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196-079
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 25, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2M-34 KUPARUK RIV UNIT 2M-34 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/25/2024 2M-34 50-103-20242-00-00 196-079-0 G SPT 6163 1960790 1541 3454 3465 3583 3590 280 300 300 300 4YRTST P Sully Sullivan 6/22/2024 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2M-34 Inspection Date: Tubing OA Packer Depth 20 1990 1920 1910IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS240624192707 BBL Pumped:7.3 BBL Returned:5.1 Thursday, July 25, 2024 Page 1 of 1 � II my III .� �[lilu � TO: Jim Regg P.I. Supervisor FROM: Adam Earl Petroleum Inspector 1a0w NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 17, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2M-34 KUPARUK RIV UNIT 2M-34 Src: Inspector Reviewed By: P.I. Suprv1—B 17 -- Comm Well Name KUPARUK RIV UNIT 2M-34 API Well Number 50-103-20242-00-00 Inspector Name: Adam Earl Permit Number: 196-079-0 Inspection Date: 6/13/2020 Insp Num: mitAGE200617112142 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-34 Type Inj W, TVD 6163 Tubing 2535 2595. 2625 - 2605 PTD 1960790 Type Test SPT Test psi 1541 IA 850 1300 1740 - 1730 BBL Pumped: 2.5 BBL Returned: L_ 2.5 OA 440 630. 610 600 - Interval 4YRTST p/p P -� �---- —� Notes: MIT IA Wednesday, June 17, 2020 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Z(✓ DATE: Friday,January 20,2017 P.I.Supervisor / (� ( 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-34 FROM: Brian Bixby KUPARUK RIV UNIT 2M-34 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2M-34 API Well Number 50-103-20242-00-00 Inspector Name: Brian Bixby Permit Number: 196-079-0 Inspection Date: 1/17/2017 Insp Num: mitBDBl70117163303 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2M-34 Type Inj W 'TVD 6163 - Tubing 2415 2415 • 2413 - 2412 - i PTD I 1960790 • Type Test SPT Test psi 1541 i IA 1300 3200 3150 - 3150 - BBL Pumped: 5.1 - 1BBL Returned: 5 OA 540 640 640 — 640 Interval 4YRTST 4YRTST P/F P ✓ Notes: SCANNED APR 0 6 2017. Friday,January 20,2017 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. l ~ - 0 7~ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Bevedy~Vincent Nathan Lowell Date: [] TO RE-SCAN Notes' Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si i • lO~IElVI®RAl01DLT1VI State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, June 11, 2008 Jim Regg P.I. Supervisor J flq ~I ~ 7 ~(:'~J SUBJECT: Mechanical Inteb ity Tests t ( CONOCOPHILLIPS ALASKA INC 2M-34 FROM: Jeff Jones KUPARUK RIV UNIT 2M-34 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv '. NON-CONFIDENTIAL Comm Well Name: KUPARUK RN UNIT 2M-34 API Well Number: 50-103-20242-00-00 Insp Num: mitJJ080610130833 Permit Number: 196-079-0 ~ Rel Insp Num: Inspector Name: Jeff Jones Inspection Date: 6~2i2oo8 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2M-34 , Type Inj. ~ W TVD I 6163 '~~~ IA I ---- 1530 2070 2070 2060 p T 1960790 TypeTest ~ SPT : TCSt psl 540-75 =L 470 500 ~- 500 490 Interval 4YRTST per, p _~ _ _Tllbing~ 2600 2600 _ - 2600 2550 ~ ~ NOteS: 1.4 BBLS diesel pumped; no exceptions noted. ~~ JUL ~ ~ 2008 Wednesday,.lune 11, 