATE OF JOB : 621998 CUSTOMER : BP EXPI 2-21-91 WELL : PT. MC. FMC BJ SERVICES FRAC A C A L JOB TICKET # 621998 DATE OF JOB : 2-21-91 CUSTOMER : BP EXPL~ WELL : PT. MC~ FRAC BJ SERVICES FP~C F.A.C.T.S. L F P C P ? JOB TICKET # DATE OF JOB : 621998 CUSTOMER : BP 2-21-91 WELL : PT. MC. #9 FRAC BJ SERVICES FRAC F.A.C.T.S~ P P P P ELAPSED TIME MINUTES 0:00 0:00 0:00 0:01 0:01 0:01 0:02 0:02 0:02 0:03 0:03 0:03 0:04 0:04 0:04 O:O5 0:05 0:05 0:06 0:06 :19 :38 :56 :15 :33 :52 :11 :30 :49 :08 :28 '47 . :06 :26 :46 '06 :25 '45 . '05 . :24 '06:44 ~:07:03 0:07:23 0:07:43 0:08:02 0:08 0:08 0:09 0:09 0:09 0:10 0:10 0:10 0:10 0:11 0:11 0:!! 0:12 0:12 0:12 :22 :41 :01 :21 :40 :O0 :19 :39 :58 :17 :37 :56 :15 :31 :49 0:13:06 :13:25 :13:45 ,~:!4:04 0:14:24 SLURRY LR.~.~_ bom 6.42 9.44 12.85 13.23 16.88 18.39 18.39 22.81 25.7 28.11 32.38 32.9 33.02 33.15 33.15 33.02 34.4 34.54 34.91 35.16 35.04 35.16 35.16 35.29 35.41 35.41 35.41 35.29 35.16 35.41 35.16 35.29 35.16 35.29 35.41 35.29 35.29 35.29 35.16 35.16 35.29 35.29 35.29 35.16 35.!6 SUP~W~. TREATI:W'G PRESSURE psi 1786 2786 3349 3485 3883 4048 4048 4572 4912 5135 5669 5631 5524 5495 5446 5446 5582 5572 5524 5427 5194 4970. 4815 4669 4563 4504 4543 4601 4611 4601 4592 4592 4592 4592 4592' 4592 4592 4601 4592 4592 4601 4592 4601 4601 4592 STAGE TOTAL (bbl) 1.17 3.93 7.66 11.75 16.5 22.29 28.04 34.59 42.26 51.18 61.07 71.69 7.18 18.07 28.83 39.76 50.79 62.16 73.42 84.85 96.37 107 119 130 142 154 165 177 188 200 211 222 234 245 257 268 279 291 300 311 321 332 343 11.37 ~z.77 SLURRY TOT~_L (bbZ) 1.17 3.93 7.66 11.75 16.5 22.29 28.04 34.59 42.26 51.18 61.07 71.69 82.43 93.32 104 115 126 137 148 160 171 183 194 206 217 229 240 252 263 275 286 298 309 321 332 343 355 366 376 386 396 407 419 430 441 TOTAL (lbs) 0 0 '0 0 6.29 6.29 6.29 6.29 128 483 SA~ND CONC (#/gal) SAND CCNC. 0 0 0 .46 .8 ELAPSED MINUTES 0:14:43 0:15:02 0:15:24 0:15:43 0:16:02 0:16:20 0:16:38 0:16:57 0:17.:16 0:17:35 0:17:53 0:18:12 0:18:31 0:18:50 0:19:08 0:19:27 0:19:46 0:20:05 0:20:24 0:20:43 :21:02 ~:21:21 0:21:40 0:21:59 0:22:18 0:22:38 0:22:57 0:23:16 0:23:36 0:23:55 0:24:15 0:24:34 0:24:54 0:25:14 0:25:33 0:25:53 0:26:12 0:26:32 0:26:51 0:27:10 0:27:30 ":27:49 :28:09 ~,:28:28 ~:28:47 o~URRY .RA~ b~m 35.16 35.16 35.04 35.04 34.79 34.91 34.79 34.79 34.91 34.91 34.91 34.79 34.79 34.91 34.91 34.79 34.79 34.91 34.91 35.16 34.79 35.41 35.04 34.91 34.91 34.79 34.91 34.4 33.9 33.77 33.65 33.77 33.27 33.52 33.15 33.27 33.4 33.27 33.15 33.15 33.15 32.77 32.52 33.27 33.4 SURF~" TREATING PRESSURE psi 4592 4592 4592 4582 4582 4582 4582 4582 4592 4592 4592 4582 4592 4592 4582 4592 4572 4514 4485 4436 4427 4349 4281 4242 4203 4145 4116 4038 3980 3970 3990 4038 4058 4116 4126 4194 4252 4320 4368 4417 4456 4456 4495 4514 4524 STAGE TOTAL (bbl) 34.02 45.44 58.31 69.11 80.38 90.49 101 112 123 7.34 18.3 29.32 40.38 51.46 61.75 72.75 3.66 14.8 25.74 36.74 7.34 18.46 29.57 11.16 22.31 3.72 15.05 26.25 3.62 14.55 25.51 36.44 47.38 7.32 18.17 .29.12 39.93 50.67 61.35 3.52 14.22 24.82 35.54 46.13 56.86 SLURRY TOTkL (bbl) 453 464 477 488 499 509 520 531 542 553 564 575 586 597 607 618 629 640 651 662 684 695 706 718 729 740 751 762 773 784 795 806 817 828 839 85O 86O 871 882 893 903 914 924 935 SANu TOTAL (lbs) 826 1159 1377 1652 2010 2383 2764 3099 3431 3772 4106 4526 5034 5558 6031 6550 7525 9286 11076 12849' 15165 17653 20500 23698 26956 30283 33587 36815 40200 43789 47269 50718 54496 58024 61651 65342 68966 72537 75983 79500 83304 87177 91063 94926 98823 SAND CONC (#/gal) 0 0 .15 .74 .74 .74 .5 .37 .74 .94 .89 .75 .75 .75 .74 .8 1.1 1.16 1.16 1.12 1.82 5.02 4.21 5.69 6.9 7.61 9.98 9.98 9.98 SAND CONC. .74 .64 .37 .74 .8 .85 .8 .8 .74 .74 .74 1.1 1.14 1.14 1.14 1.29 2.79 4.98 4.48 5.13 6.73 6.98 9.13 9.97 10.06 10.18 10.06 10.05 11.35 11.74 11.3 11.48 10.9 11.73 12.39 12.39 12.39 12.11 11.69 12.11 13.93 14.06 13.93 14.06 14.06 PPg EL~SED TIME MINUTES 0:29:05 0:29:24 0:29:43 0:30:02 0:30:21 0:30:40 0:30:58 0:31:16 0:31:34 0:31:52 0:32:09 0:32:27 0:32:45 0:33:03 0:33:21 0:33:39 RATE bom 33.77 29.62 34.15 34.4 2.39 TREATI~,I'G PRESSURE psi 4504 4553 4533 4815 6854 5980 5213 4679 4194 3854 3572 3339 3174 3029 2951 2873 STAGE TOTAL (bbl) 66.84 77.1 87.93 3.68 11.36 11.36 11.36 11.36 11.36 11.36 11.36 11.36 11.36 11.36 11.36 11.36 SLUP~RY (bbl) 945 955 966 977 985 985 985 985 985 985 985 985 985 985 985 985 SAND TOTAL (lbs) 102460 106000 108831 111305 112655 112655 112655 112655 112655 112655 112655 112655 112655 112655 112655 112655 3. SA~ND CONC (#/gal) 10.05 10.05 10.37 10.37 12.41 12.41 12.41 12.41 12.41 12.41 12.41 12.41 12.41 12.41 12.41 12.41 SAND CCNC. 14.06 11.69 7.82 7.28 3.58 3.65 3.43 2.75 2.36 2.03 1.95 1.66 1.89 1.8 1.85 1.8 PPg ORIGINAL CONFIDENTIAL UELL REPORT FOR BP EXPLORATION (ALASKA) INC. PT. MclNTYRE NO.9 AFE No.-71997S PT. McINTYRE FIELD NORTH SLOPE BOROUGH, ALASKA TELECO OILFIELD SERVICES JOB # 788 Submitted B~: 'Ron Gehree Rodneu St. Pierre Scott.Burkhart December 17, 1998 CONFIDENTIAL TABLE OF CONTENTS I. GENERAL WELL INFORMATION II. WELL SUMMARY III. DRILLING AND ENGINEERING IV. SURVEY LISTING V. BHA RECORD VI. CORRECTION FACTORS VII. TELECO SERVICES VIII. TELECO TOOL PERFORMANCE IX. APPENDICES I. GENERAL WELL INFORMATION COIIFIDENTIAL OIL COMPANY BP EXPLORATION (ALASKA) INC. P.O.' BOX 1866612 ANCHORAGE, ALASKA 88SIS-GG12 OIL COMPANY EVERETT POTTER REPRESENTATIVES JOHN SALARIO LOUIS BROWN WELL LOCATION PT. McINTYRE FIELD SURFACE LOCATION: S3S' SNL, 1048' WEL ................... BEC~-i4,"Ti2N'; Ri~E, UM ~ELL TYPE SPUD DATE DRILLING CONTRACTOR RIG NAME RIG EQUIPMENT TELECO SERVICES TELECO JOB NUMBER TELECO PERSONNEL DELINEATION S NOVEMBER 1888 ALASKA UNITED DRILLING AUDI NO.3 DIESEL ELECTRIC DIRECTIONAL SURVEYS GAMMA RAY RESISTIVITY SURFACE WEIGHT ON 8IT RATE OF PENETRATION OOWNHOLE TEMPERATURE 788 TAK RON GEHRES RO0 ST. PIERRE SCOTT BURKHAROT -1,- .... - .... ~ ...... ~ .~ ~ ........... - -- '--~. -T-~ -~ .'-w-...----..,mjb;.-.. --- ~.~- .. . _ _ CO FIDENTIAL II. WELL SUMMARY Teleco's measurement while drilling service was utilized on BP Exploration (Alaska) Inc.'s Pt. Mclntgre well ND.S, located in the Pt. Mclntgre field. Teleco was used to provide directional survegs, a real time gamma-rag and resistivitg log, and a preliminarg rig-site evaluation of the information obtained while Teleco equipment was in the hole. The gamma rag and resistivitg logs were used, through correlation, to identifw Iithologies encountered, to pick formation boundaries, coring points, and to select the 9 S/8" casing point. Teleco provided directional onlg service from surface to 3888 feet MO to successfullg kick off the well from vertical and to monitor the direCtion and inclination of the wellbore. RGb logging service commenced at 3888 feet MD and was used to ~ depth of 1288S feet, where a Dual Propagation Resistivitg logging tool was picked up and used to TO the 12 1/4" hole. After setting 9 5/8" casing, S 3/4" DPR logging tools were used to pick the coring point and to TD the hole.- Teleco's directional services were used to drill 3888 ft.-and accumulated S2 circulating hours. The 8 1/4 in. RGb tool was used to log 988~ ft. with 288 circulating hours. Teleco's 7 3/4" DPR tool logged ~3S feet in 39 circulating hours. The S 3/4" DPR tools logged 9S8 feet and accumulated 43.8 circulating hours. Combined, Teleco's tools had a total of 421.8 circulating hours from surface to 14375 feet TD. COi IFIDENTIAL III. DRILLING AND ENGINEERING RUNS No.l-3:492 ft. - 3888 ft., 17 1/2 in. HOLE TOOL NUMBER AND TYPE: ~882-42, 4X D-TF1 Teleco's directional onlg services were utilized in the 17 ~/2 inch hole section to assist in the kickoff of Pt. McIntgre well no. 9. Three runs were required to reach the 13 3/8 inch casing depth of 3888 ft. Runs one and two utilized a d~nadrill mud motor in association with a 2 1/2 degree kick sub. The second run was ended at a depth of 2137 ft.. where a building assemblg with a 12 1/4 inch undergauge stabilYzer was used to finish the 17 1/2 inch section of the hole. RUN No.4:3888 ft. - 412G ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37,_4X RGD-TF1 Teleco began logging services on November 11. 1998 when a 4X RGD (reeistivitg. gamma rag. directional) collar was placed in a slight building aesemblg to drill out of casing. Prior to this. Teleco had provided directional services throughout the 17 ~/2 inch section of the hole with a total of 3 trouble free runs. The fulcrum assembly was intended to hold angle out of the casing shoe. The inclination initiallg dropped at a rate of 8. S degrees per hundred feet. At a depth of 4126 ft., it became apparent that this assembl~ would continue to drop angle. The directional driller decided to come out of the hole and drop a stabilizer to get some of the inclination back. A total of 1126 feet were drilled during this run while the penetration rate averaged between 388 to 488 feet per hour. .. -. . _ . . · ... RUN No.'S= 4126 ft. - 4846 ft.. 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2207-37.---4X RGD-TF1 The assemblg utilized for run No.S (logging run No. 2) Was identical to run No.4 minus one stabilizer. The objective of this assemblg was to build angle slowlg to the desired S5.8 degrees. Starting inclination was 52.8 degrees with an azimuth of 13.8 degneee. A build rate of almost one degree per hundred was established indicating too much build. After drilling 528 feet it was again necessarg to pull out of the hole for a bottom -hole assemblg change. Ending angle and direction for run No.5 was 56.3 degrees and 14.1 degrees respectivelg. Penetration rates averaged 580 feet per hour as sand was drilled over most of the interval. RUN No.S: 4S46 ft. - 4~980 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGD-TF1 A packed rotary assembly was used for run No.G (log run No.3). At this point it was essential to hold or slightly drop angle to stag on target. Unfortunately, this assembly continued to build at a rate of degrees per hundred. After drilling 334 feet the inclination was S0.2 degrees and a trip was made for a bottom-hole assembly change. A steerable system would be picked up to help in maintaining the proper inclination. .,, FI DENTIAL RUN No.7:4980 ft. - S20~ ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGO-TF1 Run No.7 (log run No.4) consisted of a Baker one degree bent housing motor and an undergauge stabilizer in the-hope that this assembly could be controlled by weight. It was necessary to periodically orient Iowside to keep the angle from building, but the majority of the run was rotary drilled. The inclination and direction at the conclusion of this run were S~.2 and 17.2 degrees, respectively. A total of 122~ feet were drilled during this run. RUN No.8: 1~20~)'-733S', 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2207-37, 4X RGO-TF1 Run #8 (log run #S] was identical to the assembly previously used. Only the bit and a stabilizer blade -were replaced. This BHA generally dropped angle at the average rate of one degree per 188 feet, and it was necessary to orient highside on several occasions in order to keep the angle from dropping too fast. Weight on bit while rotating was 3~-40 KLBS, with ~0 RPMS. Pump pressure was 2288 PSI while running 118 SPM. ROPS while rotary drilling were good, averaging 188-288 ft. per hour over the course of the run. The run was ended at 733S feet, for a trip to change the BHA. The final survey prior to pulling out of the hole showed an inc!ination of S1.S degrees in the direction of N17.SE. RUN No.g: 7336 ft. - 8i20 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2207-37, 4X RGO-TFi Run No.S (log run No.6) utilized the same bottom- hole assemblg minus one stabilizer which created a 40 foot belly. This gave the assembly a tendency to 'maintain angle or build slightly, Penetration rates were high at the beginning of the run, averaging 100 to 208 feet per hour, and slowed to 38 to S8 feet per hour at the end of the run. Drilling parameters were kept similar to the previous run with a bit weight of 38-36 KLBS found to be best suited to produce the desired directional results. This BHA performed as expected and built slightly throughout the run. A tendency to turn to the right, made it necessary to make several sets during 'the run. A trip was made at 8138 feet as a worn bit was suspected, The final survey for the run was S3.5 degrees in a N21.1E direction. RUN No.18:.8128 ft. - 81S1 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGO-TF1 This run (log run no. 7) used the same assembly as the previous run and a new bit. After drilling only 34 feet, no more hole could be made while either rotating or orienting. No excessive torque ~as noted and it was suspected that the mud motor had malfunctioned. Whilsa trip for the mud motor was being contemplated, a severe electrical problem occurred which disabled most of the rig power. It thsn became necessary to come out of the hole in order to make repairs to the electrical system. No surveys were taken during this run due to the lack of rig power. RUN No. ll: 8151 ft. - 8546 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGD-TF1 Run No.ll utilized a rotary locked assembly in the hope that the ability to run increased weight on bit would help the rats of penetration. Since it had taken in excess of three days to repair the rig electrical system, it was decided to stage in the hole to get the mud in shape for drilling. After reaching bottom, a weight on bit of 68 to 78 KLBS. was run with 68 RPMS. The rate of penetration increased somewhat over the previous mud motor runs, averaging 45 lest per hour for · the run. A total of 355 feet was drilled with this assembly until it was decided to pull out of the hole for another mud motor assembly, as the angle was continuing to drop. The final survey, taken at 8462 ft. was 53.6 degrees with an azimuth of 17.~. C01, FIDENTIAL RUN No. 12:8546 ft..- 9878 ft,, 12 i/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGD-TF1 Run no.12 (log run no. $), uae a mud motor assemblw similar to BHA no. lB, uith the exception of leaving out the number one non-mag drill collar, in order to move the Teleco sensors closer to the bit. An insert bit uae used in the hope of stewing in the.hole for a longer period of time. This aesemblw had the tendencw to build angle, so some'orienting uae required to keep the inclination from building at too fast a rate. ROPS were irregular as numerous hard formation stringers uere encountered. Weight on bit while rotating was 2B-3B KLBS., uith a rotarw of 88-90 RPMS, After a good run of 45 circulating hours and 1332 feet, a drop in pump pressure indicated a possible uashout, and a trip uae made. The final survew at a depth of $SBB feet, before the trip, showed an_~.~c.!.!O~on_q~_~_degrees.and, a__ ........ direction of N13.BE. Run No. 13= 8878 ft. - llBB7 ft.,'12 1/4 in. HOLE TOOL NUMBER AND TYPE: 22B7-37, ~X ROB-TF1 Run No,13 (log run no. lB) consisted of the same BHA ae used previouelw with the exception of moving the non-mag stabilizer directlw belou Teleco to a position closer to the bit. A Reed long insert button bit with 3-1~'s and 1-18 for jets uae used. After reaching bottom, the pump pressure was still Iouer than it should have been. Several stands uere pulled and the uashout uae found in a joint of drill pipe near the surface. This aeeemblw tended to drop angle slightlw uhile rotating, resulting in the need to orient up on several occasions in order to keep the nose up. This BHA also made a good run of 1185 feet with an average ROP of 3~ feet per hour. Drilling parameters uere similar to that- of the previous run. The final survew, taken at 109SB ft. uae ~.5 degrees uith a direction of N2B.~E. COi' FIDENTIAL RUN No.l~: 11BB7 ft.- 1152B ft., 12 1/~ in, HOLE TOOL NUMBER AND TYPE: 22B7-37, ~X RGO-TF1 Run No.14 was drilled using the same assemblw as run No.12. A Smith F15CL insert bit uith 4-14's for jets uae used. This assemblg uae predicted to build slightl~ as drilling progressed. At this point a long mudstone section uae being drilled and the response of the BHA through this particular formation uae to drop angle sligh'tlg in the rotating mode. Because of this,-it was necesearg to orient up on several occasions. The average pump pressure for the run uae 2588 PSI while pumping at the rate of 112 SPM. ~eight on bit uae 38 KLBS., uith a rotar~ of 88-98 RPMS. At a depth of 11~28 feet, it uae decided to trip out of the hole to change the bit and test the BOPS. The final surveg for the run, at a depth of 11852 feet, uae 54.~ degrees of inclination in the direction of N28.SE. RUN No. 1S: 11520 ft. - 12282 ft., 12 1/4 in. HOLE ,uOL NUMBER AND TYPE: 2287-37, 4X RGD-TF1 -This aesembiy was similar in make up to t~at of BHA no. 13 with a longer fulcrum section in hopes of building angle without having to orient up as much. A new Baker i degree bent housing mud motor was run in along with a new Security long insert bit with 4-14's for jets. It soon became apparent, after several surveys were taken, that the angle was continuing to drop even while orienting up. Drilling parameters for the run were similar to those of the previous run. At a depth of 12262 ft., since the drop portion of the hole had not yet been reached, it was decided to pull out of the hole to pick up a locked up rotary assembl~ where more weight could be run. The last survey for this run was 63.2 degrees with an azimuth of 25.2 at a depth of 12196 ft. RUN No. i6:12262 ft. - 12686 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2207-37, 4X RGD-TFi Run no. 16 (log run no. 13) was a locked up rotarg assembl~ with two undergauge near bit stabilizers and one 12 1/8" undergauge below the MWD, designed to drop angle slightly, down to the drop off point of the hole. A Smith SOGH tooth bit with 4-10's, was run in for use with this BHA. After reaching bottom, a weight on bit ranging between 66 and 65 KLBS was run with a rotar~ of 90-110 RPMS. The pump pressure with the 4-18's at 118 strokes per minute, was 3888 PSI. Drilling rates continued slow, averaging 18 to 26 feet per hour. The angle during this run'dropped slowly, while the direction began turning to the right, possibly due to the lack of control with undergauge nearbits. At 12686 ft., a trip was necessitated by a dull bit. The last surve~ before this trip was 48.S degrees and N32.7E at a depth of 12681 ft. Run No.17:12686 ft. - 12885 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 2287-37, 4X RGD-TF1 For this run, with approximately 888 feet left to the 9 5/8!' casing point, it was decided to make a tool run, in order to line the hole up directionall~ for the final drop to the casing point. A slick assembly with a Oynadrill mud motor and a two degree kick sub was used. ~ ~m~h_.~W.~+h hL+_~h_.~--!