2008 Pale 1 of I • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 6, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Deaz Mr. Maunder: RECEIVED JAN U 8 ~00~ Alaska Oil & Gas Cony, ComNnd~,~lan Anchorage ~~~~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of 12". The remaining volume of annulaz void respectively was filled with a corrosion inhibiter, RG2401, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top-fill operation was completed on Dec 25, 2007. We mixed 15.7 ppg Class G cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor/sealant was pumped in a similaz manner Jan 6, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call me at 907-659-7043, if you have any questions. Sincerely, ,~ Perry ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~+o RECEIVED SCblumbel'gep MAY 2 4 2006 ~ Cif & Gas Coos. Ccmæ~ ~e Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 3808 \ Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 An.h.,".e, AK 9950\~ \ø ~ 0 1 q Kuparuk \"'\ Field: Well BL Color CD Job# Log Description Date 1 G-01 (REDO) 11213744 INJECTION PROFILE ì'ðéJ -ì3ò 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG WIDEFT IC' "\- n'J 05/06/06 1 1A-03 11258708 PRODUCTION LOG WIDEFT I "6 i - 0 ~11" 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG WIDEFT ,C,?( _ /q{"" 05/08/06 1 1A-02 11258709 SBHP SURVEY I.' '! è. I ~ l - (,--r \ 05/09/06 1 1R-13 11258711 INJECTION PROFILE I' :. è... \5<,,- /Çh 05/10/06 1 2M-34 11216296 INJECTION PROFILE I Jì:- ~ \ C¡ (;~ - (,--::A 05/11/06 1 2F-03 11216298 SBHP SURVEY i \ .:-t (\ \~~ - /..;..-...... 05/14/06 1 2F-14 11216299 SBHP SURVEY L) .1- (. 17r~'-'~ 05/14/06 1 1A-06 11258712 INJECTION PROFILE ~ J-r Q.. I ~ I - I J ~ 05/14/06 1 3Q-11 11216301 LDL ¡ 't~·-"'3ár 05/16/06 1 1J-184 11216297 USIT r) -r (' r:\"" t- (' ,.J¿¡ 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. [1~.L0- ~/os-(o~ 9 05/18/06 e e MEMORANDUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg -;) ( :2) P.I. Supervisor K,efì q '1'10;; DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2M-34 KUPARUK RIV UNIT 2M-34 i..' ;' ö1Ú \'\\Ø FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~L Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2M-34 Insp Num: mitCS050812204429 Rei Insp Num: API Well Number: 50-103-20242-00-00 Permit Number: 196-079-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. "Well !- ·2M-34··lTÿ-p-;¡~j~wTTVD-ì -616ij-iAi-- -- 900---r-20ÕüT.----l9šü-----T-.--1950·.. ..-- I ~i-"'-! 196079o!T~peT~;ttSP~·T~st ps¡-"1ï54o;-I--OAI'-40Õ-m 460-'¡-'46'Õ---¡-%O '-r" .-.--+-.-. -..--~.. _....1._..___ ..L___....._.----L__...._... .~-~-- --" ------f-..---.L------I----t.----.-- Interval 4YRTST PIF P Tubing! 2300 ! 2300 I 2300 I 2300 i I _ .___....__ .____._____ "._.. ___._._._ ..._..____. ____... ,..______--'___..__._.._..-1-_. _._-L..__._..____._ Notes: Pretest pressures observed for 30+ minutes and found stable. , r· \ ¡~..~~:~\( I '1,.;,,11 "'I~ \\1\ Ö ~ ~.",\... ì-..;¡\;;-v,h,\' Ii Ii) II Wednesday, August 17,2005 Page I of I ON OR BEFORE c:LO~,,Mt:ILM-DOC AOGCC Individual Well Geological Materials Inventory PERMIT DATA T DATA PLUS Page: 1 Date: 09/15/98 RUN RECVD ............. :o-<o? ~~P::T:O~ DATA Are dry ditch samples required? yes ~d received? FINAL 08/08/96 FINAL 08/08/96 1,2 08/08/96 FINAL 09/25/96 /~/~/¢~ / /////q~ / yes no Was the well cored? yes ~_~Analysis & description received? Are well tests required? yes ~o~Received? y~' Well is in compliance ~ Ihitial COMMENTS STATE OF ALASKA AL/-~CKA OIL AND GAS CONSERVATION COMMISU~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 114' FSL, 392' FWL, Sec. 27, TllN, RFE, UM At top of productive interval 54' FSL, 1164' FWL, Sec. 5, T10N, RFE, UM At effective depth 113' FNL, 1432' FWL, Sec. 8, T10N, RFE, UM At total depth 181' FNL, 1484' FWL, Sec. 8, T10N, RFE, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2M-34 9. Permit number/approval number 96-079 10. APl number 5o-103-20242-00 11. Field/Pool Kuparuk River Field/Oil Pool 1 6800 feet Plugs (measured) None 641 1 feet Effective depth: measured 1 6 6 9 9 feet Junk (measured) None true vertical 6356 feet Casing Length Size Cemented Measured depth Structural Conductor 8 0' 1 6" 140 Sx AS I 1 21' Surface 41 5 4' 9 - 5 / 8" 730 Sx AS III & 41 9 4' Intermediate 820 Sx Class G Production 16749' 7" 250 Sx Class G 1 6 78 8' Liner Perforation depth: measured 16450'-16495', 16526'-16575' true vertical 6221 '-6246', 6263'-6289' True vertical depth 121' 2793' 6405' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 16369' Packers and SSSV (type and measured depth) Packer: Baker SAB3 @ 16342'; SSSV: None, nipple @ 459' 13. Stimulation or cement squeeze summary Perforated C4, A3 & A4 sands on 10/4-5/96 .. Intervals treated (measured) 16450'-16495', 16526'-16575' Treatment description including volumes used and final pressure Perforated using 2.5" HC guns w/ DP charges, fp was 730 psi. 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 835 598 Subsequent to operation 0 0 4900 850 255O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service 17. I hereb~ertify that the foregoing is true and correct to the best of my knowledge. Signed Title Wells Superintendent Form -404¢f Rev ,1~6/1 ~'~88 - SUBMIT IN DUPLICATE ,CO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1 (2M-34(W4-6)) ,o, 2M-34 PERFORATE, PERF SUPPORT 0906960547.1 DATE DAILY WORK UNIT NUMBER 10/05/96 PERF C4 INTERVAL DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 7 (~ Yes ~ No (~) Yes O No SWS-BAILEY JORDAN ' I~1 ELD AFCfl CC_.g¢ DAILY COST ACCUM COST Signed ESTIMATE AK8517 230DS28ML $1 0,61 8 $84,920 Initial Tbcl Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 900 PSI 600 PSI 850 PSI 350 PSII 0 PSII 0 PSI DAILY SUMMARY PERF C4 INTERVAL @ 16450'-16475' W/SWITCHED 5' AND 20' X 2.5" HC GUNS (DP CHARGES-2 SPF-0 DEG PHASING-0 DEG ORIENTATION F/LOW SIDE OF HOLE). PERFORATE NET PAY COMPLETE. RDMO SWS E-LINE. TIME LOG ENTRY 08:00 MIRU SWS E-LINE AND HOT OIL DHP. PT BOP, LUB OK. 10:00 RIH W/CCL, MPD, SWITCHED 5' AND 20' X 2.5" HOLLOW CARRIER GUNS (DP CHARGES-2SPF-0 DEG PHASING-0 DEG ORIENTATION F/LOW SIDE OF HOLE). INITIAL PUMP RATE .5 BPM. 3.3' CCL-TOP SHOT OF TOP 20' GUN, 25' CCL-TOP SHOT OF BOTTOM 5' GUN. 10:20 GUNS STOPPED AT 2800' ELM. INCREASE PUMP RATE TO MAX 3.5 BPM, CONTINUE RIH. 11:30 TIE IN SJ. MAINTAIN 730 PSI TBG PRESS. 