~'_=-~ J~-~-~a~ ,, ~.,11 ~11 ~11 ~1, ~, ~ ~l ~.1 i ~ ~ ,~l ~ & ~ this uae expected to be a short correction run. Higher flow rates were used to drill this section ranging from 128 to 135 GPM, giving a pump pressure in the range of 3188 PSI. The run was ended after 199 feet during which time a set of 78 to 88 left had been generallg maintained. The final surveg, taken at 12784 ft., showed that the hole had turned to a-N31.7E with an angle of 4~.8 degrees. CO FIDENTIAL RUN No.18: 1288S ft. - 13001 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE: 17SB-54, 4X DPR-TF3 The bottom-hole assembly used for this run uae a slight pendulum rotary aesemblg. Incorporated in this run was a Smith F1C insert bit with 3-10's and a 12 for jets. Teleco collar No.I?GG-S4, a OPR ( Oual Propagation Resistivity) tool was picked up at this time to aid the geologist in picking casing point. A drop rate of 1.4 degrees per hundred feet was needed to reach the casing point at the desired inclination. Orilling progressed at an average rate of 20 feet per hour to a depth of 13001 feet at which time a survey was taken. This survey indicated that the assembly would not drop at the intended rate and a trip was made to make the necessary bottom-hole assembly change. The final survey, taken at 12957 ft., revealed an inclination of 45.1 degrees with a-direction of N30. GE. RUN No.19:13081 ft. - 13268 ft., 12 1/4 in. HOLE TOOL NUMBER ANO TYPE: 1755-S4, 4X DPR-TF3 Bit No.18 was rerun .in the pendulum assembly for run No.19. This assembly was expected to drop the necessary 1.~ degrees per hundred feet and to reach the casing point. Penetration rates averaged 28 feet per hour through this interval as this assembly dropped approximately three degrees per hundred feet. Drilling continued to a depth of 13258 ft. where a trip was made for a bottom-hole assembly change because of.the rapid angle drop. The final survey showed an inclination of 38.1 degrees with a direction of N32.4E. RUN .No.2g= 132G8 ft. - 13420 ft., 12 1/4 in. HOLE TOOL NUMBER AND TYPE= 1765-56, 4X DPR-TF3 The final run of the 12 1/4" hole before the ~ 7/8" casing point (logging run no.17) utilized a stabilizer and a lead collar below Teleco to reduce the rate of drop. A Hughes CJG3 mill tooth bit with 4-11's for jets ~ae run as only a short distance was expected for this run. and a tooth bit should be sufficient to drill to casing point. The rate of penetration for the run averaged 35 feet per hour ~hile running 50KLSS weight on bit and 129 rotary. The run was ended when a drilling increase, along with a slight ramping increase in the gamma trace, indicated that casing should be set at this point. The final survey, taken at a depth of 13358 feet ~0, indicated an inclination of 35.6 degrees in the direction of N3~.SE. CO FIDENTIAL RUN No.21:13420 ft. - 13446 ft., 8 1/2 in. HOLE TOOL NUMBER ANO TYPE: 2S3S-06, 4X OPR-TF3 A packed rotarw assemblw was used to drill out of $ 6/8 inch casing. A Reed HP13GJ mill tooth bit with 3- ll's for jets was run along with a 6 3/4 inch Teleco tool. After drilling out of casing, testing the shoe, and circulating a Bland mud swstem around, drilling resumed with the intention of reaching the first core point. However, after drilling onlw 2B feet the bit balled up and the.rate of penetration came to a virtual ,standstill. Rather than risk possible further damage to the bit, a trip was made at this time. RUN No,22: 1344B ft. - 13644 ft., 8 1/2 in. HOLE TOOL NUMBER ANO TYPE: 2535-BB, 4X OPR-TF3 The very same assembly was~run in the hole for run No.22. A Hughes J2 mill tooth with 3-13's for jets was the bit chosen for this run. Penetration rates for this run averaged between 30 and 60 feet per hour. Severe decoding problems were encountered during this run which made it necessary to ream for real-time data. Thi's problem is believed to be associated with torque and h~draulics of the bland mud sgstem which creates erroneous pressure pulses that interfere with the signal. The rig-site geologists picked 13~44 ft, as a core point based on our log and'the examination of -- drilled cuttings. Ct) - FIDENTIAL RUN No.23:13544 ft. - 13643 ft., 8 1/2 in. HOLE TOOL NUMBER AND TYPE: 2635-86, 4X DPR-TF3 After a core run was made the sams bottom-hole assemblg was used along with a Smith Fl5 button bit. The cored interval was reamed for a log and an additional ~0 ft. were drilled before the geologists halted drilling and circulated bottoms up, Based on the real-time log and circulated samples a trip was made for a core run. After some initial decoding problems the torque subsided and decoding improved to 1~0 percent. One surveg was taken at 1355Z ft. and indicated an inclination of 36.5 degrees with a direction of N33.SE, RUN N~.24:13843 ft. - 13843-ft., 8 1/2 in. HOLE TOOL NUMBER AND TYPE: 1819-38, 4X DPR-TF3 This run utilized the same aeeembl~ and bit ae run No.23 and was intended to be used to ream log through the cored interval. Teleco collar No.1819-38 was picked up because the rseistivit~ values of collar No.2636-88 were suspect. Unfortunately, this collar transmitted incorrect resistivit~ values and would have to be replaced. RUN No.2S: 13643 ft. - 14184 ft., 8 1/2 in. HOLE TOOL NUMBER AND TYPE: 1887-33, 4X OPR-TF3 A new Teleco BPR logging tool was picked up and run with the same assembl~ and bit for this run. The hole was reamed from the shoe to bottom, in order to collect a log through the cored intervals. The ROP for this reaming interval was kept under 158 feet per hour to obtain sufficient bed resolution for a real time log. After reaching bottom, the ROP averaged close to feet per hour in the upper section of the run, slowing to 25-38 near the run's end. Weight on bit was 38-48 KLBS with a pump pressure of 2288 PSI. At a depth of _.~84 feet, a trip was made to change the bit. The inclination was building throughout the run with a final survey, taken at 14145 feet, showing an angle of degrees in the direction of N32.7E. RUN No.28:14184 ft. - 14375 ft., 8 1/2 in. HOLE TOOL NUMBER AND TYPE: 1587-33, 4X DPR-TF3 A Reed HP5! button bit with 3-13's for jets was run in the same bottom-hole aeeembl~ to drill to TD. The ROP averaged 28 feet per hour with a bit weight of 38 kibe and 78 RPM's. A total depth of 14375 ft. was chosen to allow wireline tools below the zone of interest. A surve~ taken after drilling was stopped showed an inclination of 42.9 degrees with a direction of N30.2E. u ,FIDENTIAL CO .,IFIDENTJAL VIII. TELECO TOOL PERFORMANCE TOOL RUN 10 TOOL TYPE/# D-TF1/1882-42 IN HOLE OUT OF HOLE TIME/DATE TIME/DATE CIRC. HOURS (,) MUD DEPTH DEPTH RUN/TOTAL MOTOR 1899/11-5 2666/11-6 21.9/21.9 YES 492' 1478' D-TF1/1882-42 2300/11-6 1108/11-7 $.8/38.8 YES 1478' 2137' D-TF1/1882-42 1288/11-7' 2388/11-8 22.8/52.8 NO 2137' 3888' RGD-TF1/2287-37 0081/11-11 1700/11-11 12.0/12.0 NO 3088' 412~' RGD-TF1/2207-37 2138/11-11 8838/11-12 4.5/1S.S NO 4128' 4648' RGD-TF1/2287-37 0930/11-12 2200/11-12 S.5/22.0 NO 4646' 4980' RGD-TF1/2207-37 8881/11-13 8130/11-14 17.8/39.8 YES 4988' 6289' RGD-TFl/2287-37 RGD-TF1/2207-37 9266/11-14 6338/11-15 19.8/58.9 YES 6299' 7335' 0430)~'-~5---'0738-)1--i~-6' ...... -'~9.5/77.5 YES 7335' 8128' RGD-TF1/2287-37 0808/11-16 8200/11-17 2.5/88.0 YES 8128' 8151' Circulating hours does not include trip time or other non- pumping time. It is used to determine the Mean Time Between Tool Failures (MTBFF) of the tool in a drilling environment according to IADC conventions. ,:o.~ ~ '- . ~,., 2 ~' ~, '...~, q~ ~- ?-" .. ,- ,,- ~3"~ "%/ ~,' " ~ ._ -'.' ,. ~ ~...? . (].':. ~.' ... .. . ¥: .... ,. . . - .... .' . ...... ..:.; ......... :. ... -. . .., . . . TOOL RUN 11 12 13 14 19 17 18 19 28 VIII. TELECO TOOL PERFORMANCE (cont'd) COI FIDENTIAL TOOL TYPE/# RGD-TF1/2207-37 RGD-TF1/2207-37 IN HOLE OUT OF HOLE TIME/DATE TIME/DATE CIRC. HOURS (,) MUD DEPTH DEPTH RUN/TOTAL MOTOR 8188/11-28 2488/11-28 11.8/91.8 NO 8191' 8S46'' 8488/11-21 1838/11-23 46.0/136.0 YES 8546' 8878' RGD-TF1/2207-37 1488/11-23. 1888/11-25 38.8/174.8 YES $878', 11867' RGD-TF1/2207-37 1900/11-29 8438/11-28 43.S/217.S YES 11867' 11928' RGD-TF1/2207-37 1888/11-28 2188/11-29 29.0/239.S YES 11920' 12262' RGD-TF1/2207-37 2388/11-29 1008/12-01 22.S/262.0 NO 12262' 12688' RGD-TF1/2207-37 1138/12-81 1338/12-82 16.8/288.8 YES 12886' 1288S' DPR-TF3/1788-SB 1580/12-82 8888/12-83 B.B/B.O ND 12885' 13881' OPR-TF3/1766-56 8938/12-83 1438/12-84 i9.8/25.0 NO 13881' 13268' DPR-TF3/1768-56 1538/12-84 1838/12-85 14.8/39.8 NO 13288' 13428' (,). Circulating hours does not include trip time or other non- pumping time. It is used to determine the Mean Time Between Tool Failures (MTBFF) of the tool in a drilling environment according to IADC conventions. u, iFIDEHTIAL VIII. TELECO TOOL PERFORMANCE (cont'd) TOOL RUN 21 22 23 24 2B TOOL TYPE/#. OPR-TF3/2S3S-OG DPR-TF3/2S3S-88 DPR-TF3/2S3S-08 DPR-TF3/1818-38 -- -OFR-TF3/15B7~33 DPR-TF3/1S87-33 IN HOLE OUT OF HOLE TIME/OATE TIME/DATE OEPTH DEPTH 8881/12-87 8788/12-89 13428' '13448' 8888/12-89 2330/12-08 13448' 13S44' 8188/12-11 1888/12-11 13844' 13843' 1430/12-13 8800/12-14 13843' 13843' 13843' 14184' 1338/12-18 2288/12-16 14184' 14378' CIRC. HouRs (,) MUD RUN/TOTAL MOTOR 3.8/3.8 NO S.0/8.0 NO 3.S/11.S NO 3.8/3.8 NO 18.0/28.0 NO BIT RUN SUMMARY TOTAL TOTAL TOTAL TOTAL BIT RUNS MOTOR RUNS CIRC. HRS. FAILURES 28 11 -,new pages 418.8 1 MTBFF 418.8 VII. TELECO SERVICES TOTAL TOTAL FOOTAGE FOOTAGE LOGGED DRILLED 11378 13883 SURFACE SYSTEMS MWD TOOLS - TYPE (,) 4X DTF1 4X RGD-TFi 4X DPR-TF3 4X DPR-TF3 4X DPR-TF3 4X OPR-TF3 TR23BB-039: M-SERIES: DOWNHOLE MEMORY: DIRECTIONAL-GAMMA RESISTIVITY. 1.31M SOFTWARE 2.31 SOFTWARE DATA TRANSMISSION SIZE S/N 4X MILLER CODE 81/4" 1889-42 4X MILLER CODE 8 1/4" 2287-37 4X MILLER CODE 7 3/4" 17DB-SD 4X MILLER CODE B 3/4" 2S3S-B8 4X MILLER CODE B 3/4" 1B19-38 4X MILLER CODE 8 3/4" 1B07-33 CO,- FIDENTIAL DOI4NHOLE MEASURED PARAMETERS - DIRECTIONAL= INCLINATION, AZIMUTH TOOL FACE ORIENTATION GAMMA= NATURAL GAMMA RADIATION RESISTIVITY: 16" SHORT NORMAL n,,^, ....... ~1 I~ i i ~1 ~ ~ ! i · ~1 · TEMPERATURE: DOWNHOLE CIRCULATING SURFACE MEASUREMENTS - KELLY HEIGHT ROP (RATE OF PENETRATION) WOB (WEIGHT ON BIT) STANDPIPE PRESSURE (~) Explanation of Tool Types . D-TF1 : Teleco Tool Family 1 -- Directional Only RGD-TFI: Teleco Tool Family 1 -- 16" Short Normal Resistivity Natural Gamma Ray Detection (Geiger Mueller) Directional Downhole Temperature RGD-TF3: Teleco Tool Family 3 -- Dual Propagation Resistivity Natural Gamma Ray Detection (Scintillation) Downhole Memory Directional Dounhole Temperature . .. .- APPENDIX A: ~WD LOG INTERPRETATION CO FIDENTfAL This section briefly discusses some of the factors which directly or indirectly affect the formation measurements made Teleco and the interpretation of the log. Rate of Penetration versus Bed Resolution The vertical bed resolution presented in an real time log is directlg related to the rate of penetration. As the rate of penetration increases, the dlstance between formational measurements also .... i. ncreases, thereb~ decreas!eg .the bed_resolutionz Oue to the statistical fluctuation inherent in the measurement of gamma-rag radiation, more data points are naturally desired per depth interval to accuratelg represent the true formation characteristics. ~WO Resistivity Interpretation Although Teleco's resistivity sensor is physically similar to a 1S" short normal, the actual measurements 'acquired compare favorablg with the deep-reading induction tools. This is due to the short time which transpires between the drilling and the measurement of a particular formation. Invasion of the formation bg the mud fi'ltrate is'considered to be negligible. However, if a considerable amount of time transpires between the drilling and the logging of a formation, Teleco's resistivity measurements may be prone to the invasional--affects of the mud filtrate. Correction Factors for Resistivity The factors which affect the accuracg of wireline logs also affect the resistivities obtained bg Teleco. However, due to the differences associated with the method of measurement, the resistivitg log produced bg Teleco is corrected in a slightlg different fashion (refer to the Teleco Correction Chartbook). The factors which affect a formation resistivity measurements are~ 1. The mud resistivity 2. The annular temperature 3. The "standoff" or amount of annular volume (i.e. hole size vs. tool size) The Teleco tool transmits the temperature of the internal circuitry. These temperatures were used to calculate the resistivity of the mud under downhole conditions. The mud 'resietivitg and corresponding temperature -- were monitored at the surface and projected to bottom hole temperature using Hilchie's equation (a '- modification bf Arp'~-~q~ati'on)-;--Teleco has developed a series of correction charts which utilizes the projected downhole mud resistivity, the measured formation resistivity, and the tool and hole sizes to determine a corrected formation resistivity. This data was compiled bg Teleco and is presented in in the header information of our final logs. AOGCC GEOLOGICAL MATERIALS iNqlENTORY LIST PEi:UdiT a ?o - /r./a WELL NAME .A~/#~ /~Z. ~e ~ ~ COMP~TiON DA~ /j ! ~ I ~ a CO. CONTACT ~ check off or list data as it is received%list received date for 407. if not reauired list as NR * I drlllinq histow i ~ well tests core descri cored intewa core ditch intewals ital data ~o..o,., ,,,oo,~ t oo, I r 151 , .. 3z- AOGCC blI-ULUL'~Ib/~L MATERIALSl~w-r~ ............. ! uHY LiST PERMIT# i LOG TYPE RUN INTERVALS SCALE NO. {to the nearest foot,1 [inchl100'J 191 i 28} ~q ' 4ol ' 41) I I I I BP EXPLORATION January 17, 1991 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 I COMM '~ COMM I COMM __ ._~__ RES ENG .,~"~i~ SR ENG .... SR ENG ENG "ASST . '~-'~-~'~T' j ' ?,:'.' ~EOL~ GEOL ASST[ STAT TECHl I L. C. Smith Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Exploration Fluids from Pt. Mclntyre #9 Well (**Revision**) Dear Mr. Smith' BP Exploration (Alaska), Inc. (BP) is the operator for the Pt. Mclntyre #9 exploration well, which has a bottom hole location within ADL 365548. BP hereby notifies the Alaska Oil and Gas Conservation Commission that in the event that the production tests, if any, from Pt. Mclntyre #9 yield hydrocarbon liquids, BP may reinject such fluids into the nearby Pt. Mclntyre #6 well, or take such fluids either to the Western Operating Area Gathering Center (GC1) or to Flow Station #1 (FS1) to be commingled with Prudhoe Bay production. In the event such fluids are taken to GC1 or FS1, BP, as lessee for ADL 365548, intends to retain ownership of the fluids. In the event hydrocarbons are not reinjected into Pt. Mclntyre #6 and are taken to GC1 or FS1 for processing, BP, as exploration operator on ADL 365548 and 100% working interest owner in Pt. Mclntyre #9, assumes responsibility for paying all royalty, tax and/or other assessments on produced oil from Pt. Mclntyre #9 exploration tests in 1991. Production rates will be measured using meters on separators during testing, and hydrocarbon volumes will be strapped in tanks. Production measurements will be made in accordance with AOGCC regulations 20 AAC 25.228 and 25.230. Metered volumes of the exploration test fluids will be reported by letter to the DOG and AOGCC after production tests are completed. RECEIVED JAN 1 ? t991 Alaska Oil & Gas Cons. commisSiOn ;Anchorage L. C. Smith January 17, 1991 Page Two Exploration volumes processed at FS1 or GC1 will be reported separately from other PBU production. BP will notify the AOGCC prior to testing Pt. Mclntyre #9. If an AOGCC representative wishes to witness the test, BP requests that the representative obtain polar bear and environmental/cultural training from BP. A Beaufort Sea Environmental/Cultural Card and "polar bear stamp" are provided to persons who watch two videos at BP. Please contact Mark Fraker at (907) 564-5527 for further information about environmental training. Please indicate your approval below and return a copy of this letter to the undersigned. If your have any further questions feel free to contact myself at (907) 564-5989 or B. E. Stepanek at (907) 564-5511. Sincerely, BP Exploration (Alaska), Inc. T. J. Obeney cc. D. Platt, Department of Revenue APPROVED THIS / '? day of ALASKA OIL AND GAS CONSERVATION COMMISSION L. C. tS~ith ,1990. RECEIVED Alaska 0ii & Gas Cons. Oommissiot~ Anchorage BP Exploration (Alaska) Inr,. RECEIVED r~C o 61990 & Gas Cons. Commission Anchorage TO: THRU: MEMORAK..dM St ,[e of Alaska ALASKA OIL AND GAS. CONSERVATION COMMISSION Lonnie C. Sm ~ Commissioner/ ~ DATE: November 26, 1990 FILE NO: JT. DA. 1126.6 TELEPHONE NO: SUBJECT: BOP Test BPX Pt. McIntyre #9 Permit No. 90-140 Prudhoe Oil Pool FROM: Doug Amos Petroleum Inspector Saturday Nov. ~7_x_1990: I traveled this date from Conoco's MPU to BPX P~ Mclnt~Tr-e- ~-~ w~-fl--~o stand by for their weekly BOP test at AUDI Rig No. 3. The test could not be conducted this date because of an electrical fire in the SCR unit. The fire was caused by an improperly installed 600 volt line from the generators to the SCR unit. The rig was without power and all but one boiler for heat from 1:30 p.m. until 4:30 p.m. at which time power from one generator restored power and some heat. The hole was circulated and remained in good. condition until full power and heat was restored 5:00 p.m. 11/19/90. MondaI Nov. 19~_1990: I traveled this date from ConOco's MPU back to AUDI Rig No. 3 to witness the BOP test. The testing commenced at 9:30 p.m. and was concluded at 11:30 p.m. The mud room cellar and shaker room gas detectors failed the test. Ail other equipment passed. An AOGCC BOPE inspection report is attached.. In summary: after repairs were made to the rigs SCR unit caused by a fire resulting from an improperly installed 600 volt li_~!ie, ! witnessed~ the BOPE test at BPX Pt. Mcintyre No. 9 well on AUDI Rig No. 3. 02-001A (Rev. 6/89) 20/11/MEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report OPERATION: Drlg / Operator ~1~ ~ Wkvr Wel 1 sign Rig Location: Sec · grlg contrctr Location (general) Housekeeping (general) Reserve pit V Rig// MUD SYSTEMS: Visual Audio Trip tank '~ I ~/' .. / V/ I F1 ow monitor ~// I BOPE STACK: Test Pressure Annular preventer~/j Pipe rams Blind rams Choke line valves~'~.. HCR valve :~. ~,..~ ..~ Il Kill line valves~ Check valve TEST RESULTS: DATE NOL/. /~---~ ? /~ J TEST: Initial Weekly J Other Representative ~-~/~ .Sd J~ ~ J ~ P~ ~ q~-I 4 0 l~/S" ~ c~s~.g ~ ~ Zq~O ~ Rep ~J, ACCUMULATOR SYSTEM Full charge pressure Press after closure ft psig psig Pump incr clos press 200 psig min '~(~ sec Full charge press attained ~.~ min ~;~ sec Controls: Master Remo e L/ ........ KELLY AND FLOOR SAFETY VALVES: /~0~ ~'~ Test pressure u~-~ Lower Kelly ~k~l , Test pressure Ball type ~)f/t 'Test pressure Inside BOP :~'I Test pressure Choke manifold I v~" Test pressure Number valves Number flanges, Adjustable chokes Hyd[aulically operated choke Failures ~ Test time "~'~ hrs Repair or replacement of failed equipment to be made within I days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) WITNESS TO: THRU: MEMORAK'_JM S,"',e of Alaska ALASKA OIL AND GAS CONSERVATION COI~YiISSION / / Lonnie C. Smi.~ DATE: November 13 1990 Commi s s ioner .~ ' FILE NO: JT. LG. 1113.6 TELEPHONE NO: SUBJECT: BOP Test BPX Pt. Mclntyre #9 AUDI rig #3 FROM: Louis Grimaldi ~ Petroleum Inspector November 10~ 1990: I performed a RIG BOPE inspection on AUDI #3 ~illing fo'~ BPX 'Pt. Mclntyre #9 and found no discrepancies other than the BOP remote station was disconnected and mud pump gas detector was malfunctioned. I also did a BOPE test and all tested good with the exception of the lower kelly cock which was completely washed out. The hands could not find a replacement although they assured me that they would have one within two days. In summary: The driller and toolpusher appeared to do a conscientious BOP test but the rig has some electrical problems. I.E. The BOP remote station had a burnt wiring harness and the gas detector was inop. Everett Cooper (BPX rep) assured me that these problems would be rectified as soon as possible. *Note the BOP remote station was repaired, before drilling out of shoe as per telecon w/ Everett Potter 11-11-90 0530 hrs. Attachment 02-00lA (Rev. 6/89) 20/11fMEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMHISSION BOPE Inspection Report OPERATION: Drlg ~/ Wkvr Operator ~>?X Loca[ton: Sec /~, T~ R../~ H~ Location (general) ~ Housekeeping (general) /~ Reserve pi b ~" Well sign______.__ Rtg. /// MUD SYSTEHS: Trip tank Pit gauge Flow monitor Gas detectors V~]~ Audio Choke line valves HCR valve KIll ltne valves Check valve BOPE STACK: Test Pressure Annular preventer _ Pipe rams .,..,.(~ BItnd rams ~_.. Rig# , TEST: Intttal~/~ Weekiy~ Other Representative ~/~' ~. ~?~ ~'~-T--- Permit Casing Rep ,~ : ~ ACCUNULATOR SYSTEH: Full charge pressure ~- Press after closure //'"~"'~C~ Pump tncr clos press 200 psig Full charge press attained ,:~'? ,~',.", ,,=;~.-p s t g.,, Con[rols~ Has,er Remo[e ~ Bltnd swt~ch cover KELLY AND FLOOR SAFETY VALVES= mln-~O mtn Upper Kelly , Lower Kelly Ball type Inside BOP Choke manifold Number valves Number flanges Test pressure Test pressure Test pressure Test pressure Test pressure, Adjus. table chokes ~.~ Hydraulically operated choke pstg pstg sec sec TEST RESULTS: Failures ~ Test time_ ~ hfs .'~. Repatr or replacement of failed equipment to be made wlthtn ~'~days. Notify the Inspector, and follow with wrtbten/FAXed verification to Commission office, Remarks: '~'~'- .~'~ ~"~p ' :'"~ ..... ' . ~ ~ ~ ,: ...>:... ~. ~"~ b~'~,:': ~, <t ............ ~,:,- Distribution: orlg - AOGCC c - Operator c - Supervisor C,OOq (rev 05/10/90) TO: THRU: FROM: MEMORANDUM Sta [e of Alaska ALASKA OIL A~ND GAS CONSERVATION COMMISSION Lonnie C. Sm~/ DATE: November 7, 1990 Commissioner I ' FILE NO: JT.HH.117.4 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection BPX Pt McIntyre No. 9 Sec 14, T12N, R14E Permit No. 90-140 Pt. McIntyre Harold R. Hawkins Petroleum Inspector .Saturday November 3, 1990: Louis Grimaidi and I went to BPX Pt. }:lcI.qtyre to inspect the diverter on AUDI Rig 3. The diverter was not ready to inspect. Everett Potter called us too soon so we performed a RIG/BOPE Inspection and found no problems with BOPE' s. In summary: The RIG/BOPE inspection was performed satisfactorily on AUDI Rig 3 for BPX Pt. McIntyre No. 9. 02-00lA (P~v. 6/89) 20/11/MEMO1.PM3 TO: THRU: FROM: ,, MEMORAh;JM of Alaska ALASKA OIL AND GAS CONSERVATION CO~®'~ISSION Lot, hie C. Smi~:~,''' Commi s s ioner ../~ DATE: FILE NO: Novemb..,r 7, 1990 ~, l .HH.~. 117 3 TELEPHONE NO: SUBJECT: Diverter Ir~,spection BPX Pt. t~,~.c..ntyre Sec 14, T12N, R14E Permit No. 90-140 Pt. ~,~c ,_ntvre HaroId R. Hawkins Petroleum Inspector~' Sunday November 4, 1990: Louis Grimaldi and I inspected the diverter system an-~ '-~~~~formed with AOGCC regulations on AUDI rig 3 at BPX Pt. Mclntyre although we could not witness the test because there was an electrical problem with the rig. In sunmaary: The diverter on AUDI Rig 3 was nippled up correctly. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 November ~ 1990 Telecopy: (907)276-7542 Mr. Paul Chan Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 995]_9-6612 Re: Pt McIntyre ~9 Revised BP Exploration (Alaska) Inc. Permit No. 90-140 Sur Loc 535'FNL, 1048'F~ Sec 14 T12N R14E UM Btmhole Loc 1737'FNL, 1118' Sec 02 T12N R14E UM Dear Mr. Chan: Enclosed is the approved revised application for permit to drill the above referenced well. The provisions of the cover letter dated October 24, 1990, accompanying the original approved permit are in effect for this revision. Since , David W. Johnston Commissione~ ............... Alaska Oil and Gas Conservation Comission BY ORDER OF T}{E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 November 1, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn' Mr. Lonnie C. Smith ,Pt. Mclntyre #9 BP Exploration submits a revised form 10-401, our application for Permit to Drill the above named well. Also, enclosed are the attachments listed on the application form. This well is anticipated to spud approximately Nov. 4, 1990. If there are any questions, please do not hesitate to call Paul Chan at 564-4226. Drilling Engineer RECEIVED ( REVISION #2 · , STATE OF ALASKA . NOVEMBER 1, 1990 ALASKA OIL AND GAS CONSERVAIION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ¢~,~-"7'-~ ~pl.-/~ ~ la. Type of work Drill [] Redrill lb. Type of well.'Exploratory [] Stratigraphic Test [] Development Oil ILL Re-Entry [] Deepen Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=42 feet Pt. Mclntyre 3. Address 6. Property Designation P. 0. Box 196612, Anchora.qe, Alaska 99519-6612 ADL 365548 4. Location of well at surface 7. Unit or property Name 11. Type Bond(s~ 2o AAC 2S.02S) 535' FNL, 1048' FWL, SEC. 14, T12N, R14E . :. Pt. Mclntyre At top of produ,~,c~e interval ~,",,.-:~- '~:: ,..,,.r,~ 8. Well number Number , 2067' FNL, 1228' FILL, SEC. 02, T12N, R14E /;.,, ..,,:.:' .~.v, ( Pt. Mc/nh/re #9 2S100302630-277 At total depth ,E' 9. Approximate spud date Amount 1737' FNL, 1118' ~, SEC. 02, T12N, R14E November4, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (UDandmVD) prop line ,,,:.~ l. b' 34622 ~ ~.t.~8' feet Pt. Mclntyre #6/35' @ surf. feet 3601 14174'MD/9400'TVDfeet 16. To be completed for deviated wells 17/ Anticipated pressure (see 2o ^^c 25.oa5 (e)(2)) Kickoff depth 500' feet Maximum hole an~le 55 o Maximum surface 3650 psig At total depth (TVD)9400'/4575 psig 18. Casing program Setting Depth raze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD' TVD MD TVD (include stage data) 26" 20" 133# K-55 Butt 80' Surface 120' 120' 180 cuft Coldset I 17-1/2" 13-3/8" 68# ~~,~ Butt 2965' Surface 3005' 2700' 4200 cuft Coldset II 12-1/4" 9-5/8" 47# NT80S NSCC 13485' Surface 13527' 8912' 2966cu ft Class G 8-1/2" 7" 29# L-80 TLC 897 13277' 8712' 14174' 9442' 320 cuft Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate Production Liner ¢i~ ' ' · Perforation depth: measured ~~.~..~,~ true vertical 20. Attachrnents Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program l'~l Drilling fluid pr~ [] Time,,vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21. I hereby c~if~6)t/~t~oregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Drilling Engineer Date///~/,~[¢ /' - Commission Use Or~ly ' Permit Number _ IAPI number IApproval date See cover letter .~C~ -',/'~-//,,"~ J5 0- 4:~z-~ - Z~.-4:::) x4~'' J 10 / 2 4 / 9 0 for other requirements Conditions of approval Samples required [] Yes ,~. No Mud Icg required [] Yer%S ,,,~.~'No .... Hydrogen sulfide measures [] Yes ~_ No Directional survey required ~ Yes I'~g Required working pressure for BOPE [] 2M; FI3M; /lJi~5M; []10M; []15M; Other: ~ ~ ~~~ .... by order of Approve ~._ ,,., -.... ... _. ...... Commissioner the commission Submit in triplicate PROPOSED DRILLIN(~ PROGRAM Pt MclNTYRE #9 Ob_iective Pt Mclntyre #9 will be drilled from Dockhead #3 of the West Dock causeway to further delineate the Pt Mclntyre prospect to the North. In the event that the well encounters sufficient hydrocarbons, it will be completed with the rig as a future producer. O.oeration$ Install & cement 20", 133# K-55 Buttress conductor from 80' BGL to surface. If necessary, one joint of 30", 157.5# pipe will be installed to support surface gravel. Install rig, camp and other support facilities on location. Nipple 20" diverter system and function test same. 1990. Vertically drill 17 1/2" hole to 500 ft TVD. Kick off and :"~"~"~aOit , directionally drill to surface casing point at 2700 ft TVD. run and cement 13 3/8" 68# NT-80CYHE Buttress casing to surface. Nipple down diverter system. Install and test 13 5/8"x 5000 psi blowout preventer stack consisting of two sets of pipe rams, one set of blind rams and one annular preventer. Estimated maximum BHP is 4575 psi at 9400ft TVD ss. Maximum possible surface pressure is 3650 psi assuming a full gas column to surface. Pressure test 13 3/8" casing. Drill out casing and 5ft of new hole and perform a leak off test. Directionally drill 12 1/4" hole to the intermediate casing point at approximately 8870ft TVD. No abnormal pressures are expected in the 12 1/4" hole section. Run open hole logs. Run and cement 9 5/8" 47# NT-80S NSCC casing to surface and cement same up to approx 3400ft MD. Test BOPE. Pressure test casing. Drill out casing and 5' of new hole and perform a formation leak off test. Drill and core 8 1/2" hole to TD. Intervals to be cored will be picked by the wellsite geologist. Run open hole logs. Run and cement 7" 29# L-80 Buttress liner from TD to approximately 250ft inside the 9 - 5/8" casing.Clean out liner to the float collar. Test casing and lap to 3000psi. Change well over to NaCI brine. Run CBT/CET/GR in 7" liner and a multi-shot gyroscopic survey from PBTD to surface. A cased hole VSP will also be run. Complete the well with production tubing and a 9 5/8" production packer. Nipple down BOPE. Install production tree on wellhead and test to 5000psi. Freeze protect the 9 5/8"x 13 3/8" annulus to 3000ft'. Release rig. If hydrocarbons are encountered, the well will be flow tested with surface testing equipment after the rig has been moved off location. At the conclusion of testing, a sub-surface safety valve will be installed below the base of the permafrost and the well suspended. Fluids associated with the drilling and completion of the well will be injected down the 9 5/8"x 13 3/8" annulus. CRM 10/1/90. Pt. MclNTYRE ~/9 .PROPOSED WELL DIA(~RAM NON-FREEZING FLUID TVD CBKBI MD (BKBI 20' CONDUCTOR 120 FT 120 FT KOP ( DIR: N 18.4° E; ANGLE: 55 DEG ) 500 FT "' BASE PERMAFROST 1802 FT 1851FT SSSV 2040 FT 2150 FT · , 13-3/8' 68~/FT NT-80CYHE BTC 2700 FT 3005 FT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3300 FT " TOP OF 9-5/8" CEMENT (ESTIMATED) 4053 FT ~ 4-1/2", 12.6~FT L-80 TDS TUBING W/GLM's AND 4-1/~ TAILPIPE ASSEMBLY BEGINNING OF DROP TO 35° 7973FT 12192 FT 4-1/2" "X" NIPPLE 9-5/8" PACKER 8672 FT 13227 FT 7" LINER TOP 8712 FT 13277 FT 9-5/8" 47#/FT NT-80S NSCC 8912FT 13527 FT · PLUG BACK TD 14094 FT 7" 29#/FT L-80 BUTT LINER 9442 FT 14174 FT CRM/PC/10.17.90 ,SURFACE HOLE DIVERTER SYSTEM Two lines venting 90 deg. apad in directions that ensure safe down wind venting, and ex- tending to a point at least 100' trom any potential source of ignition. 0" Full Opening Valves 43' '-35' or, as required ' ...._1 Dresser Sleeve 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 10" Diveder Line 2. Manual 10" full opening valves mechanically connected to ensure that one valve is fail-safe open at all times. 3. All turns are 90 deg. and targeted. 10" Full opening ball valve wi Hydraulic Actuator Cellar 20" Diverter Spool wi 10" Side Outlet M EM 113190 BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM STACK DRILLING RISER I - I ANNULAR PREVENTER I 2" KILL LINE MANUAL HYDRAULIC GATE GATE PIPE RAMS I BLIND RAMS i DRILLING SPOOL I PIPE RAMS 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE Pt. MclNTYRE #9 DIRECTIONAL DIAGRAM DEPARTURE TO BHL: 9859 FT 14174 FT MD 9442 FT TVD BKB DEPARTURE TO TARGET: 9511 FT 13567 FT MD 8945 FT TVD BKB TRUE NORTH GRID N 18° 22' E SURFACE LOCATION: X = 681,298 FT; Y = 5,998,042FT; ASP 4 535FT SNL; 1048 FT EWL SEC 14, T12N, R14E NOTE: THE CLOSEST WELL TO PT. MclNTYRE #9 IS PT. MclNTYRE #6 LOCATED 35 FT NORTHWEST AT THE SURFACE. CRM/PC/10-29-90~-- 0 1 2 POINT MCINTYRE NO, 9 C ISLAND I ! I LAT. - 70'23'59.55' LONG. (MIL[S) 148'31'27.79' ~) ~MP ISLAN y ,= 5,998,042 A.S.P. D X- 681,298 ZONE 535' FROM NORTH UNE GWYDYR BAY ~ 1,048' FROM WEST UNE POINT STORKERSEN '~ K PAl3 1" = 5280' [C£1VED ~as Consi BP-051 SURVEYOR'S CERTIFICATE I hereby certify that I am properly m registered and licensed to practice ~ land surveying In the State of Alaska. and that this plat represents a survey made by me or under my supervision, and that all dimensions and other details are correct. Date OCT. 12, 1990 LS No. 7535 " Registered Land~urveyor POINT MCINTYRE No.9 AS STAKED WELL .NUMBER 9 LOCATED IN PROTRACTED SECTION 14, TOWNSHIP 12 NORTH, RANGE 14 EAST, UMIAT MEREDIAN, ALASKA B.P. EXPLORATION P.O. BOX 196612 ANCHORAGE, ALASKA gg519-6612 SUR'VLmfI~D BY.' ARCTIC SLOPE CONSULTING GROUP 6700 ARCTIC SPUR ROAD ANCHORAGE. ALASKA 99518 ~earc,~ Radius= 2CO :-' DEGREE ;_.--A3 Li~-~_-- F~r pr~=c, sed ?~ei;' Fr':'~ [4'~- 2-!2-~~-] , ..... YVO SF:.S ~:.:at i:.,, = '-'-E S-N .aE' 298._, 0O 39980', 4-2..~ ~ .... The mell ~ich comes closest to the proposed ~eil is: · --hT-_.l'o~e~t ~pp~o-~=n dr~'t:'~nu~ ~ 34. ~IC~ OFF ~or this run = ~00.0 ~eet - ~ Date: ~9--CCT-~O Time O -'--"~: .~ Note' --AO29-Z200000 PMC-06 489.0 O ~ 3=. f ~=3.0 =0=.3 ~j=~. 916.2 ~JZO. i ~7~' i 7g!:.~ ~76J.= SUMMARY Th~ ~ell which comes closest t~ the proposed well is' Cio-e-t= = approach distanc~ = ..~.. :==t, _. '--.'-~,'l"t.,~ .~..-r ;~,., ,-,,i= : U,, - "--~--~-== ALASKA UNITED RIG NO. 3 MUD SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desilter) 1- Tri-Fio Horizontal Vacuum Atmospheric Mud Degasser 1- 200 gpm Operating Capacity Centrifuge -- 1 9- Brandt MA5 Mud Mix Agitators 1- 125 bbl. Trip Tank 1- Recording drilling fluid pit level indicator with, both visual and audio warning devices at driller's console 1- Drilling fluid flow sensor with readout at driller's console I- Cavium Dewatering screen assembly ,Pt, Mq:INTYRE #[} MUD PROGRAM Interval 0-3,005' 3,005'- 13,527' 13,527'- 14,174' Mud Weight (PPg) Viscosity Fluid Loss (sec/qt) (ml/30min) pl-I Mud Type/ Components 8.8-9.8 100-200 20-15 8.5-9.0 Generic Mud #5 9.2-10.5 Set 13-3/8" casing 40-60 8-16 8.0-10.0 Set 9-5/8" casing 40-60 8'-16 8.0-11.0 Set 7" Liner 9.2-10.5 Fresh water Gel Soda Ash Barite Generic Mud #7 Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PttPA Polymer Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PHPA Polymer Calcium Carbonate Sodium Chloride RIG 3 MUD SYSTEM J i ALASKA UNITED DRILLING INC. RIG 3 MUD SYSTEM If~Lt I~O BP EXPLORATION October 31, 1990 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6~1~.:'..~ .- , (907) 561-5111 {'i' ., Mr. Lonnie Smith, Acting Chariman and Commissioner Alaska Oil and Gas Conservation Commission 300a Porcupine Ave. Anchorage, AK 99501-3192 Oil and Gas Lease ADL 34624 Desianation of Ooerator for Pt. Mclntvre #90oerations Dear Commissioner Smith' Transmitted herewith are the required Designation of Operator forms which allow BP Exploration to conduct operations for the drilling of delineation well from a surface location on ARCO/Exxon oil and gas lease ADL 34624. Please direct any questions you may have regarding this matter to the undersigned at our letterhead address or at 564-4841. Sincerely, Stu Hirsh, Senior Landman i' STATEOFALASKA (~M i ALASKA OIL AND GAS CONSERVATION C MISS ON DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner Exxon Corporation 2. Address P.O. Box 2180 Houston, TX 77252-2180 3. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: ADL 34624 Legal description of property: West Dock #3 T12N, R14E UM Sec. 14 NW 1/4 For operations associated with the drilling and operation of the Pt. Mclntyre #9 well Property Plat Attached ["'l 4. Name of Designated Operator Address BP Exploration (Alaska) Inc P.O. Box 196612 Anchorage, AK 99519-6622 RECEIVED 5. Effective date designation October 1, 1990 Gas Gens. 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obligations is hereby acknowledged Signed ' Title ~1-, ~'~v~LoP~.5' ~O&~ Date 7. The own~¥ certifies that the foregoing is true and correct Signed Form 10-411, 12-1-85 Title Date Submit in Duplicate STATE OF ALASKA A ;SKAOI LAND GAS CONSERVATION C ,MISSION DESIGNATION OF OPERATOR 20 AAC 25.020 1. Name of Owner ARCO Alaska, Inc. 2. Address P.O. Box 100360, Anchorage, AK 99510-0360 3. Notice is hereby given of a designation of operatorship for the oil and gas property described below: Property designation: ADL34624 Legal description of property: West Dock #3 T12N, R14E UM Sec. 14 NW 1/4 For operations associated with the drilling and operation of the Pt. Mclntyre ¢~3 well Property Plat Attached r"] 4. Name of Designated Operator Address BP Exploration (Alaska) Inc P.O. Box 196612 Anchorage, AK 99519-6622 · , 5. Effective date designation October 1, 1990 6. Acceptance of operatorship for the above described property with all attendant responsibilities and obligations is hereby acknowledged Signed · Title ~/~, Vice President 7. The owner~beffe"b-~ertifies that the foregoing is true and correct Signe~~~' ~ '(_~~ .... Form 10-~'1'1, 12-1-85 Submit in Duplicate BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 October 29, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attn: Mr. Lonnie C. Smith Pt. Mclnt; i e #9 .) BP Exploration has recentl~ regis~d the bo~t0.m hole location for Pt. Mclntyre #9. Enclosed is ~ revis~form 10-~01, our application for P'e.~[~,~it to Drill the above n~med well~ Also, enclosed are the attachments · '~ , , '! , ~ ' , , hste~ .~.he apphcat~on fo!