11:50 PERF INTERVAL @ 16470'-16475' WHILE MAINTAINING 730 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. RIH, LOG UP 12:00 PERF INTERVAL @ 16450'-16470' WHILE MAINTAINING 730 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. POOH ~3:30 ON SFC. ALL SHOTS FIRED. RDMO 2G-10A SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $24.00 ..APC $600.00 $12,200.00 \RCO $0.00 $1,050.00 HALLIBURTON $0.00 $4,727.00 LI'I-I'LE RED $1,200.00 $2,220.00 ,. SCHLUMBERGER $8,818.00 $64,699.00 TOTAL FIELD ESTIMATE $1 0,618.00 $84,920.00 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 30, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2M-34 (Permit No. 96-79) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2M-34. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR REOOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~ Oil [] Gas F-I Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-079 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface 114' FSL, 392' FWL, Sec. 27, T11 N, R8E, UM At top of productive interval 54' FSL, 1664' FWL, Sec. 5, T10N, R8E, UM At total depth 181' FNL, 1484' FWL, Sec 8, T10N, R8E, UM 8. APl Number 50-103-20242-00 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2M-34 11. Field and Pool Kuparuk River Elevation in feet (indicate KB, DF, etc.) i6. Lease Designation and Serial No. Rig RKB 41', Pad 106' I ADL 25590, ALK 2676 12. Date Spudded i13. OateT.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, ifoffshore 116. No. of Completions 5/10/96 i 5/22/96 ill 0/5/96 N/A MSLI One 17. Total Depth (MD+TVD) j 18. Plug Back Depth (MD+TVD)Ii 9. Directional Surveyj20. Depth where SSSV set~l. Thickness of Permafrosl 16800 6411 F-ri 16699 6356 F~ []Yes []No J NA MD! 1380' (Approx.) 22. Type Electric or Other Logs Run GR/CDR/CDN, GR/CCL/SLT-J 23. CASING S~ZE VVf. PER FT. GRADE 16" 62.5# H-40 9.625" 40.0# L-80 7" 26.0# L-80 ToP BoTroM SURF. ~'~ SURF. 4194' SURF. 16788' CASING, LINER AND CEMENTING RECORD SE~-I-ING DEPTH t HOLE SlZE 140 sx AS I l?.2511_ 250 sx Class G I ! l i Bottom 24. Perforations open to Production (MD+TVD of Top and and interval, size and number) CEMENTING RECORD 730 sx ASIII, 820 sx Class G 25. TUBING RECORD AMOUNT PULLED SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 1 6369' 16342' 26. ACID FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED HPBD - 6609# proppant used. Fluid volume pumped 1980 bbls MD TVD MD TVD 16550'-16575' 6276'-6289' 16450'-16475' 6222'-6235' 16526'-16550' 6262'-6276' 2 spf 4 spf 16475'-16495' 6235'-6246' 3 spf 27. PRODUCTION TEST Date First Production Date of Testi'Hours Tested ; Flow Tubing!Casing Pressure Press. ! 28. iMeth°d of Operation (Flowing, gas lift, etc.) ~r-- Water Injection ~5-t~O~ G~:i~-~-F~i ~-~_¥~ B L GAS-MOF TEST PERIOD ' CALCULATED · I OIL-BBL GAS-MCF I _24-Hour RATE CORE DATA WATER-BBL WATER-BBL CHOKE SIZE i GAS-OIL RATIO Oil ~-~A-~if~;-AP ~ (-~RR) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Alaska 0!l & Gas CoJ-~S. C0.rnrr,,issir~ Form 10-407 Rev. 07-01-80 Submit In Duplicate ' Geologic Marker,.. 