~. This ~ell ~s anticipated to spud approxirri~ ~y Nov. 7, 199q: - - -"~ If there are any prease do not hesitate to call Paul Chan at 564-4226. rs very trul Ln Drilling Engineer RECEIVED OCT 5 0 1990 Alaska 0il & Gas Cons. (;0mmiss'toa Anchorage t" STATE OF ALASKA ," ,~ REVISED PERMIT ALASKA OIL AND GAS CONSERVAIION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-illb. Type of well. Ex'l~l~.i~3~-~r-I Stratigraphic TestF'l Development Oil[] Re-Entry [] DeepenDI Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Pt. Mclntyre 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365548 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 535' FNL, 1048' FWL, SEC. 14, T12N, R14E PT. Mclntyre At top of productive interval 8. Well number Number 1590' FNL, 3344' FWL, SEC. 02, T12N, R14E Pt. Mclntyre ,9 2S100302630-277 At total depth 9. Approximate spud date Amount 1234' FNL, 3420' FWL, SEC. 02, T12N, R14E November 7, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth(uDandTVD) prop~L line 34622 ~ 1118' feet Pt. Mclntyre #6/35' @ surf. feet 3601 14405'MD/9400'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500' feet Maximum hole an~lle 56 o aaxlrnum surface 3650 ,,¢~l~l~X~t'~!TVD)9400'/4575 psl~l 18. Casing program Settin Dep .... Specifications ' ... g ~ '"% .... · op '.~' I&p, ttom Quanti:t'~.~of cement Hole ,, Casing Weight Grade Coupling Length M D TVD M D %i. TVD (include s~ge data) 26 20" 133, K-55 Butt 80' Surface 120',I~120'180 cuff Coldset~~, 17-1/2" 13-3/8" 68, ~rs, c,,E Butt 2965' Surfac~e 3005 ~00' 2700 cu fl Cold~t ll 13527' 8f~' 12-1/4" 9-5/8" 47, NT80S NSCC 13485' Surfac~ ~. 8-1/2" 7" 29, ~..~o TKC 917 13257 86~_~6._' 14174' 9442' 320 c.p~t'Class G 19. To be completed for Redrill, Re-entry, andr'~'Deep~'~"~'Operations.'~'%,~ ' ............ Present well condition summary '~"'~",',,, "'""', Total depth: measured ~i feet'!t, Plugs (measured) true vertical :"-:,;. feet Effective depth: measured :"!, feet ~i Junk (measured) ~:~ feet ~i~ --t~e--~tical '~, ~" Casing Len~ SiZ'9 /Cemented Measured depth True Vertical depth Structural..~, Conductor Surface Intermediate !,RECEIVED ProdU'~ion Liner% t;T __~,ri~nth: measured / 0C ~ 0 1990 Perforation x,,, true vertical ~,!~.~,0il,& Gas Cons. 20: .Attach. ments Filing, fee [] /'Property plat [] BOP Sketch [] Di~r:~er Ske~iral~illing program [] Drllhng fluid pro~lram~[]~q::.iFle..v§depth pict [] Refraction analysis [] Seabed re~'[~)-AAC 25.050 requirementsr'l 21. I hereby('~er~ ,~hat ti'Je f'bregoing is true and correct to the best of my knowledge Signed ~'~~ J,~~ Title Senior Drillin.qEn,qinoor Date // Commission Use Only ' "- ' 'Permit Numl~,br IAPI numberIApproval dateISee cover letter 15o- IIfor other requirements Conditions of approval Samples required [] Yes ,~No Mud Icg requi[ed []Yes ~No ' Hydrogen sulfide measures [] Yes -~i~ No Directional survey required ~ Yes [] ~ Required working pressure for BOPIE [] 2M; 1-13M; F15M; I-I10M; I-I15M; Other: by order of Approved by Commissioner me commission Date 10-401 Rev. 12-1-85 Submit in triplicate Pt. McINTYRF #9 PROPOSED WELL DIAGRAM NON-FREEZING FLUID TVD (BKB) MD (BKB) 20' CONDUCTOR 120 FT 120 FT KOP(DIR:N 18.4' E; ANGLE:55DEG) 500FT BASE PERMAFROST 1802 FT 1851FT SSSV 2040 FT 2150 FT 13-3/8" 68~/FT NT-8OCYHE BTC 2700 FT 3005 FT -.. BOTTOM OF FREEZE PROTECTION (ES?iMATED) 3300 FT ' ~. TOP OF 9-5/8" CEMENT ~ (ESTIMATED) '~g053 FT ......... 4-1/~12,6 /FT L-8OTDSTUBING ......... W/ GLM'~AND 4-1/2" TAILPI PE ASSEMBLY BEGINNING OF DROP TO 35' 7973 FT 12192 FT 4-1/2" "X" NIPPLE g-5/8" PACKER 7" LINER TOP 8672 FT 13227 FT 8696 FT 13257 FT 9-5/8" 47~/FT NT-80S NSCC 7" PACKER PLUG BACK TD 7" 2g~/FT L-80 BUTT LINER 8912 FT 13527 FT RE( EIV£D OCT 5 0 1990 Alaska Oil & Gas Cons. commission Anchorase 14094 FT 9442 FT 14174 FT CRM/PC/1 O- 17-90 PROPOSED DRILLING PROGRAM RECEIVED Pt M¢INTYRE #9 0C'[' 50 ~90~0 O b j e c t i v ~ Alaska 0ii & Gas Cons. Pt McIntyre #9 will be drilled from Dockhead #3 of the West Dock causeway to further delineate the Pt Mclntyre prospect to the North. In the event that the well encounters sufficient hydrocarbons, it will be completed with the rig as a future producer. Operations · Install & cement 20", 133# K-55 Buttress conductor from 80' BGL to -, surface. If necessary, one joint of 30", 157.5# pipe will be installed to support SB.rface gravel. Install rig, cam'p:, and other support facilities on location. Nipple up 20" diverter system and function test same. Vertically drill 17 1/2" hole to 500 ft TVD. Kick off and directionally drill to sbEface casing point at 2700 ft TVD. run and cement 13 3/8" 68# NT~0.CYHE Buttress casing to surface. Nipple down diverter system~.. Install and test 13 5/8"x 5000 psi blowout preventer stack consisting of two sets of pipe rams, one set of blind rams and one annular"~p.[eventer, Estimated maximum BHP is 4575 psi at 9400ft TVD ss. Maximum possible surface pressure is 3650 psi assuming a full gas column to surface. Pressure test 13 3/8" casing. Drill out casing and 5ft 'Of new hole and. perform a leak off test. ~. ,. Directionally drill 12 1/4" hole to the int~.rmediate casing point at approximately 8870ft TVD. No abnormal pressures are expected in the 12 1/4" hole section. Run open hole logs. Run and cement 9 5/8" 47# NT-80S NSCC casing to surface and cement same up to approx 3400ft MD. Test BOPE. Pressure test casing. Drill out casing and 5' of new hole and perform a formation leak off test. Drill and core 8 1/2" hole to TD. Intervals to be cored will be picked by the wellsite geologist. Run open hole logs. Run and cement 7" 29# L-80 Buttress liner from TD to approximately 250ft inside the 9 - 5/8" casing.Clean out liner to the float collar. Test casing and lap to 3000psi. Change well over to NaCI brine. Run CBT/CET/GR in 7" liner and a multi-shot gyroscopic survey from PBTD to surface. A cased hole VSP will also be run. Complete the well with production tubing and a 9 5/8" production packer. Nipple down BOPE. Install production tree on wellhead and test to 5000psi. Freeze protect the 9 5/8"x 13 3/8" annulus to 3000ft. Release rig. If hydrocarbons are encountered, the well will be flow tested with surface testing equipment after the rig has been moved off location. At the conclusion of testing, a sub-surface safety valve will be installed below the base of the permafrost and the well suspended. Fluids associated with the drilling and completion of the well will be injected down the 9 5/8"x 13 3/8" annulus. CRM 10/1/90. R EIVED OCT ,~ 0 1990 Alaska Oil & Gas L;ons. ~,,,..mission Anchorage SURFACE HOLE DIVERTER SYSTEM Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' from any potential soume of ignition. 10" Full Opening Valves REi EIVED OCT 0 1990 Alaska Oil & Gas Cons. Commission ; cho e 43' 35' or as required Dresser Sleeve 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 10" Diverter Line 2. Manual 10" full opening valves mechanically connected to ensure that one valve is fail-safe open at all times. 3. All turns are 90 deg. and targeted. 10" Full opening ball valve w/Hydraulic Actuator Cellar 20" Diverter Spool w/10" Side Outlet M EM 1/3/90 BOP STACK CONFIGURATION 13 5/8", 5000 PS! WP TRIPLE RAM ST ACK DRILLING RISER ANNULAR PREVENTER PI PE RAMS I I BLIND RAMS I REEEIV OCT ~ 0 199( Alaska 011 & Gas Cons. u~ 7~lchorage 2" KILL LINE MANUAL HYDRAULIC GATE GATE DRILLING SPOOL 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE I I P l PE RAMS I D ,, Pt. MclNTYRE ~ DIRECTIONAL DIAGRAM DEPARTURE TO BHL: 9859 FT 14174 FT MD 9442 FT TVD BKB DEPARTURE TO TARGET: 9511 FT 13567 FT MD 8945 FT TVD BKB TRUE NORTH GRID N 18° 22'E SURFACE LOCATION: X = 681,298 FT; Y = 5,998,042FT; ASP 4 535FT SNL; 1048 FT EWL SEC 14, T12N, R14E OCT ~) 0 1990 Alaska 011 & ~s Cons. Anchorage NOTE: THE CLOSEST WELL TO PT. MclNTYRE ~3 IS PT. MclNTYRE #6 LOCATED 35 FT NORTHWEST AT THE SURFACE. CRM/PC/10-29-90~-- 0 1 2 ,~o ~SLANO (M~LES) RECEIVED GWYD~ BAY "~ OC;T ~5 0 1990 · 'RSE. N "~'~' )~lja, i:)il a 6as Cons. Comil:ITL' ~~. POINT STORKE:RSF_.N POINT MClNTYRE NO. 9 I.AT. '- 70°25'59.55' LONG. -- 148';31 '27.79' Y = 5,998,042 A.S.P. X = 681,298 ZONE 4. 535' FROM NORTH UNE 1,048' FROM WEST LINE SURVEYOR'S CERTIFICATE I hereby certify that I am properly registered and licensed to practice land surveying In the State of Alaska, and that this plat represents a survey mode by me or under my supervision, and that all dimensions and other details are correct. Date OCT. 1,2, 1990 LS No. 7335 '~/ Registered Land~7~Urveyor 1' -- 5280' POINT MCINTYRE No.9 AS STAKED WELL NUMBER 9 LOCATED IN PROTRACTED SECTION 14, TOWNSHIP 12 NORTH, RANGE 14. EAST, UMIAT MERE'DIAN, ALASKA B.P.' EXPLORATION P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 SUR~:'YED BY: ARCTIC SLOPE CONSULTING GROUP 6700 ARCTIC SPUR ROAD ANCHORAGE:. ALASKA 99518 O~N BY: KMC 10/12/90 See,'ch .Redids= 20.2. 7 DEGREE LEAD For' p'r-opose'J well: PM'-Y No-~e: Ail depbhs 'in -?~et Se!ow ~.eilg ,-Bushing Closest Ap p~'o-~c h TVD DEPART TVD DEF AR ] PMC-06 489.0 O. 0 489.0 0.7 m.:,D 34. 5 Vertical -.in tensc, c t i on OEP AR = 7',.: C .~:: EP ,c.,R '7 SUMMARY The well ~hich comes closest to the proposed ~ell is' -A0~200000 PMC-06 --C-~-osest approach distance KICK OFF ~or this run 500.0 ~eet _~4~DUA i 24: [ O~;~Ar4035] PM':?_C LOSAP _SH~3P.. T. L I S.: ~ Dmte: 2~-i-~CT-?O Time' ©m' 2-4' .5.2 Sear-ch Rsdius= 200 COURSE MiNE Location = W-E S-N ?,:n~ coo)..~ ._,, ._.._.,. Top 681298. O0 5~°,80a. 2. O0 -~i. 50 ,~. · ~ Not~- Ail d~pths in ~'t ~,io~ ;<e3.1~j ~u~h~n9 (S~,E) Closest TVD DEPART TVO DEF ---A029=2200000 PMC-O8 4-89. 0 O. 0 889. 0 0 7 SUMMARY ,~ uC"SEs'r o l ST~'JC .-'E Ve~tic.al · Fh~r_~f-'C-2~.-~g'c- ......... .,;-'=' AP~v ....." :'VD 7.:EF AR T T',.' F_. ~-~ E? Ar-,', - 34. 5 ~5~3.0 ~0~ 3 ~ . 5320.1 3333. 7 ¢16. 2 740.8 7Oli. Z 4783. 5 The ~el! ~hich comes closest to the'proposed ~eli is: A029-2200000 PPiC-06 Cl~sest approach di_~tancs = _ ,.~-:, OFF ~or thi'~ to,, - ALASKA UNITED RIG NO. 3 MUD SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desiiter) 1- Tri-FIo Horizontal Vacuum Atmospheric Mud Degasser 1- 200 gPm Operating Capacity Centrifuge -- 19- Brandt MA5 Mud Mix Agitators 1- 125 bbl. Trip Tank - 1- Recording drilling fluid pit level indicator with. both visual and audio warning devices at driller's console 1- Drilling fluid flow sensor with readout at driller's console 1- Cavium Dewatering screen assembly 0CT ~ 0 1990 Alaska Oil &,Gas Cons. Commission Anchorage Pt. McINTYRE #9 MUD PROGRAM Interval Mud Weight (~ - - -- Viscosity Fluid Loss (sec/qt) (ml/30min) oH 0-3,005' 8.8-9.8 100-200 3,005'- 13,527' 13,527'- 14,174' 20-15 8.5-9.0 Set 13-3/8" casing 9.2-10.5 40-60 8-16 8.0-10.0 Set 9-5/8" casing 9.2-10.5 40-60 8-16 8.0-11.0 RE( EIVED OCT ~ 0 1990 Alaslm.Oil & Gas Cons. Commission Anchorage Set 7" Liner Mud Type/ Components Generic Mud 4/5 Fresh water Gel Soda Ash Barite Generic Mud #7 Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PHPA Polymer Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PHPA Polymer Calcium Carbonate Sodium Chloride MUD RIG 3 MUD SYSTEM HOtp~I / 05 ALASKA UNITED DRILLING INC. RIG 3 MUD SYSTEM OclDber 1987 Cm. CI~ID October 24, 1990 Telecopy: (907)276-7542 C. R. Maskell Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Pt McIntvre ~9 BP Exploration (Alaska) Inc. Permit No. 90-140 Sur. Loc. 535'FbIL, 1048'FIFL, Sec. 14, T12N, R14E, UM Btmhole Loc. 1234'FNL, 3420'FWL, Sec. 02, T12N, R14E, UM Dear Mr. Maskell: Enclosed is the approved application, for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling oper.ations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely David W. John .ton Commissione~ ........ * Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~..~ISSION dlf Eno lo sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i " STATE OF ALASKA ~ ALASKA O L AND GAS CONSERVATION COM ISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redr,ll Ollb. Type of well. 'E'x'~,o~;[;;~ [] Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenFI[ Service [] Development Gas [] SingleZone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration BKB=56 feet Pt. Mclntyre !3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 365548 .4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 A^c 25.025) 535' FNL, 1048'FWL, SEC. 14, T12N, R14E PT. Mclntyre At top of productive interval 8. Well number Number 1590' FNL,' 3344' FWL, SEC. 02, T12N, R14E Pt. Mclntyre #9 2S100302630-277 At total depth 9. Approximate spud date Amount 1234' FNL, 3420' FWL, SEC. 02, T12N, R14E November 1, 1990 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(M0ar~mVD) p rop%t/~L line 34622 ~ 3420 feet Pt. Mclntyre #6/35' @ surf. feet 3601 14405'MD/9400'TVDfeet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 Mc 25.o35 (e)(2)) Kickoff depth 500' feet Maximum hole an~ile 56 o Maximum surface 3650 pslg At total depth (TVD)9400Y4575 psl~l 18. Casing program Setting Depth raze Specifications _ Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 26" 20" 133# K-55 Butt 80' Surface 120' 120' 180 cuft Coldset I 17-1/2" 13-3/8" 68# ~r~,cy,~ Butt 2965' Surface 3005' 2700' 4200 cuft Coldset II .... 12-1/4" 9-5/8" 47# NT80S NSCC 13718' Surface 13758' 8870' 3030 cu ft Class G 8-1/2" 7" 29# ' ~.'~o TKC 897 13508 8712' 14405' 9442' 320 cu ft Class G , i9. To be Completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth' measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor S u rface IntermediateRECEIVED Production LinerOCT ! 91990 Perforation depth: measured true vertical ~l~0il& 6as Cons. · ~'0. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Dril,l~lC~J!~am [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements[] 21.1 hereby certif,~at~.,, .....,-/ - ~the fore~l~Clng is true/and correct to the best of my knowledge ,...... / / ~_.,v~,/¢'~.,,~/~ ~. Title Senior Drillin,q Engineer Date,/¢'~///¢O I Signed Commission Use Only :Permit Number IAPI number IApprovai date See cover letter ~o-'/~'~ 150-O,~ ?--- ~ Zo '~' J 10/24/90 for other requirements Conditions of approval Samples required [] Yes J~No Mud Icg required []Yes J~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required "~ Yes [] No Required working pressure for BOPE 1-12M; 1-13M; /~5M; I-I10M; []15M; Other: ~ ~Appro. v_ed. -- Commissioner the commission Date ~°rm 10-401 Rev. Submit in Objective PROPOSED DRILLING PROGRAM ,Pt M~INTYRE #9 .RECEIVED Pt Mclntyre #9 will be drilled from Dockhead #3 of the West Dock causeway to further delineate the Pt Mclntyre prospect to the North. In the event that the well encounters sufficient hydrocarbons, it will be completed with the rig as a future producer. Operations Install & cement 20", 133# K-55 Buttress conductor from 80' BGL to surface. If necessary, one joint of 30", 157.5# pipe will be installed to support surface gravel. Install rig, camp and other support facilities on location. Nipple up 20" diverter system and function test same. Vertically drill 17 1/2" hole to 500 ft TVD. Kick off and directionally drill to surface casing point at 2700 ft TVD. run and cement 13 3/8" 68# NT-80CYHE Buttress casing to surface. Nipple down diverter system. Install and test 13 5/8"x 5000 psi blowout preventer stack consisting of two sets of pipe rams, one set of blind rams and one annular preventer. Estimated maximum BHP is 4575 psi at 9400ft TVD ss. Maximum possible surface pressure is 3650 psi assuming a full gas column to surface. Pressure test 13 3/8" casing. Drill out casing and 5ft of new hole and perform a leak off test. Directionally drill 12 1/4" hole to the intermediate casing point at approximately 8870ft TVD. No abnormal preSsures are expected in the 12 1/4" hole section. Run open hole logs. Run and cement 9 5/8" 47# NT-80S NSCC casing to surface and cement same up to approx 3400ft MD. Test BOPE. Pressure test casing. Drill out casing and 5' of new hole and perform a formation leak off test. Drill and core 8 1/2" hole to TD. Intervals to be cored will be picked by the wellsite geologist. Run open hole logs. Run and cement 7" 29# L-80 Buttress liner from TD to approximately 250ft inside the 9 - 5/8" casing.Clean out liner to the float collar. Test casing and lap to 3000psi. Change well over to NaCI brine. Run CBT/CET/GR in 7" liner and a multi-shot gyroscopic survey from PBTD to surface. A cased hole VSP will also be run. Complete the well with production tubing and a 9 5/8" production packer. Nipple down BOPE. Install production tree on wellhead and test to 5000psi. Freeze protect the 9 5/8"x 13 3/8" annulus to 3000ft. Release rig. If hydrocarbons are encountered, the well will be flow tested with surface testing equipment after the rig has been moved off location. At the conclusion of testing, a sub-surface safety valve will be installed below the base of the permafrost and the well suspended. Fluids associated with the drilling and completion of the well will be injected down the 9 5/8"x 13 3/8" annulus. CRM 10/1/90. Pt. McINTYRE #9 PROPOSED WELL DIAGRAM NON-FREEZING FLUID TVD (BKB) MD (BKB) 20" CONDUCTOR 120 FT 120 FT ~ KOP(DIR:N 13.5° E; ANGLE:SGDEG) 50OFT ,, BASE PERMAFROST 1802 FT 1851FT · SSSV 2040 FT 2150 FT 13-3/8" 68~/FT NT-8OCYHE BTC 2695FT 300OFT BOTTOM OF FREEZE PROTECTION (ESTIMATED) 3300 FT TOP OF 9-5/8" CEMENT (ESTIMATED) 4076 FT 1/2", 12,6~/FT L-8OTDSTUBING W/ GLM's AND 4-1/2" TAILPIPE ASSEMBLY BEGINNING OF DROP TO 35° 7945 FT 12369FT 4-1/2" "X" NIPPLE 9-5/8" PACKER 8672 FT 13458 FT 7" LINER TOP 8712 FT 13508 FT 9-5/8" 47~/FT NT-80S NSCC 8912 FT 13758 FT 7" PACKER PLUG BACK TD 14325FT 7" 29=/FT L-80 BUTT LINER 9442 FT 14405 FT CRM/10-17-90 SURFACE HOLE DIVERTER SYSTEM Two lines venting 90 deg. apart in directions that ensure safe down wind venting, and ex- tending to a point at least 100' from any potential source of ignition. .~e~'-10" Full Opening Valves 43' I -"' 35' or as required Dresser Sleeve 1. All pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 10" Diverter Line 2. Manual 10" full opening valves mechanically connected to ensure that one valve is fail-safe open at all times. 3. All turns are 90 deg. and targeted. 10" Full opening ball valve w/Hydraulic Actuator Cellar I 'ECEIVED 20" Diverter Spool w/10" Side Outlet.. M EM 1/3/90 BOP STACK CONFIGURATION 13 5/8", 5000 PSI WP TRIPLE RAM ST ACK DRILLING RISER I I ANNULAR PREVENTER 2" KILL LINE MANUAL HYDRAULIC GATE GATE PI PE RAMS I I I BLIND RAMS I DRILLING SPOOL I PI PE RAMS I I 4" CHOKE LINE HYDRAULIC MANUAL GATE GATE Pt. MclNTYRE DIRECTIONAL DIAGRAM DEPARTURE TO BHL: 10140FT 14405 FT MD 9442 FT TVD BKB DEPARTURE TO TARGET: 9776 FT 13770 FT MD 8922 FT TVD BKB TRUE NORTH GRID N 13° 32'E SURFACE LOCATION: X = 681,298 FT; Y = 5,998,042FT; ASP 4 535FT SNL; 1048 FT EWL SEC 14, T12N, R14E NOTE: THE CLOSEST WELL TO PT. MclNTYRE #9 IS PT. MclNTYRE #6 LOCATED 35 FT NORTHWEST AT THE SURFACE AND 4530 FT AT 9400 FT TVD. CRM/9-28-90 0 1 2 G ISLAND (MILES) GWYDYR BaY ~ POINT STORKERSEN ~ ~~' POINT MCINTYRE NO. 9 LAT. = 70'23'59.55' LONG. = 148'31 '27.79' y = 5,998,042 A.S.P. X = 681,298 ZONE 535' FROM NORTH UNE 1,04.8' FROM WEST UNE 1" = 5280' BP-051 SURVEYOR'S CERTIFICATE I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska, and that this plat represents a survey made by me or under my supervision, and that all dimensions and other details are correct. Date... OCT. 12, 1990 LS No. 7535 '7 Registered Lan d~Surveyor POINT MCINTYRE No.9 AS STAKED WELL NUMBER 9 LOCATED IN PROTRACTED SECTION 14, TOWNSHIP 12 NORTH, RANGE 14 EAST, UMIAT MEREDIAN, ALASKA SURVEYED FOR: B.P. EX LORAIION P.O. BOX 196612 ANCHORAGE, ALASKA 99519--6612 SURVEYED BY: ARCTIC SLOPE CONSULTING GROUP 6700 ARCTIC SPUR ROAD ANCHORAGE, ALASKA 99518 DR^W~ BY: KMC IDAm 10/12/_90 _~4~DUA124: [DR~NO35]PM~_CLOSAP_ShORT7. LIS, 4 15-OCF-i~O ,: Date' I~-OCT-~O Time:.'I'~,:~ Sea~ch Radius= 200 7 DEGREE LEAD LINE For proposed well: PM~ [22- 2-12-1q] ......... Location = W-E S-N TVD(SBS) Top ~81~8.00 5~804~.00 -41.~0 _Bot~om_~__~8~O~37--~O08143~ ~8 ....... ~40~ ~8 Note: All depths in ~eet Belo~ Aellg ~;Jshin§ (BFB) --WELL--/DEN% Closest Approach /PROPOSED% ............... /NEARBY~ ...... TVD DEPART TVD DEPART Vertical Intersection CLOSEST ....... /PROPOSED\ DISTANCE TVD DEPART TVD ~EPART --AO~9~O0000 PMC-O& 300.0 0.0 300.0 0.4 41.0 SUMMARY The well which comes closest to the proposed well is: VERTICAt. ._ A029~2200000 P~MC--O& C.? ~ :"--Cl~r~t--ap p~-oagh~d-i~tan¢ e--= ,4 l~ O- ~ e e t *-?>: KIC;~ OFF ~or this run = 500.0 feet ....... Top _$45DUA124:EDRANO35]PMg--CLDSAP--SHORT'LiS>2 :~-nrT-'°~O- ,~ ., .~1: t6_ ............. Closest AppPoach--Anat-y-sas .................... Date: 1D-OCT-gO Time: 11:16:48 Search Radius= 200 COURSE LiNE For proposed well: PM9 [~- ~-I~-14] Location = W-E S-N TVD(SBS) &81~8.00 5~E8042.00 -41.50 '--Bottom -~3D~-OO--&OOT&O0.O0 ---SBBO.-O0 " Note: All depths in ~ee~ Belo~ Kell~ Bushing (BKB) ~2 ~= ...................... " Closest Approach ---WEEL~[DENT /PROPOSED\ /NEARBYA " TVD DEPART TVD DEPART ::~. PMC-O~ MO0. O 0.0 300.0 0.4 41.0 SUMMARY CLOSEST---- DISTANCE Vertical intersection ~RDP~SED~ ............ /NEARBY\-- TVD DEPART vVD DEPART 'JERTICA:- .~ The ~ell mhich comes closest to the p~oposed mell is: -' ^0~--~00000 PM~-06 ClosesC-a~~s~n~e ~ RIC½ OFF ~or this run = 41.0 500.0 ~eet Pt. MclNTYRE #9 MUD PROGRAM Mud Weight Viscosity Fluid Loss (sec/at) (ml/30min) pH 0-3,000' 8.8-9.8 100-200 20-15 8.5-9.0 3,000'- 9.2-10.5 13,758' Set 13-3/8" casing 40-60 8-16 -- Set 9-5/8" casing 8.0-10.0 Mud Type/ Components Generic Mud #8 Fresh water Gel Soda Ash Barite Generic Mud #7 Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PHPA Polymer 13,758'- 14,405' 9.2-10.5 40-60 Set 7" Liner 8-16 8.0-11.0 Generic Mud #7 Seawater Fresh water Gel Caustic Soda Soda Ash Barite Sodium Bicarbonate Lignite Boreplate Drispac PHPA Polymer Calcium Carbonate Sodium Chloride ALASKA UNITED RIG NO. 3 MUD SOLIDS CONTROL EQUIPMENT 1 - Brandt Dual Tandem Shale Shaker 1 - Demco 6-12" Cone Shale Desander 1 - Demco 416H w/16 cones & (1) Demco 48H w/16 cones (Desilter) 1- Tri-FIo Horizontal Vacuum Atmospheric Mud Degasser 1- 200 gPm Operating Capacity Centrifuge 19- Brandt MA5 Mud Mix Agitators 1- 125 bbl. Trip Tank 1- Recording drilling fluid pit level indicator with, both visual and audio warning devices at driller's console 1- Drilling fluid flow sensor with readout at driller's console 1- Cavium Dewatering screen assembly RIG 3 MUD SYSTEM ALASKA UNITED DRILLING INC. RIG 3 MUD SYSTEM DAWN, DAI~ Oc Iobe~' 1987 ~all At'HIO¥IO CI~ClllO BP EXPLORATION September 19, 1990 RECEIVED s EP 2 4 1990 Alaska 0ii & Gas Cons. C0mm'ts~'ton Ancl~0rage C. V. Chatterton Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 co ¢,M 'CCMM -J;~" RES ENG I '$R 'ENG ..~ SR ENG S~ G EOL.,.' :::;f1'¥, G,-OL As~i'I SSTI 1 STAT T~-CH F LE II .Exploration Fluids Pt. Mclntyre #9 Exploration Well .. ADL 365548. Dear Mr. Chatterton: BP Exploration (Alaska) Inc. (BPX) is the operator for the Pt. Mclntyre #9 exploration well, which is planned to have a bottom hole location within ADL 365548. BPX hereby notifies the Alaska Oil and Gas Conservation Commission (AOGCC) that in the event that the production tests, if any, from Pt. Mclntyre #9 yield hydrocarbon liquids, BPX may take such fluids either to Flow Station #1 (FS1) to be commingled with Prudhoe Bay production, or to Lisburne Processing Center (LPC) to be commingled with Lisburne production, for cleaning, processing, and sale. BPX as lessee for ADL 365548, intends to transfer dght, title and interest of the fluids to the Prudhoe Bay owners or the Lisburne owners respectively. .. BPX, as exploration operator'on ADL 365548 and 100% working interest owner in Pt. Mclntyre #9, assumes responsibility for paying all royalty, tax and/or other assessments on produced oil from Pt. Mclntyre #9 exploration test in 1990/1991. Production rates will be measured using meters on separators during testing, and hydrocarbon volumes will be strapped in tanks. Production measurements will be made in accordance with A©GCC regulations'20 AAC 25.228 and 25.230. Metered volumes of the exploration test fluids will be reported by letter to the Alaska Department of Natural Resources, Division of Oil and Gas and AOGCC after production tests are completed. Exploration Fluids Pt. Mclntyre #9 Exploration Well September 19, 1990 Page Two Exploration volumes processed at FS1 will be deducted from the PBU Offtake/Production Allocation Report volumes under the category of Off Unit Receipts. Exploration volumes processed at LPC will be backed out of the - Lisburne Offtake/Production Allocation Report volumes. BPX will notify the AOGCC prior to testing Pt. Mclntyre//9. If an AOGCC representative wishes to witness the test, BPX requests that the representative obtain polar bear and environmental/cultural training from BPX. A Beaufort Sea Environmental/Cultural Card and "polar bear stamp" are provided to persons who watch two videos at BPX. Please contact Mark Fraker at 564-5527 for further information about environmental training. Please indicate your approval below and return a copy of this letter to the undersigned. If you have any questions feel free to contact myself at 564-5989 or B. E. Stepanek at 564-5511. Sincerely, T. J. Obeney Pat Coyne, Exxon J. Dana Dayton, ARCO A. M. Tadolini, ARCO APPROVED THIS ~_._Z_/_. DAY OF ALASKA OIL AND GAS CONSERVATION COMMISSION ,1990. (8) Cio ~ 'i3). ' (14 r~ru (2.3 c~.---u .?.8) 2. Is vel1 co' be 'Loca:ed in a del/ned pool ............................. 3. IS ve!l loon:ed proper d~s~ce from proper:T 1/ne .................. 4. Is veil located proper d/s:ence from o-.her wells ........ $. Is sufficient undedi~a~ed acreage ava/lable ~m ~ pool ............ 6. Is vel! co be 6evinced a~d ~s vellbore plac ~n~luded ................ 7. ~s opera~o~ :he onl7 affected par~, ................................. 8. C~n pera~ be approved b~ore f/~:een-~a7 va~ ....................... g. Does opera:or have a bond in force .................................. 21.0. Is a co~ervaciou or6er nee~e~ ...................................... I1. ~ a~~a=~ appr~ nee~e~ ................................... 13 D ~ ~ ~v ~q d n~ ' . o~ · we e a ue me ~ e= ......................... i i i ii iii 14. Y~ c6nduc:or sc=lng prodded ........................................ !~. T~T'~.~ sure, ace c~g procec= ~ zones r~o~bl~ ~ec~ed co Il I I 17. ~ c~c ~e ~ ~r~ace ~d ~e~e~=e or produc~ s~gs ....' 18. W~ c~= cover ~ ~ produc:~ve ho~o~ ..................... 19. W~ ~ ~E give a~aq~ca s~e~ ~ co.apse, ce~i~ ~ b~sc.. ii i 20. ~ c~ ~ co be ~d oil ~r~ ~ ~~-~ v~ore ............. , lI. Is old v~bore ~do~c procedur~ ~cluded on l~a03 ............ ~ ~ adeq~:e ~e~bore separa~on proDose~ · i i iii i i i ~/~, i i llll i i i i i iiii~ iii i i i i i i imm Il· I I i III I Il Illl II I I ~-v: 01130/89 i ii ~ i i i mm mmm m ./ I 32. Adc~.an.e~ reqt~.remeu~s ............................................. ~ · i i i ii i i i i i i i ii i i i i ii i iii J (2) Loc (10 and 13). (14 r. hru cs) (2~ :hr= 18) (!9 :hru 31) rev: 01130/89 Company_ 1 Is :he pe.~L~: fee ar:ached e ~eee ee e,leeeeeeeeeee oeeeeeeee, eeeee lee .. e me e Z. ~ we~ co' be located ~ a de~ed pool ............................. 3. Is we~ loca:ed proper ~. Is we~ loca:ed proper ~:~ce from o:he: we~ ........ ~ ........... 5. Is s~fi:ien: ~de~ica:ed acreage av~ble ~. ~ ~e~ :o be ~e~:ed ~ is we~bore pla: ~clude~ ................ ~y · 7. Is opera:or :he o affec:a~ p~ ................................. 8. C~ pe~: be approved b~ore f~:een-~7 w~: ...................... 9. Does operator h~e a bon~ 10. ~ a conse~acion order nee&e~ ...................................... 11. Is aa~*~s::aclve approv~ nee~e~ ................................... 12.' ~ ~e l~e n~r approoriace i3 Do~ ~e we~ ~ve a ~que -=~e ~d u~e: · , ~. ~ ~6~c~o~ s~~ 1~. ~ surface c~g pro,ac: se~e ~ ~ ~der~ro~d source 1~. ~ ~ough c~en: use~ I7. ~*~ c~: :ie ~ ~rface ~d ~:a~e~:e or produc~ s:=~gs ... 18. W~ c=~: cover 19. ~ ~ c~g give adeq~:e s~e=y 20. ~ :~s ve~ :o be ~c~d off from ~ ~:~g w~bore ............. 21. Is old w~bore ab~do~: procedure ~cluded on 1~03 ............ ~ ~ adequa:e we~bore separa:ion proposed · 2~. Is ~e d~g fluid pro~ ~. ~e necess~ ~agr=-q ~d 26. Does BOPE ~ve suffici~: pres~re 27. Do~ ~e ~oke --~*old c~17 v/~Z ~-5~ (~ 8~) .................. 28 ~ ~e pr~ce of HiS gas probable.' 30. ~8 se~c ~~s~ ~a~a ~us~ed o~ s~~ ~as :ones .............. 31. ~ ~ offshore Ioc., =e ~e7 res~:s of seabed cnn~:i~s pres~:ad Lease & Well ii i 3Z. A~/:ional requ/re~en:s ............................................. ' ' I~Z~zAL' ovo. UNIT I 0~/0~T POOL CLASS ~T~A~y$ ANHA NO. TH0~ i i i 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. __ SCAN ONLY -- 999 FILES. ~~ ***** REEL READER ***** ( 1) LISWRT 91/02/22 .' MCCORD-LEWIS ENERGY SERVICES - PETROS WELL LOG ANALYSIS SY ***** TAPE READER ( 2 ) LISWRT 91/02/~ * ( 3)* ( 4)* ( 5) * ( 6)* ( 7) * ( 8)* ( 9)* ( 10) * ( 11) * ( 12) * ( 13) ( 14) * ( 15) * ( 16) * ( '17) * ( 18) * ( 19) * ( 20) * ( 21) * ( 22) * ( 23) * ( 24) * ( 25) * ( 26) * ( 27) ** ( 28) * ( 29) * ( 30) * ( 31) * ( 32) * ( 33) * ( 34) * ( 35) * ( 36) * ( 37) * ( 38) * ( 3g) * ( 40) * ( 41) * ( 42) * ( 43) * ( 44) * ( 45) * i I' MI IrTI &ITIA/ **** COHMENTS ***~ ****************************************************************** BP EXPLORATION (ALASKA) CONFIDENTIAL DATA ****************************************************************** COMPANY: BP EXPLORATION WELL : PT. MCINTYRE .~ FIELD : .PT. MCINTYRE COUNTY : NORTH SLOPE BOROUGE STATE : ALASKA COUNTRY: USA API NUMBER: 500292209600 DATE: FEBRUARY 21,1991 ****************************************************************** THIS TAPE CONTAINS DATA WRITTEN IN LIS FORMAT BY PET~OS ROUTINE DUE TO TIGHT HOLE STATUS,TELECO MWD DIGITAL DATA WAS ORIGINALLY TRANSFERRED TO BP REPRESENTATIVE AT WELLSITE ON 3.§ ' FLOPPY DISK. ORIGINAL DATA ON TELECO' S HARD DISK WAS BACKED UP ON FLOPPY WITH IBM FASTBACK PROGRAM. ***************************************************************** ROPS ]lATE OF PENETRATION / FT/HR WBCS SURFACE WOE / KLBS TCDX CDS TEMPERATURE MWD / DEG C RPAM RESISTIVITY (PD) APP RWD / OHN-M RAAM RESISTIVITY (AR) APP RWD / OHM-M GRCM GAMMA RAY COR (RWD) MWD /API GRCX GAMMA RAY COR (MWD) MWD /API RSAX RESISTIVITY (SN) API MWD / OHM-M RAAX RESISTIVITY (AR) API MWD / OHM-M RPAX RESISTIVITY (PD) API MWD / OHM-M TSD TIME SINCE DRILLED / MINE ****************************************************************** ****************************************************************** ***** FILE HEADER ***** ( 46) LISWRT.001 91/02/22 1024 ***** COMMENTS ***** ( 47) FIELD 29 WELL 22096 ( 48) ***** DATA FORMAT SPECIFICATION ***** ENTRY BLOCKS UP/DOWN FLAG 255.000 FRAME SPACING 60.0000 FRAHE SPACING UNITS .lIN LO ,. .iCROFILMED ABSENT VALUE -9999.00 DATUM BLOCKS MNEM SERVICE SERVICE UNIT API iD ORDER % LOG DEPT FT 0 DEPT MWD 800 FT 0 ROPS MWD 801 FT/H 0 WBCS'MWD 802 KLBS 0 TCDX MWD 803 TELE 0 RPAM MEMO 804 OHMM 0 RAAM MEMO 805 OHMM 0 GRCM MEMO 806 API 0 GRCX REAL 807 API 0 RSAX REAL 808 OHMM 0 RAAX REAL 809 OHMM 0 RPAX REAL 810 OHMM 0 TED MWD 811 MINS 0 ***** FILE TRAILER *** ( 1244) LISWRT.001 ***** END LOGICAL FILE API API API FILE TYPE CLASS MOD NO. 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 i SIZE 91/'02/22 1024 LO PROCESS SAMPLE REPR LEVEL CODE 4 0 I 68 4 0 I 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 i 68 4 0 I 68 4 0 I 68 4 0 I 68 4 0 i 68 4 0 I 68 4 0 I 66 1244 LOGICAL RECORDS ***** 22701 FRAMES READ FROM 1195 RECORDS, COMPUTED FRAME SPACING= 0.5000 FT 22701 DATA FRAHES FROM 3050.00 THROUGH 14400.00 RECORDS 49 THROUGH 1243 STATISTICS FOR DEPTH 3050.0 TO 14400'.0 CH MNEM SID CURVE MINIMUM MAXIMUM MEAN STD-DEV i DEPT MWD I 3050.00 14400.0 8725.00 3276.61 2 ROPE MWD 2 3.27500 2185.04 134.647 156.270 3 WBCS MWD 3 0.420000 128.963 41.8009 20.8177 4 TCDX MWD 4 48.0000 276.800 109.634 19.0804 5 RPAM MEMO 5 0.174000 34.5360 3.65854 2.81594 6 RAA~ MEMO 6 0.317000 444.898 14.8873 45.7434 7 GRCM MEMO 7 18.4130 394.347 123.786 53.1183 8 GRCX REAL 8 36.0070 417.986 155.035 42.9467 9 RSAX REAL 9 0.525000 17.2330 3.35494 1.07458 10 RAAX REAL 10 0.900000E-01 1014.26 7.87763 27.2675 11 RPAX REAL 11 9.09000 17.0200 13.1894 2.68549 12 TSD MWD 12 1.00000 5633.00 263.187 797.820 ************************************************** END LOGICAL FILE - 1 ************************************************** SAMPLES 22701 20266 19983 5239 2841 2427 2841 8648 10432 1731 10 2810 ************************************************** START LOGICAL FILE - 2 ************************************************** ***** TAPE TRAILER ***** 1) LISWRT 91/02/22 McCORD-LEWIS ENERGY SERVICES - PETROS WELL LOG ANALYSIS SY ( 2) LISWRT 91/02/22 ************************************************** END LOGICAL FILE - 2 ************************************************** McCORD-LEWIS ENERGY SERVICES - PETROS WELL LOG ANALYSIS SY --- END OF INPUT -- COMPANY ~AME : BP EXPLORATION WEb!> NAME : PT, .~CIMTYRE #9 FIELD '~,.!A~E : PT, MCINTYRE BOROUGH : NORTH SLOPE STATE : ALASKA API NU~BE~ ': 50-02q-~2096 ." IS ~aDe Verification blstinq ChlU~.n, erqer A!as~a Co,~Dutl. ng Center 6-dA~.i'-~ 991 **** FILF HEADER FILF NAI~ff, : GCT .001 SF. RVICE : FLIC .VERSIO~,~ : 001~04 DATF. I 91/01/ 6 ~,i~X REC SIZE ~ 1024 FIbF 'rYPR : bO LAST F1LE : PAGE~ ******************************************************************************** ******************************************************************************* **' SCHbtI~BERGER ~"'E~L SER¥ICE. S ** , FIELD: PT ~CINTYRE S~"AT~: ~nASKA AP1 NUMBER: 50-029-22096 b~CATION: 535' ~NL & 1048' FWL SECTION~ 14 TOWNSHIP: 12N PERi4ANEBT DATUm: N$5 ELEVATION.: O' LOG ~EASURED FRO~ RKB 40.45' ABOVE P~RHANENT DATUM RANGE: 1.4~ IS me-e Ver~.,ttcatlon chlurl ~er~]er Alaska 14.375' LOGGIL!G nlSTRICT: I.,nGGINC K~GI~.EER: PRUD~!3E: FAY JEFF FORNICA ~RO~vr-~/OUESEr,!SURY TOOt, ~U~BERS: CAD-VA 30 SGC-$a 271. C~$-DA 82 CE~S-A 733 GCEC-B 713 GCID-A 37 TCCg 420 CBC-gA 83 CEEC-A 833 GCAD-A 755 'GCPH-A 727 TCCB 276 D~TE JOB STARTED: 6-JA~=91 JO{~ REFERENCE NOI 74~68 LDP/A~!A: R, ~RUW'ELb CONS TIJ~'~I VALU DF, FI .... BP .EXPbORA.TION Company N.ame eld ~ame CN F ~..,' MaTT SWAT COUM SECT API~ PT, MCINTYRE PT ~CI~iTYRE #9 ALASKA NORTM SLOPE 535' FMb & 1048' FWL 42353~ _ 50-029-22096 We~io~ame State or Prove. nee County Section. Township Rano'e, rieid Location Service. Order Numbet APl Serial Number ....... IS ~aDe Verification chlUmP'erqer AlasKa Computing Center TYPE DEFI DFPm ~eDth Channel. G .p.g.p GYRD De~th VDMP '[rue Vertical ~)emth as c~mnel <TV~rCP!> l')Ev ] Oevlat~oD WI,A7 Deviation Az 1~r, utb NS[::P North SOUth [)rift [WDm ~ast west Dr~t Commoment C~E~. CURVATURE OF THE WELL ** n&.T~ F'O[~AT SPECIFYCATION RECORD TYPE REP~ COO~ VALUE 1 66 0 2 66 0 4 66 1 5 66 6 7~ 7 65 9 65 F 11 66 !2 6~ 13 66 O 1.~ 65 15 66 68 16 66 ** S~;T TYPE CHA~ ** N.a~ME SENV UNIT SERVICK API AP1 APl' AP1 FILE NUMB NUMM SIZE REPR PROCESS ].D ORDER ~ bOG TYPE CLASS ~DD N'U~B 8A~P EbEM CODE (HEX) D~:PT FT 4135~1 O0 GDEP GET FT 413531 99 VDEP GCT FT 41,3531 99 DEV! GET DEG 413531 99 HLAZ GCT DEG 413531 99 N'SD~ GCT FT 413531 99 Ew(')~ GET FT 4..3531i 99 CWEL GET D/HF 413531 99 000 O0 000 O0 000 O0 620 11 62O 620 620 '11 OOO O0 0 1 0 i 1 0 I 1 0 1 1 0 1 1 0 I 1 0 1 1 0 .1 1 1 4 68 000.0000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 I 4 68 0000000000 1 4 68 0000000000 1 .4 68 0000000000 I 4 68 0000000000 IS ~ar',~ Verificat. ior~ [,istlno chlu~r, berqer AlasKa Co~,Dutinq Center 6-JA~-199! 16:11 PAGE: 655 1 655 654 653 .652 651 H I.,A Y..<;CT DFpT, D F P'!' . DEP7':. 35.o0~"~ GDFP..:C.,' 32.050 VOEP,~,CP 32 000 DEVI GCT 48,~(')d NSDR,GCT 0.O~O EWDR,GCT 0.000 C~EL.GCT OO.O(';O GD£P.GC~ 1248,800 YDEIp. GCT 1242.240 DEVI,GCT ~5.i49 *'~SOP.GCT 79.978 EhOR,GCT 11,382 C~EL,GCT no,0ou GD~P.GCT b2~6,745 VI'}EP,GCT 3976.8~4 D~VI.GCT 14,12o NSDR.GCT 27i0.916 E~DR,GCT 682.6]4 CWEL.GCT 00.00o GD~P,GCT ~456 746 YDEP,GCT 5846.996 DE¥I,GCT 16.831 :~SD~.{3Ci%' 5269:948 E~DR,GCT 1432.834 CWEL.GCT 0o,0o0 GOFP,GCT 1~366.846 VDEP GCT 749~.054 DEVIoGCT 25,24.6 ~SD~ b,f 566,456 EWDR:GCT 206 877 C~EL,GCT ....... · . Gu'..- 9576..637 DEVI,GCT o7,~':1)o (;PEP Gc'r 14375 000 VDEP,GCT 30 693 hlSD~'~t''' 9403:914 ° .... .,,~u~. 649 CWEB'GCT END OF DATA *.* 0,203 0,000 i4,025 2,952 56,552 2,191 53,319 0,905 54,27S 2,058 41. 013 0~000 **** FILE TRAI [.,ER FILE NAMC : t~ ,DO1 SM~VI. CE : FblC VERSION : O0 DATF , "P : Oll01/ 6 ~Ag REC 8!Z .... : FiLE: TYPF : LO **** TAPE TRAILER **** SFRvICE NAME : GCT D~T~ : 91/0i/ 6 O~IGI~ : FLIC TaPE NA~E : 74268 CONTINUATION '~ : 1 PREvIous TAPE ~ CO~KNT : (;CT, 8P EXPLORATION, PT, MCINTYRE #9, PT, MCINTYRE, 50'029'22096 I8 'rinse ~'er~.ficetlon ~=istina :high, bert, er A18SKe C~putinq Cenr,.er 6-JAM-Iq91 1.6:11 SE~V.IC~ ~.~E : GCT E~'I'? : gilt'.1/ 6 RFE~, ~'~'E : 7426~ Cn~INO~TIOM # ~ PP~VIOUS REM[, : C(~EW'? : GCT, 8P EKghOR~TION, PT, ~CINTYRE #9, PT, MCINTYRE, 50-029-2~096 u. FtDENTIAL SCAN ONLY '- 999 FILES.. ***** REEl 1) RAILS ~CI'12/17 GG SCHLLFa'~:~EER )~.ELL S~,~VICES CS'b TAFE ***** TAPE HE~DER *'**** 2) ,RAWLS $C/12/17 CSU 5491e2 O0 SCHL~Fi~!!'~E~(~.,. ~ELL ~,eE.~VICE'~, ~ CSL T~FE } ( 3 ) LNKNCWN Li~KNCWN ) L~KNC~N LI~KNC~N LNKNCWN ) L ~KNC'W~ LI~KNC~N ***** FILE HE~DER TC~ .'C~'7 L, CG 32.4 9e/12/17 LCGIC~L ~ECC~ TYPE LCGIC~L ~ECGFE 'rY~E 22'7 SKIPPED ~EC LOGICAL ~ECC~B ?Y~E 224 SKIPPED ~EC LCGICAL ~ECC~D TY~E 224 S~IPPED ~EC LOGICAL ~ECCG, D TYPE 2~7 SKIPPED LOGICAL ~ECC~ TYF2 224 ~XIP~ED LCGIC~L ~ECCR~ TYPE 1024 5 '7 1(] P~ L~KNC~N L~KNC~N LkKNC~N LNKNC~N bNKNC~N LNKNCWN LNKNCWN LNKN¢~N L~KNCWN LEKNC~N LNKNC~N LNKNCWN ~K,NCWN **'*** INFCRM~IION RECORD LCGIC~L ~ECO~C TYPE 42 ~KIPP[D LCGIC~L ~ECC~ TYFE 42 SKIPPED L~GIC~L RECO~C TYPE 42 S~IPPED EEC LCGIC~L ~ECg~ TYPE 42 SKIPPED ~EC LgG']C&L RECg~]~'TYPE 42 S~IPFEg LCGIC~L ~ECCGD TYPE 4~ SKIPPED REC LOGICAL ~ECO~ TY~E 42 SKIPPED ~EC LCGIC~L ~EC¢'~D TYPE 42 ,SKIPPED REC LCGiC~L ~ECC:~ TYPE 42 SKIFFEO REC LGGIC&L REC06~ TYPE 42 SKIPP£D 'REC LCGIC~L ~ECO~ TYPE 4'2 SKIPPED ~EC LCGIC~L ~ECO~ TYFE 4'2 SKIPPED ~EC LCGIC~L ~ECCG,~ TY~E 42 SKIPPED 30 31 3:2 33 37 ( 41) **** E ~TF~Y BLOCKS ~ATA ~ECO.