30. ,:ormation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , , . Top Kuparuk C 16448 6221 Bottom Kuparuk C 16475 6235 Top Kuparuk A 16475 6235 Bottom Kuparuk A 16739 6378 Freeze protected annulus 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Prepared By Name/Number: 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 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 Rev. 07-01-80 Date: 10/25/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2M-34 RIG'NO RIG WELL ID: AK8517 TYPE: -- AFC' AK8517 AFC EST/UL:$ 1830M/ 2196M STATE'ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD' KUPARUK RIVER UNIT BLOCK' SPUD:05/10/96 START COMP'07/30/96 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20242-00 05/10/96 (D 1) TD: 542' ( 0) S UP V: RLM DAILY:$ 05/11/96 (D 2) TD: 2852' (2310) SUPV:RLM DAILY:$ 05/12/96 (D 3) TD: 4204' (1352) SUPV:RLM DAILY:$ 05/13/96 (D 4) TD: 4204' ( 0) SUPV:RLM DAILY: $ 05/14/96 (D 5) TD- 8311' (4107) SUPV: DCL DAILY:$ 05/15/96 (D 6) TD:10646' (2335) SUPV'DCL DAILY: $ 05/16/96 (D 7) TD:13320' (2674) SUPV'DCL MW: 9.4 VISC: 72 PV/YP: 18/24 APIWL: 9.4 DRILLING AT 994' Move rig from 2M-31 to 2M-34. Accept rig @ 1430 hrs. 5/10/96. Function test diverter. Drill 12.25" hole from 121' to 542' 101,691 CUM:$ 101,691 ETD:$ 0 EFC:$ 1,931,691 MW: 10.1 VISC: 57 PV/YP: 23/26 APIWL: 8.8 DRILLING AT 3054' Directional drill 12.25" hole from 542' to 2852' Lost MWD signal. Circulate and work pipe. Trouble shoot Anadrill surface system. POOH, work tight spots at 1832' and 1533' 73,941 CUM:$ 175,632 ETD:$ 0 EFC:$ 2,005,632 MW: 10.0 VISC: 47 PV/YP: 20/15 APIWL: 8.4 TOP JOB 9-5/8" POOH, work tight spots at 1832' and 1533' Drill from 2852' to 4204' Run 9-5/8" casing to 4000' 148,957 CUM:$ 324,589 ETD:$ 0 EFC:$ 2,154,589 MW' 8.7 VISC: 43 PV/YP: 10/23 APIWL: 12.4 DRILLING 8.5" HOLE @ 5250' Run casing to 4194' Cement casing CIP at 0453 hrs. 5/13/96. Perform top job on surface casing. Tag cement at 3889', calculated top at 4052' Drill cement to 4085' 158,649 CUM:$ 483,238 ETD'$ 0 EFC-$ 2,313,238 MW: 8.9 VISC: 46 PV/YP: 11/13 APIWL: 12.0 DRILLING Drill cement, FC and float shoe. Drill 10' new formation to 4214' Performed FIT @ 2792' TVD, EMW = 12.6 ppg. Drill and MWD survey 8.5" hole from 4214' to 8311' 82,476 CUM:$ 565,714 ETD:$ 0 EFC:$ 2,395,714 MW: 9.2 VISC: 48 PV/YP: 16/26 APIWL: 6.2 SHORT TRIP @ 11021' Held safety meeting. Fill pipe on 22nd stand. No problems. Ream 90' to bottom. No fill. Drill and MWD survey 8.5" hole from 8311' to 9270' Hole started taking mud and breathing at 8751' Reduced pump rate to 550 gpm. Added barofiber at 10 min/sk. Well stable @ 9100' Drill and MWD survey 8.5" hole from 9270' to 10646' Hole breathing on connections. Flow decreases quickly 86,277 CUM:$ 651,991 ETD:$ 0 EFC:$ 2,481,991 MW: 9.4 rISC: 47 PV/YP: 15/24 APIWL: 6.0 SHORT TRIP TO 11000' Drilling and MWD survey from 10646' to 11021' Monitor well. Initial flow back, flow slowed to 20 bph after 30 min. Performed wiper trip to 8300' No problems. Drilling Date: 10/25/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 DAILY:$ 05/17/96 (D 8) TD:14076' (756) SUPV:DCL DAILY:$ 05/18/96 (D 9) TD:15569' (1493) SUPV:DCL DAILY:$ 05/19/96 (D 10) TD:16175' (606) SUPV:DCL DAILY:$ 05/20/96 (D 11) TD:16273' ( 98) SUPV:DCL DAILY:$ 05/21/96 (D 12) TD:16787' (514) SUPV:DCL DAILY:$ 05/22/96 (D 13) TD:16800' ( 13) SUPV:DCL DAILY:$ 05/23/96 (D 14) TD:16800' ( 0) SUPV:DCL and MWD survey from 11021' to 13320' 84,097 CUM:$ 736,088 ETD:$ 0 EFC:$ 2,566,088 MW: 9.4 VISC: 49 PV/YP: 17/24 APIWL: 6.2 DRILLING @ 14600' Drilling and MWD survey 8.5" hole from 13320' to 13620'. Circ lo/hi vis sweep. Monitor well. Initial flow - 42 bph. Slowed to 11 bph in 30 min. Pump pill. POH to shoe. No problems. RIH. Ream 90' to bottom. Drilling and MWD survey 8.5" hole from 13620' to 14076. 80,905 CUM:$ 816,993 ETD'$ 0 EFC:$ 2,646,993 MW: 9.3 VISC: 49 PV/YP: 19/24 APIWL: 4.6 DRILLING @ 15853' Drilling and MWD survey 8.5" hole from 14076' to 15536' Monitor well. Initial flow - 35 bph. Flowing 14 bph in 25 min. Pump pull. Perform wiper trip to 13533'. No problem. Ream 90' to bottom. No fill. Drilling and MWD survey 8.5" hole from 15536' to 15569' 88,932 CUM:$ 905,925 ETD'$ 0 EFC'$ 2,735,925 MW: 10.4 VISC: 48 PV/YP: 20/22 APIWL: 4.5 RIH W/ROTARY ASSEMBLY Drilling and MWD survey 8.5" hole from 15569' to 16175' . Well taking .4 to 1.5 bpm Monitor well. Flowed back 49 bbls in 30 min. Slowed to 10 bph. Pump pill. No problems. Hole fill - 40 bbls short. 107,208 CUM:$ 1,013,133 ETD:$ 0 EFC:$ 2,843,133 MW: 10.4 VISC: 47 PV/YP: 19/18 APIWL: 5.0 ROTARY DRILLING AT 16420' RIH to 9900' No mud returns last 10 stds. Spot 75 bbls 25 ppb LCM in annulus. RIH to 15221' Wash and ream from 15221' to 16145' Circ and condition mud 22 ppb LCM. Increase flow rate to 500 gpm w/rotary at 100 rpm. Slight seepage. Drilling 8.5" hole from 16175' to 16273' 98,145 CUM'$ 1,111,278 ETD'$ 0 EFC'$ 2,941,278 MW: 10.4 VISC: 48 PV/YP: 18/17 APIWL: 5.0 CIRC AFTER SHORT TRIP (16,800) Rotary drilling 8.5" hole from 16273' to 16787' 82,394 CUM:$ 1,193,672 ETD:$ 0 EFC:$ 3,023,672 MW: 10.4 VISC: 54 PV/YP: 24/22 APIWL: 4.2 RIH W/7" CSG Rotary drilling 8.5" hole from 16787' to 16800'. Monitor well. Flow slowed to 10 bph. POH for wiper trip to 15000'. Pump and work through several tight spots from 16600' to 16200' No problems. Held pre-job safety meeting for running casing. RIH w/7" casing to shoe. Lost 11 bbls mud. 83,925 CUM:$ 1,277,597 ETD:$ 0 EFC:$ 3,107,597 MW: 10.4 rISC: 49 PV/YP: 18/20 APIWL: 4.4 LD 5" DP F/DERRICK RIH w/7" csg. Work thru tight hole from 5630' to 5680' RIH w/7" csg. Work thru tight hole from 8612' to 9411' Push pipe w/top drive 10071 to 10321' RIH to 14304' Lost 338 Date: 10/25/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 DAILY:$ 05/24/96 (D 15) TD'16800' ( 0} SUPV:DCL DAILY:$ bbls mud to formation. No returns. Continue RIH w/7" casg. Push w/top drive from 14433' to 14938' and from 16100' to 16500' Lost total of 770 bbls mud. Cement casing. Bumped plug. Check floats. OK. No flow out annulus. ND BOPE. 288,875 CUM:$ 1,566,472 ETD:$ 0 EFC:$ 3,396,472 MW: 0.0 riSC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish ND BOPE. Set pack-off. Test packoff to 3000 psi. Freeze protect 9-5/8" x 7" annulus. Release rig @ 1200 hrs. 5/24/96. 36,136 CUM:$ 1,602,608 ETD:$ 0 EFC:$ 3,432,608 Date' 10/25/96 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 REMEDIAL AND COMPLETION OPERATIONS WELL:2M-34 RIG'NORDIC WELL ID' AK8517 TYPE' AFC' AK8517 AFC EST/UL:$ 1830M/ 2196M STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:05/10/96 START COMP:07/30/96 FINAL' WI: 0% SECURITY:0 API NUMBER: 50-103-20242-00 07/30/96 (C 16) TD: 0' PB:16699' SUPV:MEL DAILY:$ LOADING 3.5" TBG IN PIPE MW' 8.5 SW Move rig from 2M-35 to 2M-34. ND tree. NU BOP. Tested BOP. 33,869 CUM'$ 1,670,346 ETD:$ 0 EFC'$ 3,500,346 07/31/96 (C 17) TD: 0' PB: 16699' SUPV: JT DAILY: $ PU & RIH W/TBG RIH with 3.5" tubing. 