~ D ~ATU~ SPEC'IF ~ATA FRAME S LP/DCt, N FLAG CPT'rCAL LOG DATA ~EFE~Eh CATA ~EFERE~ F~AME SPACIN ~AME SPACIN PA~I~M F~A~ CEPTH RECCR~ kNITS OF DEF ~EPR. CODE F RATU~ SPECIF * DAT~q FCRi~i~T SPECIFICATiCN TYPE ZCAT!CN aLOCK 'TYPJ ..... I]E DEPTH SCALE UNITS ..... CE PCINT- CE PCINT LNITS G UNITS ES/RECORC I~G PCDE IN OAla RECORDS .... CLlPgl DEPTH ICAIICN ELCCK S~-TYPE O OCr, O. CCOCCC E+O~ 2~2 .<]CC 1 .CCO~C I .CgCCC -52~ .OCC INCH 60 .OGOC .1ZN 3 .CC, OCC 1 .CCCCC .1I,~ 7_~ .CCCC 1 .C~IGC£ O CATUff BLOCKS ~NEM SERVICE SERVICE lCD TIME ETIM CS lOH EIFF IOH lENS TOH UNIT Aml AFI LOC- TYPE $ 7 ~ ',iS 7 6:~e S 7 ~]6 F/HR ? d.~,6 F 7 aFrO L~F 7 6Z5 ~PI FILL CLASS NC. :': 7 21 ,'7 2 1 Zl 7 2.1 7 SIT."- )ARK TOH fiIRD TOH I RDZ TOH IRDP I RDN TOH ; IXD TOH IXDZ TOH I XDP lOH I )DN lOH ! RMZ lOH I~MP TOH ! RMN lOH R IXM TOH 1XMZ TON IXMP TOH ! XMN TOH ~CID ~OH CCIM TOH I~QF TOH ZP, QF lOH ~EQF TON '~ SFV TON $ FVP TON ~ FVZ TOH ~ SFC 'TOM SFCP .TOH ~ FCZ TOH I~CSF TON $ FQF TON ~ SFB TOH ~ FBZ TON ~ FBP TON ~RFO TON f~ FOC TOH fiXFO TON X FOC TON RSPR TOH ~PAZ, TON SPAP TOH RITE lOH ~IH TON D'ZHV TOH FT~yP TON FT~Z 1OH RPSD TON, E PS~ TOH ,~N PSDTOH ,i. PSDTON IR~A ION 'Z I)~PTON ! RDA TOH ; IXP TOH ~,'OQ~CT OH Z' W ~i~ TOH IND.B 15VT TON ~ 5VT lrOH ~ 2IV,,, TOH .1 sv !! 'rOH ~EC~' TOH R. EC~ 'TON . ~ E RS',i TOH 15 0 c 0 0 .3 0 0 0 0 0 0 0 0 0 ,.., 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 G 0 0 C rl C 0 O 0 0 0 0 0 0 C) C 0 0 0 0 O 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C 0 0 0 0 0 0 C C c C, c F.: C C O C., 0 C O 0 0 O O 0 0 C O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C 0 0 C C 0 0 0 0 0 0 0 0 O 7 7 7 7' 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 ? 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 .? 7 7 -? 7 7 7 7 7 7 7 7 7' 7 7 7 7 7 7 7 7 '7 2 ECGOCCCOCC 4 ~COOCCO0£C 4 [CCOCCOOCC 4 8COOCCOOCC 4 ~CCOOCOOCC 4 ~COOCCOOCC 4 ~CCOCCC3£C 4 6COOCCCOCC 4 .~CCOCCOOCC ~ ~CCCCCCOCC ~[COCCOOCC ~CCOCCCCCC ~ccoccoacc ~cooc[oocc ~cooccoacc Ecoocccocc !~cooccoocc ~coocccoc£ coo caocc '~CgOC~.OOCC ~CCOCCOOCE ~¢COCCCOCC '~CO0g[OOCC ECCOOCCO£C 4 ~COO~COOCC ~COOCCOOCC 4 .SCCOOCOOCC 4 8COOCCODCC 2 6COOOCOOCC 2 6COOCCOOCC ~COOOCOOCC 8COOCCOOCC ECOOC¢OOCC ~CCO¢'~OOCC 8CCOO20.OCC 2 8COOOZOOCC ~COOOCOOCC ~COOCCOOCC ,6'CO00COOCC 2 6CCO~COOCC 2 ~COO~20OCC 2 ~000200CC 2 ~CCO060OCC 8CCO0600CC ~COOC200CC 8CC08200C6 2 2 ~CCOC200CC 2 ~COOCZOOCC ,2 ~COOe'20OC£ 2 2 ~COOC~OOCC ,8CC00200¢C 2 8CCOG~OOCC 2 ~COOCZOOCC. '~C~Og'20O~C 2 8CCOC200C£ 2'SCC'OC2COCC' 2 2 8C000200CC 2 ~CO00200CC 2 8CC00200CC 2 B£COCCOOCC 6~ 6'5 68 49 4g 49 49 /,9 49 4g ?g 7~ P~,A TCH IDP I~P DPH ~ P H T 0 H IRD l'OH IXD IRM '[OH IXM TCH XD XM TOH ILD TOH ILM LD LM l'OH ~RA TOH L~A F~ TOH FV TOH FC TOH ~ FL 'IOH SFA TON FLU "fOH FLA ~R TOH P, TOH TSG TOH TEN IOH ~TE TOH RES IOH I'EN lOH PTE lOH 1EM 10 I:,1 TEM IOH CSW TOH V TOH SP lOH PA PAR lOH PMV P lOH 0 C C 7 ~ Pi / P! 1 1 Fl 4 6. n 7 ~, N/'~ 110 4,4 0 7 OHY, Iv 12C 46 O 7 0 H N ~ · 1 E 0 44 ~ '7 N~/F O O O 7 N P~ / ~ O 0 0 7 OHM~ 1ZO 46 g 7 OHM~ 12g 44 O 7 ~/~ 110 46 C 7 ~,/~. 110 44 0 7 OH~i~ 120 46 C 7 OH~ 1 ~0 44 0 7 1 ~ 0 O C ? 93 5 4 O 7 M A O O 0 7 MV O 0 O 7' M A 0 0 C 7 MM/~ ZIO I C 7 M~/,~ 210 I 0 7 0 H ~ F ~ 20 I 0 '7 OHNF 2~2 I O 7 O ~G C 0 0 O 7 GAPI 310 1 C '7 G A P I '] 1 '0 I C 7 0 0 0 7 L6F 0 0 0 7 L, SF 0 C C 7 D, EGF 0 O O 7 DEGC 0 O C 7 ~ C / K 0 0 ~ 7 O E ~ C 66 'O 21 C 7 0 0 C 7 V 0 0 C 7 MY 10 I 0 7 M V 1 0 I O 7 ~V 10 I O 7 N V 10 I '~ 7 ~; V 10 1 O 7 *~'*** DATA FC~M:T SPEC!FICATICN ***** LOCKS COAD TYP6 ............ O.CCOCCCE+CC PECIFICATICN ELOCK 'TYPE .... O,CCOgCCE+GC' FLAG I .COCCC LOG OEPTH SCALE U~II~ ..... 1,CGOCC FE2E~CE POINT -526,0CC FE~EhCE POINT LNITS I~C~ PACIkE 6C ,OOCC P~CI~;~ U~IIS ,lIN F~A~ES/AECOR~ ~.COOCC ECCRDIhG ~CDE 1.C~OCC F D6FTF Ih DAl~ RECORDS .... ,1Ih ODE FOR CllPgl DEPIH 7~.COCC PECIFICAIIC~ ELOCK SU~.-TYPE 1.COOCC . , .~'C 00C C COC'. C C,F. COCO C(~C'C ~CCCCCC£1CC ~COOCCOOCC 5 CCOCCOCC C. 6COOOC fnC,.,,.., C ~CCOCCCOCC 2 ~CCOC£COCC 2 ,I~COOCCOOC C 2 ~CCOCCCOCC 2 ~CCOCCOOCC ~,CCOCCdeCC 2 8COOC~COgE C 2 i~COOCCCOEC ~CCOCCOOCC 2 E'COOCCCCCC 2 ;:~COOCCOOCC 2 ~COOCCOOCC 2 aCOOCCCCC C: ?COOCCOOCC ? ~COOCCCCCC ~CCCCCO(]C C .'2 ',f!CCOCCCOC C 2 .~COOO~OOC C 2 ~4COCCOC£C 2 SCOOCCOOCC 2 ~'C, COCCCGC C ~!COOOCOOCC 2 8CCOCCCeCC Z ~4OOCCOOCC ? ~CCOCCOCCC 2 ~COOOlOOCC ? 9C'GOCILuCC ',,2 gCCO01CC~CC 2 ~COOC2OOEC R a~OOC£COCC 2 ~C'~JCCCCGC C 2 E'CCOC2OOCC 2 6~COCCOOCC I I £ATUP MNEM lCD 'liME ETIM BL I TOH TOH TOH OCKS ViCE SERVICE D CRDE~ fi UNIT AFl ~PI FiLE TYFE CLASS NO. d_!6 21 7 d.lo 21 7 SIZE PROCESS LEVEL PCCCCCCCCC 6CCOCCCCCC SAFFLE REPR CODE 73 I £S ,tIFF 1 ENS, ~ iRD TOH I RDZ TOH ]RDP ~IXD TOH IXDZ TOH IXDP TOH ]XDN TOH ~IR~ TOH i ~MZ ] RMP TOH I~.MN TOH ~ IXM 10H IXMZ TOH IXMP TOH IXMN TOH gCID TOH ~CIM TOH Ii~QF ~ E Q F ~ 0 H ~FV TOH S FVP TON SFVZ ~SFC ~OH FCP TOH FCZ ~CSF FQF SFB TOH FBZ 'TOH ~nFO TOH FOC 'TOH ~,FO TOH FOC TOH EPR SPAZ PAP TOH ITE DIH TOH IHV TOH F~VP TOH FTVZ TOH ~PSD TOH ~SD TOH ~PSD TOH IPSD TON ~A TON ZRP IRD~ TON EZXP ~CDC TON INF2 TOH I~D2 TON 5VT T0H ~SVT TON S2IV TON 5VS CECL TON ECS TCH F/HR F LBF F M M/Iv.' ~/P ~/P ~V ~ V NA NA ~'(A MA V V V V MV V V V V 6~5 158 O C O 0 0 O 0 0 0 O 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O 0 C 0 0 O O 0 0 O C 0 0 C 0 C O O 0 O C ~ ERS TOH i PRE TOH I F~,A TOH ] P~A 'TOH CZDP C IMP TOH IDPH TON !)PH loll ! IRD ] I×g 'TOH ] IRM IIXM TCH IXD TOH ,[ILD iOH C IL~ I LD TOH ILM ~LRA lOH ~FV ~FC 1CH CSFL lOH (~FA ~ FLU SFLA ITEM ~6R 'ICH ~R ~lEN ~HTE )~ES lOH )TEM IOH ~TE TON ~lE) lOH CTEM CCSW TOH ~EP lOH 'SPA SPAR ~ F~V 2326 7' 0 0 7 O ~ ~/F 7 110 ,44 0 OH~,~ 7 120 OH~ ? 120 44 f,i~ l ~" 7 0 0 O o H im~ ~ 7 I ~ 0 4 OH~X 7 120 44 0 MM/~ 7 110 46 C N ;~ / ~' 7 11 0 0 H ~ ~ 7 120 46 OHP,~ 7 I ~ ~ ~ b 44 0 7 120 0 0 M A 7 0 ~V ? O C 0 ~A 7 O 0 C M~:/~ ? 21 0 1 C ~ M / ~ ? 210 I C 0 H M F, ? 22 0 1 DE~C ? 0 O C ~ ~ P I ? 31 0 1 6, API ? 310 1 0 7 O C C L~F 7 0 0 L ;2 F 7 0 OH~' 7 0 O C DEGF 7 0 0 O ,D E G C 7 O O D C / K 7 '0 0 9EGC 7 660 Z1 C ? C 0 O V 7 O 0 ~V 7 10 1 MV ? 10 1 O MV 7 10 I O ~V 7 10 I CH ~KEI~ TCD TIME ETI'M ***** FiLE T~ILER ***** .0C7 LCG 32.4 ';'C/12/17 1024 PR ***** END LCGiCAL FILE ~9 LCGIC~L RECOROS 7C LNXNC~k LCEICAL RECO~£: TYPES FRJMES REAC FRCM 77E, RECCRDS, CC~PUTED 23Z6 DAlA F~APE,~ FRCH 144f3.CC IHRCL~H 1332C.5E SIATIETICS FCF DEPTH 1Z]EO.5 TC CLRVE ~I~I~[F FJXZ~tJN 1 0.345~a1E+C~ C.345~dEE+09 ~ 371.CC6 ~556.00 5 5.577CC '131Z.47 FFAP'E SPAC INit= FECCRDS .cC 144E3.C 564.2~1 C. SOOC FT SAFPLES 232~ ,~ C:S TOP, 5 DIFF TON 6 tENS TOF ? /~RK TON. 8 ~IRD TON, 9 ]RDZ ]0 IRDP TON 11 I~DN TOH 12 B, IXD TOH 13 IXDZ TOH 14 ]XDP TOH 15 I~DN 16 ~I R~ 1 OH 17 I~Z TOH 18 I~P TOH 19 I~M~ 'TOH 2g ~IXM TON 21 IXM'Z TOH 22 IXMP TON 23 IX~N TON 24 DCID TOH 25 DCI~ TON. ,26 ID(~F TOH 27 29 30 31 32 54 35 I~QF TCH DEQF TOH SFVP SFVZ TON. RS:FC TOH $ FCP TCH SFCZ TOP, DCSF lOP, 36 SFQF TON, 37 RSFB 'TOP, ] B S ~8 Z T OH 39 $'FBP TO, H 40 R~FO TON. 41 RFOC 'ION. ,42 ~XFO TOH 43 XFOC TOP 44 ~SPR TOH 45 SPAZ TOH 46 SPAP TOH 47 RITE TOH 48 RDIH TOH 49 DIHV 'TOH 50 FTVP TOH 51 FTVZ TCH 5~ RPSD TON 53 EPSD TOF 54 XPSD TON 55 IPSD ~ON. 56 IRMA TOH 57 2IRP T01- 58 I~DA lO~ 59 2IXP '[CH 60 )/(]DC TOH (1 IWF1 TCH 6']. IWF2 TOH 63 I~DB TOH 64 15VT TOP, 65 25VT 66 S2IV TON. 67 15VS TCH ~8 CECL d9 DECS TOH 4 21C.37~ 4'74C.00 S G.CCCCCCE+CC C.CCCCOGE+CC 6 3C],O.CC ~SC;G.OC 7 11,125C ~ -542. CCC 1 4G7.6::'.5 9 -23,4979 1~,9~61 10 18~0.Z~ 1977,36 11 1~'~ 1.4~ 1967,10 12 -542.0C[ 589~.84 1] -51.9241 115.9~5 15 1785.55 2071 ,C5 t7 -19.0851 -18.~178 1~ 32~1 .]2 3297.25 19 32~9,1~ ~302,42 20 -949,CCC 2752,2~ 21 '1.' ,, ~ 0 52 '7 22 '-314,dg~ 575,72.4 23 3378 ,C4 341 ~,66 24 O,~COOCCE+OC 247~,00 25 O. CCOQgCE'+~C '1,02344 2'6 0". OCOOCC E+GC 27 O,C~OCCC~+CC 2 ,CCEO0 23 O,CCO~CCE*CC 7,O~COO 29 2,~743~ 56,1198 30 31~,~49 319,597 31 2. 57482 32 1,45C~1 12,2164 3~ 12,2475 12,Z165 34 g, 7'~42~ E-C1 C.8264~5~-gl 35 -2,21~q 32752,0 36 O,OC'OCCC~+OC 1 ,OCCOC 37 -0,17627C 160,375 ~8 -~,.4C673E -C,1~4C6~ 536, ggC 53fi.SO~ 0.9~7734E-0~ I .32C31 g. CCgGCCE~QC C.70~C0~ 45C. 25C d 59.500 97~.CCC 986.50G 65.9375 71 .~125 22~.125 2~5.~75 Z47.CCC 25A.375 3.69~E~ ~ ,71E75 0.43Q4536-CE C.1gC430E-01 2,1757~ 2,25C00 2.17~7E 2.2441~ -0,20~195E-C1 ~ ,24CC9 2,131d4 ~ ,25C0~ g.~27734E-O2 9.9S219 2.1 ~164 2.25C06 4.41797 4,554~9 2.CC5E~ E .C5E59 3,74414 4,42578 4.~32~1 4.~5~Z4 2.~47~ 2.37c95 0.927734~-C2 ~ .72~65 4.~25CC ~.0523~ O.CCOCCCE+CC 2.CCCOO 5144. CC 3.274.57 C.CC(]OCCE+CC 7~ .9274 2a9.11C -Z 2. ~4~ '7 1~76.5E 1279.51 3270,7~ ~9,134~ 2 52C,5~E 3391 ~,115~61 C,13542~ ~,~4~64~E-C1 ~,3C7395 1~,4677 31 E, 92E 2 . 5946 ;'~' 8.4~672 12,27~T ~,8~595~E-C1 122,902 g,4 25623 E-C I 39,2136 -0,]2933E ~,~15221 C;.~27292 G.1DO914 0.~5491~E-[1 -11 9~1.692 7C,1871 232.677 3.70872 g,~]94C~E'-C 2 1 .E4164 2,21115 1 2.2113C 0.~1929E ?.21 2~C 0.271~51 2.2124~ 4.4~16~ 2,C3149 E.C~291 4.143[C 4.63911 2.}~981 0.~742C~ 4 ~ 6. ~, 5 S O.OCCCCCE+OO 469.106 15.14'7~ 17 t. 7 C,95429C ' 4.5C211 4.44~06 ~ 20.1 4. ~7 3C 0.1111 7.57~62 '7.3~71~ ~,547S262 152.732 C.4~1782 1. 421 98 ~ .61Cle C. 36~5 96 C. 9'3~ ~ 1 5 I. 747 7 C.]C[ 5 2CE- 01 1741.42 27.?932 C.34~C58E-01 .,, C .413587 g.2237'69 C.'272735 C.1~75~7 1.4C52a 2.5~$66 1.66~39 1 .~771 C .3CEC47E-02 C .2C~[76E-OZ C .26C~87E-OZ C .Z77~ CC E- G2 ~.1767~E-01 1 C.177161E-01 G.7C7254 C.17~4~1E-01 C.32~269E-01 ~ .11~91CE-~1 0.12574~E-01 G,7~1797E-01 ~ , 47E ~ 4~ E- C.52E453E-G2 C 2326 2326 232~ 2326 2326 232 ~ 232~, 2326 232~ 2326 2326 2326 232~ 23 ~f 6 2326 2326 232~ 2326 232~ 2326 232~, 23 2326 2326 2'32~ 232~ ~32~ 2326 23 ~6 '232,6 '232~ 232 ~ 232~ 232~ 23'2~ 232~ 232~ 232e 232~, 23E6 2326 2326 2326 73~ 2326 232~ 232~ 232~ 232~ 232d 2326 71 I F~E TO, 75 74 CIDP TO~ 75 C~P TO~ 77 I~PH 7S IIRD TOH 79 IIXO TCN ~0 81 IZXP~ TOH ~2 IXD TON ~3 IXM TON ~4 CILD TOH ~5 CIL~ ~6 ILD TON ~7 IL~ 88 OPERA TOH ~9 QLRA TON 90 SFE~ TON gl SFV 9~ S FC TON 93 C S FL TCH 94 g5 SFLU TON 96 ~LA TON 97 !lE~ TON 98 RGR TON 101 HTEN TOD 1C2 RNTE TOH 104 ~]E~ TON 105 ~MTE 1C~ DTEM ~OH 1C7 C~EM TON 1C~ CCS~ TON 1C'9 NV TON 110 RS~ 111 112 SPAR ~OH 11Z 114 SP TON 70 4.COCCC 25~:'.C05 7'1 2I].OCC'C 2C.CCO0 ?2 O. CCOCCCE*CC 73 1 .COOCC I. OCt OC 7,4 -25 .dS~] ~,BOd ,OO 75 -~8'7.5CC 14E~.00 7~ 0.2¢22C7 1 77 O. ~JTO Eg'~ 78 '1~,0~13 128S,00 79 -658.06C 5572.00 ~C -gg~.CCC 14~Z,OO 81 -9dl ,5C6 263.8, OC 82 0.."1'7 919 ~ 195C.00 83 0.3789C~ 195C.00 84 -3.7793C 243~ ~5 -975.5CC 174~. 8~ 0.~10156 1950.0C ~7 0:.5722~ 1950.00 88 0.349~09 489.C00 89 -214.125 Z1.SE81 90 0'240Z34 91 -0.Z1777] 51.3438 93 4C.25CC Z2752.0 94 4g.,~5~3 32752.0 9S O.OCOCCCE+~C 9d. 96,00 96 o.g765~ZE-C3 969d.00 g7 71.0GCC 77. 5625 9~ 17.1094 9~ 21.2~g 2~9.750 100 17'~.06C 176.C00 101 -2~C.50C 1503.00 lOZ -2.6C.5CC 1503.00 103 0.2C2~37 C.280~73 104 15~.75C 167.E50 105 ,~7.525C 75'. 1'~5C 1Od -99d. CCC 555.500 107 ~.9375 79.5C00 lOS O.OCOCC~E*CC C.COCCOCE+OC 10g 25C. 5~C 110 3~4.75C 111 4d7.50C d72.COO 112 -221.37~ 9.1615~ 113 -~7.566 -~01 ,CO0 114 -237.5C[ 24,3906 L FILE- I I 2~: .'743 2C .OCCC C. C C O0,CC .,,OOCC 3~,?.93~ 32~.416 6. ~ 4 2'~ 7 1 3,3. 2~ ~, 1 47,5~41 3C2 81 .~94C 153 · 4 ! 1 79~ .859 3a~.182 32E .934 7.7212~ 1 31.72 9.932C~ -1 e 41.21 8.'2~42C 45C,34C 524.623 595. 5~ . i .¢' 75.663~ ~1.0585 17~. 234.1 5 234.152 0.~20114 1~ .65'¢ 72.5935 -2'1E.515 7d .46~7 0. CC 606 C 25{.013 637 - 5 'g. 38 5 -627.918 -59,3862 C .CCCC' OCE+OO C.OCCCOOE+O0 C.OCCC L!CE,OO 257 .. 2 2' 9 272.C2~ 57,241~ 48,5 ~ ';' 4 m ~ ~,.' 163,467 291,5 94 25C,945 475,~7~ 893 ,~ 01 236,~49 274,289 80.7C24 4'~;~ 2.4 81 36.4C08 48. ~ C 5 ~ ~8,$973 S. '217 77 1. 717 53 1967..8C 2474.36 23 ~C. 3~ 2297,35 1,854 1 ~ ] 7,4317 1 S 6. ~ ,41 156.~41 C 4.3C719 2. ':~ ~ ~ 1'6 ~22,ell 1,2~c34 44.59 29 ~3 .Z741 ~6.730C 14.E164 ~9.7104 232~ 23,26 2326 2326 232~ 2322 '2326 2326 2'32'5 23~4 232 ~ 23Z~ 23~d 2326 2325 23~ 232~ ~32~ 232d ~32{ ]326 2328 21~4 ~18'7 232'~ Z3'2~ 232[ ~3~ 23~6 ~3~ 23 '2{ Z32~ 'Z 3 ~ d 2326 2325 232~ 232~ 232~ 23E~ 232~ I I *'*'*** FILE HESDE2 ***~* ( 1) TCH .CC~ LC6 3214 LNKNCWN LCGIC~L ~ECO~C TYPE 224 LNKNCWN LCGIC~L ~ECCRC TYPE 22'7 LNKNCNN L06ICSL PSCC6C TYPE 227 9C/12/17 S~IFFED REC S~IFPEO SKIP2ED ~EC lC24 PR LNKNC~N LCGIC~L RECC~g I'Y~E 224 ,SKIPPED REC i' LNKNC~N LCGIC~L 'GECC~;C TYFE 227 SKIPPED BEC LNKNC~N LCGIC~L ~'ECC~D TYPE 224 SKIPPED LNKNC~N LCGIC~L RECC~C TY~E 2~7 S~IFPED ',~C ~ I~KN~WN LCGIC~L RECORC TYPE ~27 SKIPPED LNKNC~N LCGIC~L FECC~ ~YFE 227 ~IPP,GD REC L~KNC~N .LCGIC~L RECO~D TYPE ~2'7 SKIPPED ~EC ;~' LNKNC~N LOGICAL ~ECC~ ~YPE 224 SKIPFE~, ~EC L~KNC~N LCGIC~L ~ECO~ TYPE ~E7 ~IPPED L~KNC~N LCGIC~L ~ECC~ TYPE 227 S~IPFED ]~ L~KNC~N LCGIC~L ~ECO~ TYPE ;224 SKIPPED LNKNC~N LOGICAL ~ECCG~ I'YFE 2,27 ~IPPED ~EC L~KNC~N LCGIC~L R~CC~ TYPE 225 SKIPPED ~EC ~ INKNC6'N LOGIC~L ~ECO~ TYBE 2~,7 S~IPPED LNKNC~'N L~GIC~L RECC~ ~Y~'E 224 SK,IPP~D ~EC L~KN'~N L~GZC~L RECG~:D TYPE 227 SKI~PED '} LNKNC'~N LOGICAL ~ECO~D ~YPE 225 S~IPPED REC ***** INFORmaTION RECCRO ***** ( ~9) ***** DATA FC~NAT SPECIFICATION ~***** ENTRY ~LOCKS D~TA RECORD T3PE .................. O.~COOC~E+OC CATU~ SPECIF~(ATICN ELOCX TYPE .... :~TA ~RAME SIZE ............ - ........ L~/DC~N FLAG ...................... 1.COC~C CP'TIC~L LCG DEPTN SCALE UNITS ..... 1.COCOC DA, TA ~EFEB, ENCE POINT ............... S2~'.GCC CA. TA REFErEnCE PC'INT .INIT$ ..... --.- INCH F~AME SPACING .......... 6£,CCC£ FRAME SPACING U~ITS ................ .1Ih )AXI~bM FRA~E~/~ECOR~ ............... 3,CCCCC EEPTN RECCR~I~G ~CDE ............... 1,CCOC[ LNITS OF DEPTH IN D~l~ ~EEORDS- .... .1I~ ~EPR. CODE FO~ O~TPUI DEPTH ....... 73.00CC ~ATU~ SPECIFICATICN ELGCK SUE-TYPE 1.[OOCC D:A'TU~, DLOCK5 ~NEM SERVICE SERVICE UNIT AFI ID CRDER ~ TYFE CLASS led TON S 0 0 TIME TON MS 036 ETI~ lON S ~35 21 CS TOH F/H~ ~Z~ 21 ~IFF TON F ~6 lENS TON LE:F 615 D~RK TON F 150 1 GIRD I'ON NN/~ 0 0 I~DZ TON N~/~ O 0 IRDN TCH ~N/~' O ~IXD TON M~/~ 0 ZXDZ TON ~/F 0 O IXDP TOH ~F/~' C C IXDN TON ~?I~ 0 0 ~IRM TON M~/~ 0 C IRMZ TON ~M/~ C C IRMP TCN ~,F-/F C C I~MN TON FF/~ 0 C GIXM ICN NH/? C IXMZ TOH M~/~ C O I~MP TOH ~/F 0 C ]XNN TON ~/F 0 C ~CID TON ~i~i/~ C 0 CCIM TOH ~:~/~ 0 C IDQF TOH O O SIZE PRCCES~ LEVEL 4 E2OOCCCO£C 4 .ECCOCCOOEC 2 ~2OOCCOOCC ~COOC~COE£ ~COOCCO~CC ~CCOCCOCCC ~COOOCOOCC ZCOOCCCgCC EECOCCOOCC ~CCCCCCOCC ~CgOCCCOCC 2CCOCCCdCC OCCOCCOOCC ~COCCCCOCC ~EOOCCCCCC ECCOECOCEC ~CCCC~JCC ZCCOCCCCCC ~CCOCCCOCC ECCOCCCCCC ~EOOCCCgCC .~CCOCCCCCC ~CCOOCCOCC .~.CCOCCCOCC FCCOCCOgCC SAi~,FLE REPR CODE 7~ ~,8 49 49 ~EQF TON ~$FV } FVP $ FVZ ~ S FC TON ~ FCP ~CSF 'TON S F~F ~ SF~ TOff S FBZ TOH ~ FBP ~OH ~.F0 TOM n FOC lOH ~XF0 lOH ~ FOC loll 6SPR TOH SPAZ TOH S P .A P 'T O H ~ITE nOIH TOH IHV FTVP TOH FTVZ ~PSD TOH EPSD TOH PSD TOH IPSD TOH i ~ ~A TOH 2]RP TOH IRDA lOH 2IXP ~ODC TOH IWF1 TOH ]WF2 INDB 5VT ~OH 5VT TOH 2IV TOH 5VS TOH ECL TOH ECS TOH :ERS FRE TOH FBA TOH ]PBA TOH ]DP IMP IDPH I~PH TOH IRD IXD IRM TOH IXM IXD TOH IXM TOH ILD ILM TOM ]LD TOH ILM TOH ~RA ~LRA SFB TOM FV SFC 1CH 1,iV ~A MA, V V V V ~V ~V MV D EG C V V V V OH~t~ OH~ ~/~ ~I~' OH~F ~/F OH~ 0 0 0 0 0 O 0 0 0 ',3 0 0 '0 0 0 0 0 O 0 0 0 0 0 0 O C 110 110 120 1~0 0 0 G 0 '120 120 110 110 120 122, 12,3 0 0 0 0 CSFL TOH ~ iv, / F ,;'10 ~ FLU TOH ~ ~LA TOH ]TE~ TON DEGC ~R TOH G,APi 310 ~R TOH GAPI 310 STSG TOH ~TEN TOH LBF 0 FH'TE TO~ L~F 0 ~ RES TOH DTEM TOH DEGF 0 ~FTE TOH DEG~ 0 ~TEM TOH D~/K 0 'CTE~ TOH D'EG~ [CSW TOH 0 FV TOH V 0 ~ PA TOH MV 1 0 SPAR TGH P)~ 10 SPMV TOH NV 10 ~ F T 0 H ~ V 10 ( 7C) ***** DATA FCFi~A'T SPECIFICATICN ENTRY BLOCKS CATA ~ECORD TYPE .................... ~ATU~' SPECIF]CAT]C.N E'LOC~ TYPE .... ~ATA FRAME SI2E .................... IP/DOWN FLA~ ...................... CFTICAL LCG D~PTH SCALE U~ITS ...... ~A'TA ~EFEREhCE POINT .............. ~ATA REFErEnCE PCINT LNIT$ ........ ~RAME SPACIN~ ...................... ~'R,A~E SPACING UNI1S ................ ffAXI~UM F~A~ES/RECOR~ .............. ~EPTH RECCRDI~G ~ODE .... LNIT~ OF DEPTH I~ DAI~ RECORDS .... ~EPR, CODE FC~ C~,lPbl DEPTH ........ ,,,~TU~ SPECIFICATION :ELOCK SUB-TYPE O. CCOO¢C E+OC, 2~2 .aCC 1 .COOCC 1 .COOGC -5~E .O~C INCH 6C.GOgC 3.COOOC I .COOOC .i I~ 73.OOCC 1 .COOCC CATU~ BLOCKS ~kEN SErViCE lCD TCH l IME TOH ETI~, TCH CS TOH ~IFF TOH ~ ENS TOH )ARK IOH ~ERVICE UNIT AP CRDE~ ~ LO $ S F L2F F ~/~' ~/~ MD',/~ N ~ / F: h~/~ ~FI API AFI FiLE TYFE CLASS MOD NG. O O C S 6]0 21 O 6 6'.~ 6 21 C ~ 6]5 21 C 6 I ~ O I O ? 0 C C 6 C C C 6 O O C 3 0 0 G 8 O C C 6 0 O C 6 SIZE PROCESS LEVEL 4 8COOCCOOCC 4 8COOCCOOCC 2 ~ 7. CCCC OOC'C 8CCOC2C, CCC 4 ~coocccacc '~ccgccoocc 6ceocco~cc 4 accgcc~dcc 4 ~cooGcogcc ~cgocccGcc 4 2CGGCCegCC 4 ~COOOCOJCC 4 ~CCOCCCUCC 4 6COOOCOOCC 4 ECOOCCeOCC ~CC, OCCCOCC ~CCGCCg~[C ECOOOCCGCC eCCOGCS~CC ~COOCCCGCC ECOOCCOOCC ~CCOCCCOCC SA~' FLE 49 4'9 49 79' 49 49 49 · 4 '9 49 49 49 49 49 49 REP~ C'C' D ,F, 73 49 ~8 49 68 ,6,8 ~ C,'ID TOH i~CIM TOH IDQF TOH I~gF TOH g EQF TOH I~SFV TON S FVP TOH $ ~VZ TOH ~$FC TOH S FCP S FCZ TOH ,~CSF TOH ~ F',~F TOH ~ SFB TOH S FE~Z TOH S FOP TOH ~RFO ~ FOC TOH ~XFO IOH ) FOC ~ SPR TOH SPAZ lOH ~ F'AP TOH tq~TE '[OH R~IH TOH DIHV TOH FTVP TOH FTVZ TOH ~PSD TOH EPSD 'TOH )~FSD TOH IPSD TCH I ~ ¢,IA TOH ~ IRP TOH ! RDA TOH 2IXP ~CDC TOH I~F1 TOH I~F2 lOH ] hD'B lOH I 5VT TOH ~. 5VT TOH S ~IV TOH 1 5VS ~ECL TOH {;ECS TOH [:ERS TOH ! FRE TOH I F~A TOH 1P:'~ A TOH (IDP TOH C IMP TOH IDPH TOH I~PH I IRD TOH I IXD I IRM TOH. I IXM IXD TON IXM TOH C ILD TON C ILM TOH ILD TOH ILM TOH ~?,RA lOH (;LRA 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 110 110 120 120 G 0 120, 110 110 120 1;'0 120 S Fg "ir O H ~ FC TOH CSFL TOH CSFA TOH S FLU TON 5 FLA TOH 1TE~ 'ION ~GR TOH ~R STSG TON FTEN TON, I~NTE TON ~ R~S TON ~lE~ TOH /~ ffTE TOH i~ T L=. N TON ClEM TON CCSW ~SP TOH .cFA TOH :SPAR TOH ~P l'OH ~V 7 O ~A 7 ~P!/~ 7 210 ~/~ 7 210 OH~', 7 220 DEGC 7 O 0 GA:PI 7 310 '1 GAP! 7 210 1 ? 0 L~F ? 0 L~F 7 0 C OH~ ? 0 0 DEGF '7 0 DECC 7 0 DC/'K ? 0 0 DESC 7 ~'0 21 7 0 O V ? 0 NV 7 10 1 ~d V 7 10 t ,M ~ 7 10 1 NV 7 10 1 NV 7 10 I *****' FILE TFAILEt~ ****'* TCH .CC3 LCG 32.4 ****~ END LOgiCAL FILE 72 bNKNC~ LCEICAL RECORD 90/12t17 1024 PR 99~ LCGICAL RE,C06~S TYPES ZCCOCCC~2£C I 49 ECCCCCCOCC 1 ~CgOCCCOCC 1 49 ~CCOCCCOCC 1 49 ~COOCCOCCC 1 49' 3CCCCCOOCC 1 ,49 eCOOCCOOCC 1 ~CeOCCOOCC '1 49 ~COOC20OCC 1 49 64000000CC 1 49 ~£COCCOOCC I 7~ ~CCOOCOOCC '1 49 8CCOCCCOCC 1 ~COOCCOOCC t 49 $COOCCOOEC 1 ~4COCCOOCC I ~C08CC00£C 1 49 9CCOCIOOCC I 49' 9COOCIOgCC 1 '79 9000010~CC 'I 6CgO~gOCC I 49 8~00000CC 1 4'9 '~COOCCCOCC 1 49 ~COOC20OE£ 1 ~OOCCO~C£ I 49 2713 FRAMES RE~ F;~CIv, 9'05 2ECCRDS, COMPUTED F~A~E SPACINE: C.SOOC FT 271 ~ ~TA CH ,~EM SIC I lCD Z lIME 3 ETIM lOH ~ CS S DIFF TOH 6 TENS TON 7 ~RK TOH ~ RIRD TOF g I~9Z 10 IRDP TON 11 IRDN TCH 12 ~IXD TOH 13 IXDZ IXDP TOH IXDN TSF RIR~ TCF I~Z TCH IRMF IRMN TON ~IXM Tek IX~Z IXNP 'TCH I~MN TCF FRAME5 FRCM 14452.00 1HRCLGH '13096.CC RECCRDS 7 ~' THROUEP, 997 51ATISTiC5 FCN ~EPTH 130~6.0 TO 14452.C CLRVE MINI?liP PAXIPU?, N E~,h STD-DEV SAMPLES 1 0.34568]E+09 C.345655E+09 C.345884E+£'~ 526.