32,932 CUM'$ 1,736,210 ETD'$ MW- 0.0 0 EFC'$ 3, 566,210 08/01/96 (C 18) TD: 0' PB: 16699' SUPV: JT DAILY: $ RIH W/COMP ASSY MW' 0.0 RIH to 15899. Held safety meeting. Run CBL. POOH. RIH w/completion assembly. 52,607 CUM'$ 1,841,424 ETD:$ 0 EFC:$ 3, 671,424 08/02/96 (C 19) TD: 0' PB'16699' SUPV'JT DAILY'$ RIG RELEASED MW: 0.0 RIH slowly with completion assembly due to hole angle. Set packer w/2500 psi. Test f/30 minutes. Pressure tested annulus w/2500 psi on annulus and 500 psi on tbg for 15 min. Freeze protect well. ND BOPE. NU tree and test (500/5000} . Release rig @ 2230 hrs. 8/1/96. Move rig to 2M-31. 167,592 CUM:$ 2,176,608 ETD:$ 0 EFC:$ 4,006,608 End of WellSummary for Well:AK8517 2M-34 D.~ 09/30/96 DAY 3 DAILY KUPARUK RIVER UNIT WELL SERVICE REPORT JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERF "A" & "C" SANDS OPERATION COMPLEi'E I SUCCESSFUL NO YES Initial Tbg Press [ Final TUg Press [ Initial Inner Ann 50 PSI 700 PSI 50 PSI SUMMARY Kl(2M-34(W4-6)) JOB NUMBER 0906960547.1 UNIT NUMBER KEY PERSON SUPERVISOR SWS~BAII .F:.Y r-u ~.mv Final Inner Ann ] Initial Outer Ann [ Final Outer Ann 650 PSI 0 PSI 0 PSI PERF'D "A" SAND INTERVALS @ 16570' - 16575' RKB AND 16550' - 16570' RKB W/SWITCHED 5' AND 20' GUN (DP CHGS4 SPF-180 DEGREE PHASING-90 DEGREE ORIENTED FROM LOW SiDE OF THE HOLE-HOLLOW CASE CARRIER). DEVIATION REQUIRED GUNS TO BE I PUMPED DOWNHOLE, 3-1/2 BPD PUMP RATE REQUIRED. JOB IN PROGRESS. TIME 09:00 12:00 12:30 14:30 15:30 17:30 18:00 19:30 20:30 LOG ENTRY MIRU SWS AND APC PUMP TRK. HELD SAFETY MTG (6 ON LOCATION). PT'D LUB AND SURFACE EQUIP TO 4000 PSI; RIH W/CCL, MPD, SWITCHED 5' AND 20' GUN (DP CHGS-4 SPF-180 DEGREE PHASING-90 DEGREE ORIENTED FROM LOW SIDE OF THE HOLE-HOLLOW CASE CARRIER). WENT DOWN TO 3000' ELM COULD NOT PASS. STARTED PUMPING DIESEL @ 2.5 BPM. CONTINUED DOWN THE HOLE TO 11200' ELM, UNABLE TO PASS. UNABLE TO GET ENOUGH RATE W/PUMP TO CONTINUE. S/D. STOODY BY FOR LARGER PUMP AND RE RIGGING OF SURFACE LINES. STARTED PUMPING DIESEL @ 3.5 BPM CONTINUED DOWNHOLE. TAGGED BTM @ 16662' ELM. TIED INTO SHORT JTS FROM CBL/GR LOG. PERFD INTERVALS @ 16570' - 16575' RKB AND 16550' - 16570' RKB. POOH. ON SURFACE ALL SHOTS FIRED. RDFN AND NOTIFIED DSO OF STATUS. Alaska Oil & (~as Co~'~s. Commissm KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(2M-34(W4-6)) 2M-34 DATE 10/04/96 DAY 6 DAILY JOB SCOPE JOB NUMBER PERFORATE, PERF SUPPORT 0906960547.1 DAILY WORK UNIT NUMBER PERFORATE A SAND OPERATION COMPLETE I SUCCESSFUL I KEYPERSON SUPERVISOR NO NO SWS-BAILEY JORDAN InitialTbgPress IFinalTbgeress IlnitiallrmerAnn IFinallnnerAnn IlnitialOuterAnn I Final Outer Ann 1000 PSI 1100 PSI 750 PSI 800 PSI 0 PSI 0 PSI SUMMARY PERF A3 SAND INTERVALS @ 16546'-16550', AND 16526'-16546' W/SWITCHED 4' AND 20' X 2.5" HC GUNS (DP CHARGES-4 SPF-180 DEG PHASING-90 DEG ORIENTATION F/LOW SIDE OF HOLE) PERF A4 SAND INTERVAL@ 16475'-16495' W/20' X 2.5" HC GUN (DP CHARGES-3 SPF-180 DEG PHASING-90 DEG ORIENTATION F/LOW SIDE OF HOLE) RDFN TIME LOG ENTRY 15: 00 MIRU SWS E-LINE AND APE? DH PUMP. TGSM-PERF SAFETY PROCEDURES/EAPFT SFC LINE AND CHOKE 3000 PSI OK. PT LUB 3000 PSI OK. 16:45 RIH W/CCL, MPD, SWITCHED 4' AND 20'X 2.5" HOLLOW CARRIER GUNS (DP CHARGES-4SPF-180 DEG PHASING-90 DEG ORIENTATION F/LOW SIDE OF HOLE). 