~0~ 2 376.000 ~C74.00 657.03E 1,~6.4 2~ 3 9.6740( 17J2.54 916.014 526.50~ 4 18~.CCC 4564.00 2'701 .~4 401.70~ 5 O.OCCOCCE+CC C.COCCOC'E*Od O.CCCOCC~+CC C.g~CCOCE~Cg 6 EgTS.CC 7O~C.O0 6C7~.27 334.581 7 79.75CC [1.~750 ~0.5~27 0.559153 6 -542.0~C 144~.14 2~C.604 193.~47 9 -2~.972C 25.9127 -2].d54~ 1.01~.~C 10 1S5:~.4& 19.49. ~9 1~5.21 2.914~4 11 1~1.~9 1974.71 1ETC.E7 ~.024~E 12 -542.CCC 593~.77 -127.53d 345.~6d 1~ -5~.6777 110.731 -~.~241~ ~.7EE56 14 -2J7.73~ 377.Eb0 1~d.3E7 171.~69 15 !779.06 20~'~.7~ 1944.E] 15.5C55 1L -S?~.149 14q(.sV, 1~.570 309.197 17 -1~.2503 -1~.5546 -1,E.,~SE7 C.117~37 16 3~1 .E4 ~294.14 32E3.;~ 14.E]3~ 1'~ S2dO.C~ =299.57 ~271.50 14.39~C 2G -949.000 27~E.43 181.241 437.C~E 21 9. a 4,5 ~"S~ I. 6,4] 37 I ,. 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OgCC 3CE+ 1 .OCCOg 393C.0~ 153~.00 195C.0~ I 95 C 132~.00 561 1~61 Z'64~ .OO lgSC,OC 195C.~0 253~.0G. 17C3.00 195e.3C, I ~; 5 C. 6C4,COO 2.364'74 0.114914 0.11 ~ 1: C ,3 0.722447E-C1 ,~.~e354[ 1 5,9 3 d ~6 2.d154'$ 7.27457 12,22~2 O.?~5711E-C1 '1 C 7,343 0,, 364 ~16 E-'C I 6C ,515C - C.,,~5306C 0.936763 0.3137~1 32d .'~: 1~ -1 S. 04 E ? 97~ .44C 71.146[ ~'-j =.,C.957 249'.62~ 3 .?C'384 G. 1C7357 E-C '1 1 2.20512 1. ,~ 41 5C Z. 206 C E 2.207C4 2.~065'~ 4.54~ 2 .C30C4 4.193~7 4.d25C~ 2.35219 4.~ZllC 0.995945 ~,74~ 12?.5~5 2C.ggCC C.CCOOCCE*CC 1 .COOCC 317.5~C 8.513]~ 254,45e -21,5586 2c~ .o~ 222,555 45~,2~ 771.1~2 315.974 22.~ .~55 7.15595 3C.957~ -51.4111 C~.15~523 ,~731 89 1.32104 10,7552 .133 ~ 24 3.O~e, 72 C,75C51ee-0'2 .487C3CE-03 101[ ,61 ,. 1 87 ¢, · 68.62 O~ E'-01 .36C 5 54 6.427C00 .4 '7.~ 9 81 ,25~Z8C 0.47C990 .8~;~01 1.6C14~, 1,01 ~ 44 1.11266, ,27~492E-02 C.26~Cg5E-O2 C ,'27]C 43E-g2 .174~71 E-01 1,9~145 ,1779 5dE-01 0.5';C712 ~.12'~17~E-~1 O. 117C ~1E-01 0.1g~C44 ~'. 3 ~ ~ ~ 71 F.- ~ 2 ~O0.C5g 73 .~E 95 263.~46 e4. E '9 ~4 174.7~9 30~.~51 =15,;1~ 429.~01 799'.E~C EgZ.ES~ ~47.341 }4G.4ZZ 271 3 2713 '271 3 2713 2713 27 '1 3 2713 2713 2713 2713 2713 2713 :~713 271 3 2715 2713 2713 ~71 3 2713 2713 ,271 3 2713 2713 2'7'1 3 2713 2713 2713' 2713 2713 271 3, 2713 2713 2713 2713 271~ 2713 271]$ 271 3 2713 271 3 2713 2713 2713 ,?.713 2713 2713 2713 271 3 2713 27C8 271~ 1713 2713 2713 2711 2713 2713 2713 2713 2712 £713 2713 2713 2713 ",~0 S'FS 'TON ,0.2C,~ C 172.125 91 SFV TON -0.2~7 ~. 52.212~ 92 SFC ~OM 1.~4 5 tl. 9~ ~ 93 CSFL lOH 41.~ 5 94 C~FA ~CH 5C.3 ~: 32752.~] 95 SFL~ l'OH 9 ~.195 )E-C~ ~6 SFLA TOh 9~ 0.390 5E-02 97 ITEPI IOH 9 73.6 C 79.12DU 96 ~G~ ~OH 9 16.3 ~ Z73.25~ 99 E~ ~0~ 9 13.9 3 257.?50 "1C0 SISG TOH 10 17,6. C 17J.C00 1~1 HTEN IOH 10 -ZgC. C 536.500 1C2 ~TE TOH 10 -29G. C 536.500 1G3 ~RES lOH 10 0.2C2 ? C.274414 1C4 )'lE~ lOE 10 1S1. 5 16'7.~75 1C5 A~('TE TOH 10 ~6'.5 5 75.5COC 1~6 DTEN ~OH 10 -'~9~. C 226.~0C 1C7 CIEP~, lOH 10 79.1 5 ~4.CC00 1CB CCSW TOH 10 O.~CO C'E+GC (.OOCCOCE+CC 109 H~ ~OH 10 25C. C ~61.C00 110 RSP lON 11 ld9. C 111 SF,4 ION 11 25C. C 112 SPAR ~OH 11 -341. C -1~3.~25 113 ~FMV TOP 11 -~3~. C 114 SF TO~ 11 -359. C -162.375 END LOG]C,~L FILE - 2 7.10334 43~ .8~1 21E~.3C 2133.3~ 7~.~0~4 '?~.1d91 75.982C 17e.0~C g.~1767~ 1.~1.59C 71.99~5 -225.~31 g. CCGOCCE*CC ,255.04'? 2~C.971 34~.04~ -247.972 -53g.0~ 10.]401 401~.69 I · 7411 9 36.1~ '3~ 35. ~ ~ T 4 10,~.~ 106. ~ 6C .19C721E-01 5.~C~91 3.11~51 294.705 1. g ~ 5 ;~ Z g.OCCCOCE~OO 9~05 m LJ ~ ,~ ~6. ~ C 29 2'71 ~ '2713 2119 2117 ,:2713 271] 2713 2713 2713 271 3 2713 2713 2713 2,713 ,~ '713 2713 2 '71 3 271~ 2713 2713 ~713 2713 271 '] I I I *'**** FILE HE~DER ( 1) ?'CH .013 LOG 32.4 9C/12/17 L~KNC~N LCGIC~L ~.ECO~ TYPE 224 SKIPPED ~EC L~KNC~N LCGIC~L ~EC~£ TYPE 227 SKIPPED LNKNC~N LCGIC~L ~ECO~ TYPE 227 SKIPPED ~EC LNKNC~N LG'GIC~L ~ECCf~ TYPE 225 SKIPPED LNKNC~N LC. GIC~L RECO6~ TYPE 227 SKIP~Sg ~EC L~KN¢~N LCGIC~L ~ECO~g TYPE 227 SKIPPED ~EC LNKNC~N LCGIC~L RECC~ TYPE 224 S~IPFED LNKNCkN LCGIC~L ~ECC~ TYPE 2~7 SKIPPED 6EC L~KNC~N LCGIC~L RECC~g TYPE 224 SKIPPEO ~EC L~KNC~N LC~IC~L RECC~ TYPE '~Z7 SKIPPEO ~EC L~KNCWN LCEIC~L RECCRC TYPE 227 SKIPPED LNKNC~N LCGIC~L FECC6£ TYPE 225 ~KIPPED LNKNCWN LCGICAL RECCFC TYPE 227 SKIPPED LhKNC~N LCGiC&L ~6CC~ TYPE ~27 ~IPPED L~KNCWN LCGICAL RECC~C TYPE 227 SKIPPED ~EC L~KNC~N LCGICAL 6ECCFC TYPE 2~4 SKIPPED PEC C~KNCWN LCGICJL RECC6C TYPE 227 SKIPPED L~KN, C~N LCGIC~L ~ECCF~ TYPE 227 SKIPPED ~EC LNKNCWN LC~IC~L 2ECG~ TYPE Z27 S~I?PED L~KNC~N LCG~C~L 2ECC~ TYPE 225 SK!~PED ~EC 3C72 Z 3 7 9 1C 11 12 13 14 15 17 19 P~ ***** iNFCRP~TION RECC~;O ( E!C) ***** DAI~, FCRD',AT SPECIFiCA~ICN E ~TRY' SLOCKS ~ATA RECORD T~'PE ........ ~ATUY SPECIFICATICN 'ELOCK 'TYPE .... O,CCOOGCE+~G ~T~ FR~qE SIZE 434.~CC IF/DO~N FLAG ....... 1.COGCC C~TIC~L LCG DEPT~ SCALE U~ITS ...... 1.COGGC ~ATA ~EFE~E~CE POINT ~ATA ~EFE~:E~CE FGI~T LNITS ......... ~NCH ~RAME SPACING F~APIE SPACING U~ITS ......... ~AXI~M F~A~wES/RECO~B 7,CO0OC ~EPTH RECgRDIhG ffODE .............. 1.COOCC L~ITS OF DEPTH Ih DA1~ ~ECORD~ .... ~EPR. CODE FO~ C~I'PUI DEPTH 7~,OOOC ~ATU~ SPECIFICATION EL,OCK SU~-TYPE 1'.CO'CC :ATUN 6LOCKS tN,EM SERVICE ID · ~S IOH lOP loll TIME TOH ETIM TOM CS TOH DIFF TOH lENS ~OH D~RK ~OH ,~ERVICE CRDE~ ~ UNIT AP1 AFI ;~PI APl FILE LC'6 'TYFE CL,ASS ~OD NO. IN 3'1 262 I O 13 S 31 O G O 13 ~S ~1 ~'~6 S ~1 ~36 21 0 1S F/H R 3'1 6, 36 Z 1 0 I 3 F 31 ~36 21 0 LZ~F 31 ~35 Z1 0 1.~ F 31 1~0 1 0 13 I N 31 '2 ,~ O '1 O 13 IN 3t 2EO I 0 13 F3 31 2~2 1 V 31 3 54 O 0 13 V 31 3 54 0 O 1,3 'CPS 31 354 2 C 13 CPS 31 3~4 2 0 13 CRS 31 '3~4 2 0 CF'S 31 354 2 0 C~S 31 354 I C 13 CPS 31 354 I C 13 C P S 31 3 5.4 1 CRS 31 3~4 1 C F $ 31 3 5,4 1 0 1 3 CPS 31 354 I O 13 CRS 31 354 1 G 13 CFS 31 '354 1 G 1'5 CPS 31 354 2 0 13 C P S 31 3 5 ,~ 2 ~ 13 31 ~ ,,~4 V 31 354 0 C 13 V 31 354 O g 1'3 ~1 354 0 0 i3 31 3~4 g G 13 CFS ~1 354 Z C 13 CFS 31 354 2 0 13 CFS 31 3~4 Z ~ 13 CPS 31 ~54 CPS 31 3~4 1 0 13 C P S ~ 1 ~ 54 1 31 g 0 O 13 31 3~4 I C 13 31 3S4 I C 13 ~1 354 I C 13 31 354 1 31 ~5~ , I 13 I 3 ~/C~ :~1 3SG 2 ~/C~ 31 350 : n 13 S ! SA~FLE REPR C'O D E 49 73 66 4'9 4'9 4~ 49 49 4~ 49 /.,9 49 49 49 /-,9 49 79 49 49 LURH TOH hRHO TCH D~HO TOH CPHI TOH lNRA TOH ~TNR TOH ~CFT TOH ~CNT 1ALP TOH CFTC TOH CNTC lOH INPH TOH hPOR TOH hPHI ICH ~IIM lOH DEVI IOH ~E TOH SDEV TOH 'FNOR lOH ~INC 'TOH ~NOR lOH EADZ TOH EAT TOH SPT lOH GPV IOH ENV TOH ESW 'l'OH HAZI lOH F1AZ TOH ~X 'TOH AY 'TOH ~Z '~X TOH fY TOH fl IOH ~HGX TOH ~5N TOH ~W4N TOH ~3N TCH ~2N lOH ~IN TOH ~SGR TOH CHV$ IOH DHVF IOH hGPE TOH ****** DATU~ S~GT IPUW TOH 1PLW lOH FFUW lOH FPLW ~FUW lOH ~PLW lOH WSNG IOH ~4NG TOH ~3NG TOH ~2NG TON ~ING lOH 1HOR TOH LRAN TOH FOTA TON S~R TOH C~R ~TEN TOH 5LOCK,' G/C3 ,G/C3 G/C., V/V CPS CPS CPS V/V V/V V/V DES DEG DEG DEG OER DEG V DEGC OEGC V V DES DEG M/S2 M/SZ OER OER OER G/C3 CPS CPS CPS CPS CPS GAPt V V SIZE CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS PP~ PP~ GAPI GAPi L ,,'~ 6' 350 ~0 ..,"~ 56 4, 2 '0 4,20 4'2' 0 ~90 620 0 0 0 0 630 0 0 0 310 310 310 ~10 310 DOES NOT ZlO 31C 310 31 G 310 31G 31~ 719 310 31 G 2 C" 1 S ~ O 13 Z 0 13 2 0 1 3 1 0 1 3 I O '1,3 1 C 13 I C 13 1 O 13 d C '13 I 0 13 1 O 13 C O 13 0 C 13 0 0 1 3 1 0 13 I 0 13 1 O 13 I w~ 1 3 0 0 1'3 0 C 13 ,.,'q O 13 0 C '1 '3 0 C 13 0 O 13 0 C 1 3 0 0 1 3 C C, 1 'S 1 0 1 0 13 0 ~ 13 0 O 13 O, 0 13 O C 13 O C 13 0 C 13 I O 13 2 O 13 2 C 1 '3 Z C 13 2 O 13 2 C 13 '1 0 1 3 ~ C 13 0 C 13 ~- C 13 A6REE ~ITH 2 C 13 2 0 13 2 C 13 2 O 13 2 rJ 13 2 C; 1 2 C 13 I C 13 I C 1 C 13 i C 13 I C 13 0 C 13 0 C 13 0 O 1 3 I O !3 I O 13 C ¢' 13 68 6.5 6~ -?g ~E 6~ I SA~,!PL~S - SKtFPED ( 81) ***** DA'T~ FC:~'M~T SPEC'IFICATICN *'**** ENTRY BLOCKS CATA RECORD TYPE .................. ~TU~ SPECIFICATION ELOCK TYPE .... ~ATA FRAME SIZE .................... LP/DC~N FLAG ...... CPTICAL LC6 DEPIN S,C~'LE UNZTS ..... ~ATA REFERENCE POINT ~ATA ~EFE~E~CE POINT LNITS .......... ERASE SPACING ............... ~A:ME SPACING UNITS- ............... ~ AXIf~UM FRA~ES/REEOR~ ~EPT~ RECORDinG ~ODE .............. LNITS OF DEFT~ I~ bAl~ RECORDS---- ~EPR, CODE FOR CUIPU1 DEPTH ....... :ATU~ SPECIFICATION ELOCK SUI~-~YPE gATU~ ~LOCKS ~EM SERVICE ES 'TOH 'TOD "TOH lIME ETI~ IOH DIFF lENS TOH ,~ARK TOH ~CAL TOH ~ALI TOH ~NV TOH SHVD TOH LHVD TOH ~LLL TOH ~LLU TOH ~LUL TOH ~LUU TOH ~SLL TOH ~$LU TOH ~UL TON ~SUU TON LL TOH LU TOH LS lO~ LITH TOH ~$1 TOH ~$2 TON FARI TOH LSHV TOH SSHV TON FF$S TOH FFLS TOH ~LL TOH '~LU TOH nLS TON ~LIT TOH ~SS1 TON EER. VICE CRDE~ ~ UNil AFl 'TYF~ S 0 ~S 636 S 6]6 F/H~ F 6]6 LBF 6]5 F 150 IN 260 IN F3 "~. ~.2 V 35,4 V 354 CPS CPS C~S CPS Z5~ CPS CPS CFS CPS 354 CPS CPS 354 CPS 354 CPS CPS CPS V ~54 CPS 354 CPS ~54 CFS 354 CPs 354 C:~S 354 API FILE CLASS NO. 1 13 C 1 '3 2.1 13 21 '13 1 13 21 13 1' 13 1 13 I 13 1 13 O 1.3 0 13 2 13 2 13 ~. Iz 1 13 I 13 1 1 13 1 13 I 13 1 13 1 2 13 ._'2 13 Z 13 ~ 13 ¢ 13 0 13 0 13 T: 13 13 ,,. 2 13 1 1'~ SIZE PROCESS LEVEL 2 4 ECGOCCOOCC ~COOCCOOEC 2 ~2OOOCOOCC 4 ~CCOC'20OCC 4 ~CCOCCOOCC ~CC0OCOOCC ~CCOC200CC 8400CC00CC 2 ?4COCCOGCC 9CO0C200CC ~C¢0C2OOCC 8CC00208C6 6C00C20OCC ~CO0C20OCC 2 8C00CEOCCC 8COOC2OOCC 8CCOE2OCCC 8C006200C£ 2C00¢20~£C eCCOCCOOCC eCOOCCCOCC 8CCC6CCGCC eceoccoocc ~ccocccccc ~4ooc2o3cc ¢cco62ccc¢ ¢c0oc2oocc 3ccoc~ooEc [CCOC~COEC ~CCOC2COCC 3CCOC2COCC 3CGCC~CGCC 5CCOEECOCC SCCOC2COCE SA~FL:E 49 49 49 49' 79 REPR ~CDE 73 49 49 .4 ~ 49 49 49 49 4~ 49 49 49 49 49 49 4~ 4g 49 49 49 49 4¢ 4g EF 1RH HOB RHO PHI NRA TNR eFT £NT ALP FTC NTC NPH PHi ZIM EVI DEV NOR ADZ AT ~T FV ~W 1AZ Y X ¥ Z HGX ~3N ~2N SGR HVS HVF ~PE ~GT ~UW PLW PUW PLW PUW PLW 4NG TON TOH TON TON lOH '1' OH TO H TOH 1'OH TOH ~0~ TOH TOH TON TOH ~0~ TON TOH ~OH TOH 'TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH TOH AT~JF G/C3 G/C3 G/C3 ~/C3 ~/C3 V/V CFS C P $ CPS CPS V/V V/V V/V DEG DEG DEG DES OER DEG V DEGC V V D E G D M/S2 ~1S2 OER OER G/CZ CPS CPS CPS CPS CPS GAPI V V SIZE CPS CFS CPS CPS CPS CFS CPS CFS 354 35O ]50 ~ 50 350 35O 42O 42O 420 ,S 90 · 420 690 690 ~0 ,~ 3 '1 0 0 O O 0 0 0 0 0 310 31~ 310 310 310 31~ 0 0 310 DCES NCT 31 g 310 31~ 310 310 310 ~10 31 n '1 1 '2 2 1 I 1 1 1 1 C 1 1 .0 1 t t 1 0 0 0 0 1 1 0 :0 0 1 2 1 0 ~2 22 22 1 1 0 C O 0 0 0 0 0 0 0 O C 0 ¢ 0 C 0 C., G 0 0 F' ¢ C C C: C C 0 ? ¢? 1L]Of3 C OOC C Z' ,"~ 4 COC C O3C C 2 :~4GOCCOOCC 4 ~2~0C200CC 4 [~40CCCGC£ 4 ~240CC00CC 4 '8240CC00CC 4 ~COOGCOOCC 4 ~COOCCOOCC ~ ~COOCCOOCC ,4 eCOOCCgOCC 4 6CgOCCOOCC 4 ~COOgCOOCC ~COOCCOgCC 4 ,3CCGC100CC 8COOC'~OOCC 4 8C00~100CC /COOCIOOCC 2 ~CCOClO'OCC 2 ~C¢0~100CC ~CGOCCOGCC 4 ECgOCCOOCC ECOGCCCGCC '~CCOOCOOCC 16 ~C~OC£~OCC 16 ~CgOCC~OCC 16 16 .4 4 4 2 ~EFF. 4 4 49 49 4~ 49 9 ~8 6e, 49 ~9 AND -79 I SAMPLES SKIFPE~ ~3NG TOH 310 ~2NG TON 310 ~ING TON 310 TNOR TOH 7'90 LRAN TCN 79~ FCTA TOF 719 ~GH TOH GAPI 310 CGR TOH GAPI 310 NTEN TON LBF 0 ~NTE T'OH L~F 0 ~RES TOH OHMS. 0 MTEM TOH D6GF 0 ~TE TON ~E~'C 0 gTEM TOH DC/K 0 CTEM TON DEGC dEO CCS~ TON C NV TON V 0 4 4 ~2COCCOOCC 4 ~2~GCCC~CC .4 ~dOOCCOOCC ~,dCO~COOCC ~CgOgC~gCC ~CCOOCOOCC 2 ~CCOCCCOCC 2 ~COOCCC'O.CC ~4OOCCCgCC ~CO0OCOOCC 2 ~CCOC1COEC ~CCOClOOEC 2 ~C00CIC~£C FILE. TF~ILER · 013 LC6 32.4 '9C/12/17 3C72 P R ***** END LOGZCAL FILE 4C3 97 L~NO~N LC"EICAL RECORD TYPES LCGIC,~L RECORDS 1999 FRAMES RE~ FRCM 2~ RECCRDS, CC~P~T:ED F~ANE 1 '999 [,.~'IA FRAMES F'RCM 143.d7.5C .THtiC~GN 13~68.5C RECC ~I,~.TISTICS FOR DEFTH 1~'~dS.5 TO 14]'d ~ . 7.5 C. 50C'C FI CH ~E~ $I~ I ES 10~. 2 TOD 3 TIME TON 4 ETI~ TON 5 CS TON 6 DIFF TOff 7 TENS 'TON' ~ ~mARK TON, 9 RCAL TON 10 C~LI TOH 11 IHV TO~ 12 S~VD TOF 13 L~VD 14 ~LLL 15 RLLU l& ~LUL TOH 17 ~LUU TC~ 1~ ~SLL 19 RSLU TOF 20 ~SUL TOH 21 RSUU TON 22 LL TON 23 L~ TOH 24 LS TON ~5 LITN TOH 26 SS1 TON 27 SS2 TON 2~ P~RI 29 LSNV TO~ 30 SSNV TON CLRVE MIflIF.~ PAXI~'.UM ......... ~ ~"6E+~ C,'~4 7OS.GCC 171d,00 I .71~C I 974.75 O.CCCCCC;',OC C.GOCCOGE+OC O..CC 3340.6C 9 585. OC 691 8d. Z 5CC 87.81 2S ~7. d.C7813 21.71~E 7.~ 8.265~3 21.7500 9.~ O.OCOOCCE+CC 547.C00 235 1219.C6 I 222.00 I 22 1185 .CC 1171.0C 11 13.77Z4 E4.~125 32. 1QZ.gZE 204,(2~ 14~ gd.d25C 1~3.~5C 1~ O.dCOCCCE+OC 18.cC63 5,3 2~,25C6 205.~7~ 11C 1C1. 87~. 229._~7"_, 172 92,~75C 183.750 141 0.983887 43.2185 17. 4d..~Z5C 460.250 117.f;25 738.500 1C=.43E 769.509 274 10.4922 149.250 62. 53.2~13 E4~.COO 191 ~1.3125 383.250 274 O.CCOCCCE~GC E.COCCOO~OC C.CC 1 'led. C [ 1171 .CC 11 121 ~.CC '1 222.00 1 -C.1~5547 C.191~95 -O.2C COCC 5895 E+C ~ .871 .23C 7.44 OOGC E+E C I .14 0837 7211 1152 .7cd C.~1 829? ,0[~ .71[ 2C¢5 .733 .84E 2CIE ,17~ COCCE~CC C 3715E-C~ STD-D EV $~ ~' P,LE S O.OCCCOCE+O0 1999 46.1~ 5~. 19'gg 574.4 8.5 I 999 ~ 9. d.4 86 1 999 .OCCC'OGE+CO 1999 49~.55~ 1999 .4~7 Z~ 1999 2. 3514E 19~9 ~.C~'~5C 1999 145.~17 1999 ~.7E~51 1999 1~.E~57 1999 12.~C 1999 2.d~C87 1999 ~.~7 1999 15.21 5C 199~ 12.~93~ 19~9 5.37345 199~ &2.]487 19~9 ~ '.7~35 1999 76.~444 1999 21 .]]CC 1999 27.=217 1999 3~.~]02 1999 C.OCCC OCE+CC, 1999 1.C5787 199~ C.64[73C 1999 C.4'714 ~TE-01 1999 ~S$1 ~SS2 SLDT ~LS ~L$ ~$S ~EF $1RH LSR~ L~BH D~LP D~HI T~RA RTNR ReNT TALP CFTC TNPH NFOR A, ZI~ B~VI SD~V FNOR FINC O~OZ ~T G~T H~ZI P~AZ FX ~GX ~5~ ~4~ R~2N ~GR CkVS DHVF ~PE TFU~ TFL~ ~FUW ~FLN T OH TOH TOH TOH TGH TOH TOH 'T 0 H TOt~ TOH 'T OH TOH 'T TOH 'T OH TOH TOH 'TOH TOH TOH TOH TOP, 'TO~ TOH TOI~ TOI~ TO~ TOH TO~ TO~ '[OH TOH TOH TOH TOI~ TOI.4 TOI~ TOH TOH TOF TOF TOk TOH TOH 'T ,0 ~ TO~ TOH TOH TCF TO~ TCH TOP' 47.3439 e3. 3438 17.00CC O · 51959C 0.55.:!31 C 5 -0.7d I 7 lg E-C1 -0.1~335 2.332C3 1.1~d13 1..~25~C 0.8~4941 -1. ,~ 3521 -0. 231 33 5 1 I. E' 0 G C C 3C4.d~ 0.,570177 554.731 1411 .~,~ O. 1 (9CdC 0,1485E9 3.9'15~ ~2.32~2 0.5C 1 27 Z 7 .'~j 97 79.05C8 14.7~ -14'.82C3 24C64.~ 8.~5~1 ~ ~ .79C~7 ~ .ET~C~ 4.2~C1 -1.178C5 -0.d32151 -1.158!4 O.CCOCCCE+CC O.CCOCCC~*OC 6.E,5275 Z5.21C1 ~].C O.CC~CCCE*O( 1 55 2 ,]. ~C O~C C ~+OC 253.375 394.C00 17.CCOC C'.74~582 · ~0,5203E-01 C.922~52E-01 4Z.9C63 4 .~9~44 3.17188 3.25E81 .6'76 i 0 '9 3.03170 ~. 1'3 'L~ 44 ~ ~.541449 4 5. 02778 2047.31 4,42~. 19 1.3~535 2077.10 412~.69 .571 t 06 C.52Z300 ~44.181 4'2.7C30 318.539 I. 1 -C.5~3~E-~1 7~ '~4.4Cll 14.~C47 -14.'7~ 6~, 344.1 ~1 8.7137~ 4.~99~1 12.2~3 1 .7~93 I .1E¥7~ 3.27930 3~.~1~ 49.C196 155.~12 ~3.~19 $47.47~ 28c .~79 15~5.~0 1 ~.32~11 E .57E~ 191 27 17 i.,j ,m ~' C.1 0,7 4. 2 ,, £, 0.1 0.1 £, 1.17e 4.31~ .OOeC 19151£-C2 5403~E'-C~ ~78~9 4~9C9 4562C ~'7175 4,4512 29011E-£1 444a3 23434E-£1 2434~ 3.07973 932.375 I .C3225 95 O.Z 35 37 17 37 0.~' 77 -C.6 70 14 - 1,4, 24 35 21 5. 7. O.g 0.1 9. 9. 44 13 9C O.C 15 C.5 1. 9. 4.831 25721 2~174 2,4331 .239] .E954 .89.54 25327 744~g 1~894E-Cl ·02'19 .7~d] .'7~43 .77~5 C~4.C .2393 C.723 374[,2 ~755< 2~37~E-C1 4~162 210~4 .5993 5.9C1 C.36e .2395 CC~CC[*CC 5~.~2 ~795~ .<}617 2 ~',. 3'? 4,7 ' 41'.. 5'~. 5.~ C.OCCCOGE+O,O G.19ES14~-01 O. 271~ ~ E-01 g .1 9,5~,67 E-gl C. 271~ 1C E-01 3.01508 O. ,41121 '7 O. ! 7],~ 06 0.175~03 C .33~411 C',.1356 5~ C .9021 ZSi- 01 C.53~846 C.57E499 ~99.12~ ~ 53. ] 92 0.88371C E-gl ~Z1.7 24 C.744263E-01 C.76CTC7E-01 0.7 74~ 7~E-~1 1~.~136 4.d, 4~15 17.450C ,4. 64215 6.4~22 25E'-01 O .'27~492 C .137514E-OR ~ · 18'1 94 4.5]278 C.12]~35E-01 0,,134401E-01 6,'12E4 24E-02 18,513d 25.5C~2 0 C.31~C53 6.132995 C.857224E-01 ~,1~E¢53 C. 1 044 ~3 4.4140~ 22.¢799 ~7'.~57~ 147,~4~ C .OCCCOCE+CC 3. ~C~ 4C ~.~346~1~-01 5 · 5~ [ 76 1999 '1 1:999 1999 1999 1999 1999 19~'9 1999 1999 1999 1999 1999 1999 1999 1999 199~ 1999 1999 1999 1 999 1 '999 1999 1999 195'9 199~ 1 9'99 1999 1999 1999 1999 1 999 1999 1999 1999 1999 1999 1999 1 999 1 999 79~ 7996 799~ 7996 1999 !999 1999 1999 1999 1999 19~9 19.c, 9 1999 1999 I 99 $ 1999 1999 199,9 1C4 WPNG TOH ~-5.21C1 423.]19 1C5 ~ING 3OF. 63.0252 '~47.479 106 THOR TOH 0.3~7~5~ 26.3~7~ 1C7 ~RAN TO~ -2.~16~7 ~1.4~43 1C8 PCTA TOH 0.1394~E-0'~ C.461".~79E-01 1 C9 110 111 ~TEN 112 ~:HTE 30H -575.5CC 2276.00 113 MRES TOH 114 FTE~ TCH 15,6.~Z5 171.'~5~ 115 AF. TE 116 ~EN ~CF -99~,5CC 596,C00 117 CTE~ 118 C~SW TOH 119 135,901 ~.731ZE ,1'~1 8C:f E-£1 8~,~5fl 6~.908~ ¢],~Cf77C. -£5~,~37 ~C:~6.CC [7,]579 1 47., '~ 4 S 3,3471 9' ],94171 0,'~21C 30E-02 43.5573 24.C3 ~Z9 231 .]76 ~31.]7~ 4.64760 ~. 5E~04 1 .gEE 61 '-0',637 ~,52E'- 09 1.353 75 1999 1 19'99 '1 999 1999 '1 999 1999 1 999 1999 '1 999 '~ 999 56,4 1999 199'~ ! 999 I I ***** FILE HE~DER ***** ( 1) TCH .'~1'7 L'CG 32.4 9C/12/17 3C72 LkKN¢~N LCGZC~L RECOF~ TYPE 224 SKIPPED ~E¢ 2 LNKNC~N LCGIC~L ~EC¢~ TYPE 227 SKIPPED ~EC 3 LNKNCWN LCGIC&L ~ECO6~ TYPE 227 SKIPPE~ ~EC 4 L~KNC~N LCGIC~L ~ECC~ TYPE 225 SKIPPED ~EC 5 LNKNCWN LCGIC~L RECC~ TYPE 227 SKI~ED ~EC 6 ***** INFCR~IION RECCR~ ****~ L~KNC~N LC~IC.~L ~ECO~: TYFE 42 $~IFPED 6EC 23 L~NC~N L~GIC~L RECC~C TYPE 42 S~IFPE~ ~EC 24 L~NC~N L~GIC~L R6CO~ TYPE 42 SKIFPED ~EC 25 LhKNC~N LCGIC~L RECOF~ TYFE 42 SKIPPED aEC 26 LNKNC~N LOGICAL ~ECO~ TYPE 42 SKIFPEg ~EC 27 L~KNC~N LCGZC~L RECO6~ TYrE 42 SKIPPED ~EC L~KNC~N LCGIC~L ~ECC6C TY~E 42 SKZPPED ~EC 29 LNKN¢~N LCGIC~L ~ECOF; 'TYPE 42 SKIPPED FEC 3C L~KN~WN LCGIC~L ~ECO6~ TYFE 42 SXIPFED LNKNC~N LCGIC~L RECC~C TYFE 42 S~IPPED ~EC 32 L~KNC~N LCGIC~L ~ECCF~ TYPE 42 S~IPPEO ~EC 3~ L~KNC~N L~GIC~L RECCFC TYPE 42 SKIPPED FEC 34 LNKNCbN LCGIC~L 2~CC~ TYPE 42 SKZPPED 3~) ** NTRY BLOC ATA ~ECOR ~TUM SPEC ATA FRAME P/DC~N FL * ~,AT.~ FCR~AT SP6CIFICAIICN T~PE .................. '[.C.~i'iCN BLOCK TY.,~E .... O.CCOeCCS+OO 434.CCC 1.COCCC P~ PTIC~L LCG DEP'TH SCALE UNITS ..... ATA REFE'~ENCE PCINT ~TA REFERENCE PCIN'T LNITS ........ RAME SPACIffG ....... ........ ~AME SPACING UNITS AXIffUff F~A~E~/~ECORg EPT~ RECCRDIbG ~CDE .............. kITS OF OEFT~ Ih DAT~ RECOR~ .... EPR. CODE FOR C~TPU1 D6PTH ....... ~TUff SPECIFICATION ELOCK SU~-TYFE ATUP BL NEM SER I ~ lOH OD lOH IME lOH TIM TOH S TOH IFF TO~ ENS TOH ARK TOH CAL TOH ALI TOM NV HVD TOH HVD IOH LLL LLU TOH LUL TOH LUU lOH SLL IOH SLU,TOH SUL TOH SUU TOH L U TOH S IOH ITH S1 IOH S2 TOH ARI TOH SHV SHV FSS IOH FLS ~OH LL TOH LU TOH LS TOH L~T TOH SS1 TOH SS2 TOH LDT RLS TOH RSS TOH LS TON SS TOH EF TOH 1RH TOH SRH ~RH lOH RHO ALP lOH HO~ TOH RHO PHI lOH OCKS VICE EERVICE UNIT A D CRDER # L IN $ $ F L6F F IN IN F3 V V C P S CPS CPS CPS CPS CPS CPS CPS C P $ CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS 6/C3 G/C3 G/C3 G/C3 G/C3 Git3 G/C3 V/V -1'7.0 INCH .lIN 1.C0 .1ih 1.C0 AFI ~PI A I'YFE CLASS 262 1 0 O 6)6 21 6=6, ;21 6,35 21 63 ~ 21 6~5 21 150 1 280 1 2~G 1 2~2 1 354 354 2 354 2 354 2 ,354 354 1 354 I 354 1 354 1 354 1 354 1 354 1 3)4 2 354 2 354 2 354 C 354 O 354 354 0 354 Z 354 3,54 2 354 '~Z 3~4 1 3~4 1 0 C 354 1 354 1 354 1 35J 1 350 2 350 2 35C Z 350 2 356 1 ~93 1 0¢C FILE, NO. 17 17 17 1'7 17 17 1'7 17 17 17 17 17 1'7 17 17 17 17 17 17 17 17 17 17 17 1 ? 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 17 I7 17 17 17 17 17 SAF, FLE REPR CODE 49 73 49 49 4g 49 49 49 49 4~ 49 49' 49 49 49 49 49 49 49 49 49 49 49 49 79 49 49 49 49 49 49 1NRA ~lNR ~ OFT FONT 1ALP CFTC ChTC 1NPH hPOR TOH I'OH l'OH TOH ~PHI lOH ~ZIM ~EVI ~ lOH EDEV FNOR lOH FINC lOH ~NOR !OH ~ADZ TOH 6AT TOH E)T I'OH EPV TOH ENV 'TOH ESW lOH F~ZI 1'0~ FIAZ ~X IOH ~Y ~Z FX TOH FY lOH FZ ~HGX TOH ~WSN lOH ~W,4N TOH ~W~N TON ~WZN ~IN lOH ~SGR CHVS lOH OHVF lOH ****** DAlU~ lPUW TOH TPLW IOH FPUW TOH FPLW ~PUW TOH ~FLW IOH ~5NG IOH ~4NG TOH ~NG ~2NG lOH ~ING IOH 1HOR TOH LRAN FOTA lOH SGR DER TOH FTEN TOH ~HTE TOH )RES lOH ffTEM TOH ~YTE lOH ~TEM TOH ClEM ELOC~ CF'S CPS CPS CPS V/V V/V V/V DEG DEG DEG DEG OER DEG V D EGC D EGC V DEG DEG M/S2 OER OER OER CPS CPS CPS CPS CPS GAPI V V SIZE CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS CPS P PM GAPI GAPI L'6F OHMF DEED DC/K D E,~(C 4 ;2 O '1 C 17 420 I C 17 &20 I 0 17 4.20 1 0 17 E' 90 0 C 17 420 I 0 17 42.0 1 C 17 ~ ~'0 0 0 17 890 0 0 1 '7 690 C; 0 17 630 I C 17 '~20 I O 17 ,631 I C 17 6 20 1 C 17 0 0 0 17 0 O 0 17 0 3 0 17 0 O 0 17 C) 0 0 17 0 0 O 1 7 0 0 0 17 0 C 0 17 0 0 0 17 d~O 1 0 17 630 I C 17 0 0 U 17 0 C 0 17 O 0 C 17 0 0 C 17 0 0 0 17 0 0 0 17 ~'7:5 1 0 1 '7 310 Z ,3 17 310 2 C 17 ]10 2 O 17 31 '0 2 C 17 310 2 0 17 310 1 C 1 '7 O iI C 17 0 0 0 1'7 310 22 LQ 17 DOES kO1 A6~EE ~ZTH 310 22 0 1 7 310 22 C, 17 310 22 0 17 310 22 C 17 ZIO 22 C 17 310 22 C 17 310 22 C 17 310 I O 17 310 1 O 17 310 1 C 17 ~1~ 1 C 17 310 I C 17 790 56 C 17 7~;2 50 O 17 71 '~ 50 O I 7 310 I C 17 310 I O 17 O C C 12' C C C 17 0 C 0 17 0 O t 17 C C t 17 0 3 S 17 d 6:: ,3 21 '"' 17 E;440CCCOCC E.C 40C20C)E C ~C.40C2.00C C 8C40C~:00C6 ~:20002COCC [~40¢C30CC ~; e 4. FJCC OeCC ,~24006C066 3240CCOCCC ~2400CCOCC' ECCOCCOOCC '~:.COC)OC SOO C .£CCOOCOOCC 8CCOECOOCC ,CCOCCO0£ C 8COOCCCOCC JCOOCCOOCC 5CC, OG1COC C 8(:C)OCIOOC C (;COOCICC, C C 8CCOC..IOOC C ,~;COOCIOOC C ~CCOC1COCC ZECCCCOOCC 8CC!OCCOOCC ¢JCOOCCOOCC ¢.CCOCCCOC C 8CtDOCCO'dC C ".~:J C O. OOC CdC C ,!:!COOdC OOC C 8COOCCOOCC ;S'100CCOOCC .~: C CO(32. OOC C ~CCCOC~OOCC 8CCOFJ20CCC 8CCOC200CC 8COOC2COEC ~006200EC ~COO0100C C ",;COOCIOOCC 8CCOC10C£C CODE 79 SIZE ~COOCIOOEC 6'.C00C100CC ECOOCICO£C ~COGCIOOCC ~COUCIOOE£ ECOOClOO£C ~2CCOC100£ C ~COOCCCC£C ,3CCOC£CQCC ~COOCCOCCC ECCQCCCOCC ~CC'JCCOOCC E2COCCOLICC E~COCCCOCC ~2nOCCOOCC '. _ E~COCCCOCC ~.~COCCOCCC FCOOCCOgCC 8ECCCCCCCC 8CCOCCOOCC aC CUCCOGC C ~4COCCCOCC ,-~C OOCCCCC C ~CCOC1CCCC (::8 68 6',,.. 68 49 '79 6'8 68 68 68 4~ 68 68 68 49 2 -79 ~8 4~ 4S 49 I SAMPLES SKIFPED ( ENTRY ~ATA R ~ATU,~ ~A'TA ): LP/DCWN CPTIC~L EATA KEF DATA ~EF F RA~E SP F ~AME SP C EPTH RE ~ITS OF ~EPR. CO ~ ATU~ SP ) *'~*'** DATA FC~iAT SPECIFICAIICN ~LOCKS ECO~D TYPE ................... SPECIFICATICN ELOCK "TYPE ..... RA~E SIZE ................... FLAC .... LCG DEPIH SCALE U~IT~ ..... ~ENCE PCINT E~EhC~ PCINT l~ITS ........ ACING ..................... ACIN~ UNIIS ............... FRA~ES/RE!~OR~ .............. CCRDI~G ~CDE DEPTh I~ DAIA RECORDS .... DE FO~ OtlPU1 DEPIH ....... ECIFICATICN ELOCK SU~-TYPE O.CCOCGCE+OC 434.0gC I .COC~C 1 .,COOCC -17.00CC ]NCH 6C.OGOC .1Ih 7,C000C 1,COOCC ,1I~ 7~.000C 1,COOCC ATU~ BLOCKS hEM SERVICE .~ERV)CE U~iT API &FI ~PI APl FILE ID CRDE~ # L~E TYPE CLASS ,MO~ NO. $ TOH IN 31 282 1 O 17 CD TON S 31 C 0 O 17 IME lOH ~S 31 6~6 21 0 17 TIM TCH S 31 626 21 ~ 17 S TCH F/H~ 31 636 21 C 17 IFF l'CH F 31 6~6 21 0 17 6NS TOH LSF 31 635 Z1 0 17 ARK TOH F 31 I 50 1 O 1 CAL TCH ~N 31 2~0 1 0 17 ALI TOH IN 31 ~EO I 0 1'7 HV TCH F3 31 2~2 1 0 HVD TOH V 31 354 HVD TOH V 31 ~ 54 0 O 17 LLL IOH CPS 31 354 ~ ~ 17 LLU TOH CPS 31 3~4 2 0 17 LUL lOH CPS 31 35~ 2 ~ 17 LUU TOH CPS 31 354 SLL TOH CPS 31 354 1 O 17 SLU TCH CPS 31 354 1 C 17 SUL IOH CPS 31 35~ I 0 17 SUU lOH CPS 31 35~ I 0 17 L lOH CPS 31 354 I 0 17 C lO~ CPS 31 35~ 1 0 17 S IOH CPS 31 354 1 ~ 17 ITH lOH CPS ~1 354 I C 17 S1 TOH CPS 31 354 2 O 17 S2 lOH CPS ~1 354 2 C 17 ARI TOH 31 3~4 2 O 17 SHV TOH V 31 354 O 0 17 SHY TOH V 31 354 0 0 17 FSS lOH 31 ~54 O O 17 FLS TOH 31 354 LL lOH CPS 31 354 Z 0 17 LU TOH CPS 31 364 2 ,S 17 LS TOH CPS ~1 354 2 ~ 17 LIT IOH CPS 31 354 2 C 17 ~$1 TOH CPS 31 354 I C 17 SS2 TOH CPS 31 354 1 LDT TOH 31 O 0 C 17 ~LS lOH 31 554 1 ~ 17 RSS TOH 31 354 1 C 17 LS TOH 31 ~5~ 1 C 17 SS TON 31 35~ 1 [? 17 :SIZE S,A~FLE REPR CCDE 49 73 49 49 49 49 49 49 4'; 49 49 49 49 49 ~ 9 49 4~ ,;9 7~ ,4 q I I I I £F T~h UP, H TOH ~HO lOH ,~LP ~HO PHI TOH NRA TON TN~ lOH CF'T TOH CNT tOH ALP TOH FTC lOH ~TC lOH hPH POR PHI lOH ZI) lOH E V I l 0 H DEV ~OR lOH INC TOH ~OR lOH ADZ AT ~T PV ~V TOH SW lOH AZI lOH 1AZ ) TOH Y lOH Z IOH X TOH Y TOH Z TOH H~X lOH WSN lOH WAN TOH ~)N TOH ~2~ IOH Wi N 'TOH HVS lOH HVF GPE lOH ***** D NGT PUW TOH PLW PUW PLW PUW lOH PLW lOH 5NG lOH 4NG lOH 3NG lOH 2NG lNG HOR lOH RAN CTA ATUP ELCCK .G / C S G/C 3 ,S/C3 G/C3 ~/C3 6IC) ¥/¥ CPS CPS CPS V/V V/V DEG DEG D6G DEG OER DEG V DEGC DEGC ¥ V DE8 DEG M/S2 ~/SZ OER OER OER G/C3 CPS CPS CPS CPS CPS GAPI V V SIZE CPS CPS CFS CPS CPS CPS CPS CPS CPS CPS CPS PP~ ".~ 58 1 O 17 750 2 C 17 3 50 2 C, 17 35..0 2 C: 17 3. 50 2 L~ 17 ~ 17' ]50 2 O 17 35 a 1 C 17 ~90 I 0 17 420 I Lq 17 420 1 C 17 420 1 O 17 420 I C 17 ~,90 0 0 17 42C I O 17 ~20 I rd 17 ~.90 0 0 17 ~90 O 0 17 ~ 90 '0 C 1 7 630 I O 17 620 '1 0 17 6.~ 1 I 0 17 6.~ t,q 1 C 17 0 C 0 17 O a g 17 0 g C 17 0 0 0 17 0 C C 17 0 0 O 17 0 0 LO 17 0 0 0 1 '7 630 I C 17 630 I 0 17 0 0 C 17 0 O 0 1'7 0 8 O 17 0 0 C 17 O 0 O 17 0 C O 17 ~.75 I C 17 3'10 2 e, 17' 310 ?. C 17 310 2 g 1'7 310 2. C 17 310 2 C 17 31 0 1 0 17 0 C C 17 0 0 0 17 310 22 C 17 DCES kO1 AC~EE ~ITH 310 22 C 17 310 22 C 17 310 22 C 17 ~10 22 C 17 31U 22 C 17 ~1 0 22 0 1 7 310 2~ (~ 17 31Ll I C 17 Zlg i C 17 310 1 0 17 310 1 C 17 310 I C 17 790 50 0 17 792 5C C 17 71g 50 O 17 4 4, 4 4 4 4 4 4 4 4 2 4 4 1 6 16 16 16 2 4 4 4 REF~ I SANPLES - SKIFPED r,.6R F'1EN TON HTE RES TOH T5M TON ~EM TOH (TE~ TOH 'CCSW ~V TOH LNKNOWN vAPI 31 310 1 7 GAF! .31 310 I 7 L.SF 31 O 0 7 2 ,~C~OCC~CC L~.F 3t O (j 7 2 ,~COOOCOOCC OH~ 31 O ~ 7 2 ~COOGCOCCC DEGF 31 0 C 7 ~ ~COOCCOOCC DC/K 31 0 G 7 Z '~CGOCCCOCC DEGC 31 ~0 21 7 2 9CCOCIO, OC'C 31 O 0 7 2 ~'COOC lOO,C C V 31 0 O 7 2 ~COOC'lOOCC LCGIC~,L RECC~ TYPE 227 ~KiPPEO ~EC 3 LOGICAL ~,ECO~ TYPE 227 ~KIPP,EO REC 3 ***** FILE T~iLER TCH .017 LC6 32.4 9C/12/17 3C72 PR ***** END LOGICAL FILE 1~0 LCGIC~L RECOE~S ***** 41 ~NGW~ LC~iCAL RECORO TYPES 692 FR~P.:.ES RE~ FRCf~I 99 RECCRD,~, CCFPUT~D FRAME SPACINg= C.SOC[ FT 692 ~A]A FRAPE~ FRC~ 139~5.5G THRC~GH 13,6,20.C~ RECCRDS 5C S'1ATISTICS FCR ~EF'TH 13620.0 TO 13~5.5 CH ~EM SI~ CL'RVE ~ihI~oP M AXIFiIJM MEA~ I BE TON, ~. 5OC~CC, 2 TCD .TOll 3 TIME TO~ 97~.G6C 4 ETIM TON 1.914gC 5 CS TOH 94C.~CC .6 DIFF TOH O.~CGOCCE+OC 7 TENS TON 8 ~ARK TO~ 48.2~13 ~ RCAL TOH 4.47d5~ 10 C~LI TOH 6.~867E 11 I~V TO~ 12 S~Vg TO~ 1217 13 L~VD TOH 11~3.~C 14 RLLL TOF' 11.757~ 15 ~LLU TOF 115.~5 16 RLUL ~0~ 1C4.313 17 ~LUU TO~ O.CCOOCCE*~C 18 RSLL 10~ 63.71~ 19 RSLU TO~ 132.25C 20 RSUL TO~ 103.~75 21 RSUU TO~ 3.1503S 22 LL TOH 77.3125 23 L~ 10F 15E.1~5 24 LS TOH 1 25 L]TH TO~ 21.Cg3E 26 SS1 TOH 1~2.75C Z7 SS2 TOH Z~l. 28 FARI TOk O.CCOGCCE+GC 29 LSHV TOR 11~3.CC 30 SSHV TOH 1217.gC 31 FFSS ~0~ -0.139~ 32 FFLS TON -0.115723 33 ~LL TOE 69.37~C 34 ~LU TO~ 15C.375 35 ~tS IOH ~.5CC00 8.500CC C.345E98E~09 g,. 3458'9 ~ E+£ c~ 1914.00 1CC6 · ~96.~ 35~.65~ 1811.0~ 17E~.~7 C.OG. 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O.CCOCCC~+OC ATA FRA? SIZE- 112.~CC F/DC~N F A6 1.CC~CC PTIC~L L G DEPTF SCALE IJ~IT2 ..... 1.COOCC ~TA ~EFE EKCE PCZNT 17~.CCC ~TA ~EFE E~C~ PCINT LNITS INCH R~ME SP~ IN~ 6C.~C[ ~AME SPA ~N~ UNITS .lIN P~ ~AXI~M F~A~E~/RECORg ~EPTH RECCRDI~G ~CDE I~IT$ OF ~EFT~ IN DAl~ RECORDS ..... ~EPR. CODE FO~ OUTPU1 DEPTH ....... C~T~ SPECIFICATICN ELOCK SU~-TYFE 1.CagCC ?3.OgCC 1.CGOCC I I I 1~ ATU~: BLOCKS ~NEM SERVICE ID IOD TOM TIME TOH ETIM ~OH ,CS ~OH ~IFF TOH 3~NS TOH ~RK TOH ITT TCH 3T1 TOH 3T2 TOH 3T3 30H 3T4 TCH A~PL TOH C~L TOH TC TOH ~'T ¢~SL TOH ]~SL TOH E~LF TOH GGR TOH STSG TOH ~TEN TOH ~ HTE TOH ~RE$ FTE~ TOH ~TE TOH STEM ~OH G~Vl TOH C~1 F~VO TOH ~DIO TOH ~$VO TOH GSiO TOH CIO TOH S~O TOH SIO TOH ~CA TOH ~LCS TOH LLD TOH ELLD TOH LLS TOH LLG ]OH F~ TOH FS TOH CTE~ TON CCSW TOH FV TOH ~SPA ~SP TOH SFAR TOH 5F~V TOH SF TON ~ER~ICE UNIT AFI' AF~ LC6 TYFE S 11 '0 S 11 F/H~ 11 F 11 L~F 11 F 11 150 S 11 ~29 US 11 522 US 11 522 US 11 522 US 11 522 MV 11 522 MV 11 524 MV 11 524 11 US 11 522 MV 11 524 US '1'1 ~V 11 524 US,/F 1'1 520 ~AP! 11 310 GAPI 11 310 11 L2F 11 0 L6F 11 0 OEGF '11 0 :DEGC 11 DC/~ 11 0 ~V 11 9?0 MV 11 ~'?0 MV 11 97O UA 11 970 ~!V 11 '~71 UA 11 971 MY 11 UA 11 97O MV 11 971 UA 11 971 DS '11 970 DB 11 971 11 970 OH~F 11 M~/~, 11 220 OH~k 11 220 OH~ 11 NW 11 97~ NW 11 971 9EGC 11 11 11 0 11 10 11 10 11 11 10 11 10 FIL,~ ,5 6 ,~, .6 6 6 ZE PROCE:S. LEVEL 4 ~,20GCCCOC C ~CGOCC.GOC C COO ~ 00C C ~COC, CCOOCC ~:COOCCOOC C ~COOCCCOCC ~:COOCCOOCC ,,"3 C COCCCO£ C ID OtC ag C C ~4COCCOOCC ~CO0'OCOOCC 2CGOCCOOCC COCO OOC C ;SC(]OCCCGC C ~COOCCOOCC ~COCCCOOC'C ~CCOCCOOCC ~CCOCCOOC C ';~2COCCOOCC ~COOO~OOC C :~4GOCCOOCC OOOC OOC C OOCC OOC C ~CCOC, COOCC ~.COOCCOOCC 8COOCCOOCC COC C OOC C ~COOCCOOCC ~C00C100CC COC2 OOC C ~COOig2OOCC ~COOCEOOCC 0002 OOC C ~COOC~20ClC C ~4 C~OC2C,DC C ~.400C200C C ~4¢0C;"00C C ~4COC;C. OCC ~2GOC2C, 0[ C ~CCOC20C, C C ~- 2 C gCC I.].~ C. C OOCC COC C ~2GOCCC. 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OC 22~ 2.37 C.OOCCOOE+CC O.CCOOCCE+CC 1211C.C 36.5625 ~5.89~5 C.7~6~¢3E-01 O.3~,3044E-C 1 76C.500 545.03~ 539.C00 3:~ 1. 764.50C 5aZ.714 ~40.COO 3EC.3~3 ~2.531~ 2.86Z26 ~.~15715 ~.OCCC9 4.~075~ 21.8125 C.5~4378 C.COCEOOE+GO O.CCOOCCE+(C C.COCCOOE+CC O.CCCOCCE+CC C.COCCOOE+dC C.CECOECE+E( 121.C0~ ~1.44E7 297.E50 7~.5985 27'~.50C 7~.40C5 176.~00 17~.0CC ~89~ .OC 631 Z~:9~.OC 681 . C.223145 C.~C2375 17~.1~5 16~ .d~ 79.5~00 75.9171 595.500 -854.33E ~?O.COO C.~452d4 271 .~5C 0.3~11~ 399.C96 1i 7 "~ 5 74.4481 17E5 398.9 59 1785 163.76~. 17~5 · OOC. 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CPTIC~L LOG DEPTH SCALE UNITS ..... CATA ~EFE~ENCE PCINT .............. ~ATA ~EFE~ENCE POINT ~NITS FRAME SPACING ...... - .............. FRAME SPACING UNITS-- ~AXI~E~ FRAME~/RECOR~ ............. ~EPTH RECCRDI~G ~ODE' ............. L~ITS OF ~EP~ I~ DA'I~ RECO~D~ .... ~EPR. CODE FOR OblPU1 DEPlH ....... ~ATU~ SPECIFI~ATICN ELOCK SU~-'TYPE 132',COC 1.C00OC 1.£~0CC 17~.0CC INCk 6C.OGCC ,1~ 61.0G~C 1.CO00C ,1Ih 7],0GCC ~ATUP 9LOCKS ~N'E~ SERVI'CE ID IOD lOH 'l IME TOH E lIM TOH C S TOH ~ I F F I EN,S lOH ~ARK TOH 'liT TON lll lOH I 12 lOH ll3 1 1 ,~ 10 ~ ~PL lOH ~ ~L lOH lO lOH $~AT TOH II TCH llSL TOH 'CBLF TOH ~GR TOH (R lOH STSG IOH FTEN TOH ~HTE lv F;ES TCH DTEM IOH ~TE CTEM TOH G~Vl TOH tV1 TOH nDVO TOH FOIO ~$VO TOH FSIO lOH DVO lOH CIO TOH ~0 TOH ~I0 ~CA TOH ~C,A IOH ~LCS lOH LLD TOH CLLD TOh SERVICE £ R D E R 2 UbI'l AP'I AFI LOG TYFE S 11 0 NS 11 636 S 11 6]6 F/H~ 11 F 11 L6F 11 F 11 1~0 S 11 US 11 5'~2 US 11 522 US 11 US 11 5,22 MV 11 522 MV 11 ~V 11 524 11 5~0 US 11 522 MY 11 US 11 52'2 ~V 11 U$/~ 11 520 GAPI 11 310 G,API 1t 11 L2F 11 0 L~F 11 0 OH~F 11 0 DE6F 11 0 DE~C 11 0 DC/K 11 0 ~V 11 976 ~V 1'I ~V 11 970 UA 11 97O ~ 11 971 UA 11 ~71 ~V 11 ~70 UA 11 ~V 11 971 UA 11 ~71 D~ 11 ~70 De 11 971 11 OHR~ 1'1 FILE NO. 6 6 6 d6 6 6 SiZE SAPFLE CCD~ 73 49 49 4~ 49 49 49 49' 4~ 4,9 49 49 49 49 7g 49 49 49 49 49 49 49 49 7~ OPTICAL LOG DEPTH SCALE UNITS ..... ~ATA ~EFERENCE FCINT CATA REFERENCE POINT LNIT$ ......... F~AME SPACING ........ ~A~E SPACIN~ U~I~S DAXIPU~ FRAFE~/RECOR~ gEPTH RECCRDI~]G ~GDE .............. L~!TS OF DEPT'~ I~-, DAI~ ~E~ORDS .... qEPR. CODE, FOR OUIPU~ DEPTH ....... CATU~ SPECIFI~AI!CN ELOCK SUG-TYPE C ATUff ~L ~NEM SER I 1CD TIME TOH ETIM 'TON ~$ TOH ~IFF TOH TENS TOH ~A, RK ZTT TOH lll TOH 1T2 l'OH T T3 TOH 1T4 ~ MPL TOH {EL TON 1 C ~ ~AT TOH II CBSL TON TTSL TON CBLF TOH CT TOH ~R TOH (R TO~ 5TSG FlEN ~OH G HTE TOH ~ ~ES TOH ~TEM TOH ~:TE TOH ClEM TOH ~ DV1 TOH ~1 TOH F DVO n CIO TOH ~ ~VO ~ SIO CVO TON CIO 5VO TON ~IO C ~CA TOW S~CA TOM ~ LCS LLD CLLD 3CH LLS TOH LLG OCKS VICE SE~:VICE D ORDER ~ UNII API AFI LCG T¥F E S 11 0 F/HR 11 636 F 11 L~F 11 F 1'1 '150 S 11 529 U~ 11 522 US 11 US 11 522 US 11 522 MY 11 522 NV 11 ~V 11 5~4 11 5EO US 11 522 ~V '11 524 US 11 52'2 MV 11 524 US/F 11 5,20 GAPI 11 310 GAPI 11' 310 11 0 L2F 11 0 L:~F 11 0 OH~ 11 0 DEGF 11 O DEGC 11 0 DC/K 11 0 ~"i V I 1 g 70 MV 11 ~?0 MV 11 970 UA 1 1 NV 11 g71 UA 11 971 ~ 11 970 UA 11 97O NV 11 971 UA il ,971 D~ 11 970 D~ 11 971 11 Ch~t~ 11 2~0 OHMS': 11 7.20 C~ 11 ~7 2 i .COOCC 17~ .OCC INCH 6C .OGCC .1I i',, 61 .OOCC I, C OCCC .1I~. 73.00CC I .COOCC FILE NO. 7 7 7 7 7 7 7 7 7 7 7 7 '7 7 7 7 7 '7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 '7 Z 7 7 7 7 7 7 SIZE SA~FLE REPR CODE 73 49 49 49 49 49 49 49 49 49 49 49' 49 49 49 49 49 79 49 49 49 49 49 4g 49 49 49 49 4g 4~ ~SPA T SPAR IT ~PMV l SP I ( 67 ENTRY C ATA C~TU~ CATA LP/DC~ CFTICA ~ATA ~ATA ~RAME F~AME )AXI)~ ~EPTH 'LhITS ~EPR. ~ATU~ 7 C 7 0 7 C ? ) ***** DATA FC~AT SPECIFICAlICN ***** BLOCKS ECORD 'TYPE .................. SPECIFICATION ELOCK TYPE .... RAME SIZE ...... N FLAG ........... L LOG DEPTH SC.ALE U~ITS ..... EFERE~CE PCINl ........... .... EFERE~CE P~INT LNITS ........ iN .1 .'1 SPACING SPACING U~IlS ............... M F~A~E~/~ECOR~ RECORDING FCDE ................ OF DEPI~ Ih DA'I~ RECORDS .... CODE FO~ O~IPU1 DEPTH ....... SPECIFICATION ELOC~ SU~-TYFE O.CCOOCC~+OC O.CCOOCCE+OC 1~2.0CC 1.CCOCC 1.COCCC I?9.OCC 6C.OOCC 61.00CC 1.C00C¢ 73.00CC 1.COOCC .) CATU~ GL ) NEM SER I I CD l OH TIME TOH ETIM TOH CS TOH ~IFF IOH lENS TOH PARK TOH ITT IOH 'lTl IOH ll2 113 IOH ll4 ~FPL IOH £~L IOH 16 I'OH 5RAT TOH 1l IOH (~SL 1TSL TOH CaLF TOH CT TOH ~GR IOH EP IOH ~lSG IOH FTEN TOH ~HTE TOH ~ES TCH ~TEM TOH ~TE TOH ClEM TOH ~DV1 TCH tV1 IOH ~DVO TCH ~IO ~SVO IOH OCKS VICE SERVICE D ORDER i# U~IT $ S F/HR F LBF F US US US US MV MV US US/F GAPI GAPI L~F LE'F DE~C DC/K MV ~V AP L C 1 1 1 I AFI API 6 TYPE CLAS 1 O 0 I 636 21 I 636 21 11 636 21 11 6'36 21 11 635 21 11 150 1 11 52'9 82 11 522 83 11 522 83 11 522 83 11 5Z2 ~3 11 522 85 11 5~,4 86 11 5E4 32 11 5~0 67 11 522 ~3 11 5£4 86 11 522 ~3 11 5~4 86 11 5~0 60 11 316 1 11 31C 1 11 C C 11 O 0 11 C O 11 0 O 11 0 0 11 0 C 11 0 C 11 ~70 O 11 ~70 1 11 ~7¢ C 11 ~?0 O 11 971 C A FILE NO. 7 7 7 7 7 ? '7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 7 ? 7 7 7 7 7 '7 ? 7 SIZE PROCESS LEVEL 4. 4 ~CGOCCCOCC 2 8200CCGOCC 4 ~COOC20OCC 4 ~COOOCOOCC 2 ~CGOCCCOCC ,4 ~C'OOCCCOCC 2 2 6CCOCCOOCC ! SEGOCCOOCC 2 ~4COCCOQCC ~ JCCOCCCOCC 2 6CCOCCOOCC Z ~CCOCCOOCC £ ~£OOCCOOCE ? ECOOCCCOCC 2 6CCOCCOO£C £ ~£COCCC3CC 2 6CC'OCCCOCC 2 ~COCCCOC£ Z 8COOC20OCC E4CCCCCC£C ~CGOCCCOCC ~COOCCOOCC ,SCOOCCCOCC ~CCCCCCOCC ~C~CCCOOEC ~COCCCCGCC ECCCCIOOCC .~4OOC2COCC ~COCC2OOCE ~CCCC2O3CC ~CCOC~CeCC $~FLE REPR CODE 73 68 49 49 49 49 49 49 4,9 49 49 49 49 49 49 49 49 79 ~9 49 49 49 49 49 4'9 49 ~9 CECA TON ~2CA TOH ~LCS TOH LLD TON CLLD TON LLS TOH LLG TON FD TOH FS TOH ClEM IOH CCSW TOH FV TOW ~SPA TOH ~SP TOH ~PAR ~PMV TON ~F TOH '970 7 C 2 971 7 970 C C 2 220 10 O 4 Z 20 1 ,220 g C 7 4 I I ~ 7 0 11 971 6 O 7 2 '.~: 11 6 ~ 0 21 11 0 11 0 0 0 7 29 11 10 1' 11 10 1 11 10 1 1'1 10 1 C 7 2 11 10 1 ***** FILE i~IL. ER TC'H .0'0'7 LCG 32..4 '9C/12/1~ 819~ PR '***** END LOGICAL FILE 95 LOGICAL 62 bNZNC~h'. LCEICAL RECOE~ TYPES 00¢2C0£C OOCCOOCC O00C~OCC COCCOGCC OOCCOOCC OOC2GGCC COC200CC OOCIOCCC OOCIOOCC gOClOeCC OOC200CC OOO~OOCC COCCOOCC GO02OOCC O0¢CCOCC RECORDS 714 FRAMES RE~D FP, CM 12 RECCR~S, CCFPUTE5 FgA~E SP.A'CIN.'C-= 0.500C FT 7'14 ~AiA F~A~ES FR~M 13935iOC 1HRCbGH 13576.5C REC,CRDS 7~ TH~OU6F 94 CH I lCD 2 TI~E 3 E"TI~ 4 C$ 5 DIFF 6 TENS 7 ~ARK R IlT ~ TT1 10 112 11 ll3 12 ll4 13 AMPL I ~ C~L 15 TC 15 SRAT 17 ll 1 $ CESL 19 TISL 20 C~LF 21 DT 22 RGR 23 GR 24 S1 SG 25 HIEN 26 RHTE ,~IATI~TI¢S FCR DEFTH '13573.5 TO 13935.C SID CLRVE MI~I~U~ FAXI~U~ F~EA~ STD-DEV 'lC~ .594~E+09 C.345948E+09 34594~E+C~ 150.532 IOH .CCC 1423.00 4E .1 57 6:8. E 2 29 TOF 23CC 5 34,1 84 62.80~ 150..414 lOH .4.CC 273C. O0 420,17 21 8.1 2~ TOH OCCCE+C[ C.OOCCOOE+OC CCCOCCE+CC C .OOCCOCE+O0 TCH O.CC 7940. gO 1~5.3~ ] ~3.5 ~]C IOH ZG13 36, [750 6,614~ C.207266 ICH 145alE-C4 C,301E84E-01 145~1~E-Cl C,~44993E-02 TON C,75E ?el .500 55,27E ~4.22 33 TON 9.5CC 537,500 ~ .417 46.~[77 TOH 'C. gCC 7 58.C O0 5e · 2C 1 d4.? 5 7E 'T OF 2.25C 535,C O0 [~. 75E 46. ] 4 03 TON 17~3~ Z1.4e E. 8 .5591 E ~, 57C 71 TOH E82~lE-C3 1 .~42~ 137~] C.20E471 TCF COGCC 5,CCCCO .a4454 0.3d2] 45 TOH 7"~ 32C E-G1 ~,3]C6~ 5~10e2 C,Z67~.37 TOH CGCCE[*CC C,OCCCOOE+GC CECOCEE+CC C.OCCCOCE*O0 TCH CCCCCE+CC C.COCCOCE+gO CCgOCCE+CC C .OCECCCE*OC TOH COCCCE+CC C,OCECOCE+CC CCOOCC~+CC C.gCCCOCE+OC TC~ ~ ~2~ 1~-C] 1, ~4 2o 1]?~[Z C .2C24 71 TON . a~75 1 22. ~ ~' 4,5774 ~. "[4 45 TON ,Z2~1 ~97.~00 3.7772 45.[C 2~ TCH .437~ 276.2 56 3.5'~.5C 46.C7 2C i OH ~. CCC 1 7e. C OC 7 '~. OC C C. OCCC gC ~+ CC TOH ~.25C 79S.50C ~1.911 ~5.17 31 SAMPLES 714 714 714 714 714 714 714 714 714 714 714 714 714 714 714 '714 714 714 714 714 714 714 714 714 7'1 4 71 4 ~Vl '[OF EOVC TOH RCIO TOH R~VO TOH ~$I0 'TOP. ~C TOP, ~I0 TO~ SVO TOH SIO ~0~ ~CA TOH SECA TON DLCS TO~ LLD CLLD TO~ LLS 30H L. LG TOH P~. P"S ~ 0 H CTE~ CCS~ TOH ~PA '~ S P T 0 H ~FAR END LOGIC -1 , ~709C .4,7"?7 3~ - O. lC 59~ 2 ~ , 7Z~ -0,1£0~9 ~ '~ . 21E'75 3. ~4072 I .,~E~,~ O. 2].~'~.t~ 1.40~,00 b14,25~ I 54:, 0,1~1133E-01 ~,45703 2.7625~ 1,15~8~ 9 · CO00C 207,~ , O.c. 73~ , 1 52 207 , -O,a~37~E-01 ~ .~1C94 3,~44C9 I.,6E32~ O, 23437~ 13~2,00 6C5, ~14 152, O, 27343:~ E-01 ~,43750 2.76057 1,15111 9,1093~ 207~.00 '73~, 95~ ~07. 1 4.9219 ~ O,CCO0 21 · 9327 ~, ~1 ~7.7~56 ~0. CCO0 33.91 ~7 I . 77~ 59 3~,00CC 44. CC O0 3~ , ~11 2 C ,29~1 0'.~93'26'~ '~ G. 5'200 ,6,. ? 5052 5. O~ 554 I 6.5156 111 9.0C 22C.5~5 145.9 59 O. 87089C 37, ~ 93 ~. 2979~ 4, OS7 67 -1 37 . ~1 1 1 21 4.94 I . ~9084 45.75 52 0 · ~ 3252 C ? 33 t . 0 C 2221 . 61 e 20 . 2.,16797 7804,.0G 1~3.18 702.'2 95 ~1 . 9375 e<4. ~500 ,~,2. 832C 0.5 ~[ 1 614.4.CC ~144.00 ~,144.CC -G.3~,552 25E-09 243.5CC 248.~50 245,.74~ 0.9233 22 O, 5COCCC C,7G8C0~ O, 591 54~ 0 , 45S~ 21E-01 1', 50GCC '14'9.'125 37,4.3.4~ 58.51 25 -41 , 2813 106, ~13 -5, ~444~ 58,'2~ 52 -43,0CCC -4 2,5COC -4~,75e4 C .6F~9418E-01 -41.25~C 1 06.313 -5, ] 47C ~ 58. ~ 9 65 714 714 714 714 '714 714 714 714 714 714 71,4 714 714 714 714 714 714 "714 714 714 714 714 714 '7'14 714 7'14, START LOGICAL FILE - 7 0 '~**** FILE HE~DER ***** L~KN¢~N L'CGIC~L ~OF~ TYRE 2E'7 $~IF~E~ ~EC L~KNC~N LCGIC~L RECC~ TYF~ ~7 5~IPFE~ L~NC~N LCGiC~L ~ECC~£ TYF5 2Z4 S~i~FED ~EC LNKNC~N LCGIC~L ~ECCGC TY~E ~7 $~IPPE~ ~C L~KNC~N LCGIC~L ~ECC~ TYF~ 227 SKIPPED LNKNCkN LCGIC~L ~ECC~ lYF[ 224 ~KIFPED ~C L~KNC~N LCGIC~L ~ECCFC TYF~ 227 E~IFFED REC LNKNCNN LCGICSL FECCFC TYPE 2Z4 S~IRP~O ~EC LkKNCNN LCGIC~L FECCF[ TY~E 224 S~iPPED LNKNCNN LCGICJL ~[,CC~ TYF~ £~7 S~IFPED L~NCNN LCGICJL SECC[~ IYF~ ~24 EZI?PE2 ~C LNKNCNN LCGIC~L ~CCFC TYPE 227 SKIFFE~ ~EC L~KNCNN LCGICJL ~ECCF~ TYRE 227 E~IPPED LNKNCNN LCGICSL ~,ECCF[ TYRE 227 SKIPPED L~KNCNN LCG,IC~L BECCF~ TYFL 227 ~TRF~D LNKNCNN LCG.[C~L ~ECO~$ TYi:~ 2Z? ~K[.PREO L~NCNN LCGICSL ~ECCF~ T'Y~ 227 ~KIRPE~ PR ***** FILE 'I~!LE~ ***** TCH .024 ~FTE 32.4 ***** 5ND LO~IC,RL FILE 41 CN~NO~ L:C~ICAL R~COR~ ~'C/1Z/I? 3C72 S'? LOGICAL T~PE S EN'D LOG]C~L FILE E~D OF INFUT --