34' OVERALL/3.3' CCL-TOP SHOT OF TOP 20' GUN, 26' CCL-TOP SHOT OF BOTTOM 4' GUNRIH W/CCL, MPD, SWITCHED 4' AND 20' X 2.5" HOLLOW CARRIER GUNS (DP CHGS-4SPF-180 DEG PHASING-90 DEG ORIENTATION. F/LOW SIDE OF HOLE)34' OVERALL/3.3' CCL-TOP SHOT 20' TOP GUN. 26' CCL~TOP SHOT 4' BOTIDM GUN ~ 17:45 SFC-5000'-RAMP PUMP RATE UP FROM .5 BPM TO 3.5 BPM. MAINTAIN 3.5 BPM & RIH 18:30 TIE IN SJ. PERF INTERVALS @ 16546'-16550' AND 16526'-16546' WHILE MAINTAINING 700 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. POOH 20:15 ON SFC. ALL SHOTS FIRED 20:30 PT LUB/BOP 3000 PSI OK. 20:40 RIH W/CCL, MPD, 20' X 2.5" HOLLOW CARRIER GUN (DP CHGS-3 SPF-180 DEG PHASING-90 DEG ORIENTATION F/LOW SIDE OF HOLE). 3.5' CCL-TO TOP SHOT OF 20' GUN.INITIAL PUMP RATE .5 BPM. RAMP RIGHT UP TO 3.5 BPM @ 3000' ELM & RIH. 22:15 TIEIN SJ. PERF INTERVAL @ 16475'-16495' WHILE MAINTAINING 700 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. POOH 23:30 ON SFC. ALL SHOTS FIRED. RDFN ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A Kl(2M-34(W4-6)) WI.Il. 2M-34 DATE 10/05/96 DAY 7 JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERF C4 INTERVAL OPERATION COMPLE I'E NO SUCCESSFUL YES KEY PERSON SWS-BAII JEY JOB NUMBER 0906960547.1 UNIT NUMBER SUPERVISOR JORDAN Initial Tbg Press 900 PSI Final Tbg Press 600 PSI I Initial Inner Ann [ Final Inner Ann I 850 PSI I 350 PSI I Initial Outer Ann [ 0 PSI I Final Outer Ann 0 PSI DAILY SUM MARY IPERF C4 INTERVAL @ 1645°'-16475' W/SWITCHED 5' AND 20' x 2'5'' HC GUNS (DP CHARGES-2 SPF-° DEG PHASING-0 DEG I ORIENTATION F/LOW SIDE OF HOLE). PERFORATE NET PAY COMPLETE. RDMO SWS E-LINE. TIME LOG ENTRY 08:00 MIRU SWS E-LINE AND HOT OIL DHP. PT BOP, LUB OK. 10:00 RIH W/CCL, MPD, SWITCHED 5' AND 20'X 2.5" HOLLOW CARRIER GUNS (DP CHARGES-2SPF-0 DEG PHASING-0 DEG ORIENTATION F/LOW SIDE OF HOLE). INITIAL PUMP RATE .5 BPM.3.3' CCL-TOP SHOT OF TOP 20' GUN, 25' CCL-TOP SHOT OF BOTI'OM 5' GUN. 10:20 GUNS STOPPED AT 2800' ELM. INCREASE PUMP RATE TO MAX 3.5 BPM, CONTINUE RIH. 11:30 TIE IN SJ. MAINTAIN 730 PSI TBG PRESS. 11:50 PERF INTERVAL @ 16470'-16475' WHILE MAINT~G 730 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. RIH, LC~ UP 12:00 PERF INTERVAL @ 16450'-16470' WHILE MAINTAINING 730 PSI TBG PRESS. NO WEIGHT CHANGE/NO PRESS CHANGE. POOH 13:30 ON SFC. ALL SHOTS FIRED. 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" '"'-' - ..... -,_-..,- ,::, ~..::.:- %'6i. 5,{: ;:2;:.'" ~ -7560,4? -,{,:?}=5,?,-:, :. ?,'..!:i::--.: ,. :'.)5 1.5:"? .:bT --7772,24 -}"O,~.":i .; ] '.-}: i F'...x,qq. ,:."--, '"'" ...... .......... , ..... ,,., -...., .'_' ,.2,6 ~ ,_C :'.', O, ~'/ 0.-- /-. i 363,.,_'..,,~ 06 2;.,-'4,3 0'-7.' / ~-,82,4 275.:.,5 51'._;!?,27i.:::07:3:-3~ ;;"'.'¢i~88.~'.,'"'~'",,_-,,' 5200, OS i !300~ 2(; 75 ~4:'-;_ 2??-: ;!_,.-.'., 5246:75 '.;:1476,24 "~ ",: / ";' ~ Y"-5- 53H,67 11741,52 7'4,~d -7':-:.'$"_..' ,O;!. -7232:q8 ! ..... --SiS..':;,,:Y.L; -740!+?,7 j i0:}:5~ ,'5 c-,~-:/.,. .... r.., --,:---'.,:,,,,,6:¢-'"':?" _:-,..;: ~,::'"'" 1 "-.. :.f...; i '"~"" '::" '"" ":'~' 11477 -i:,.~:.'..=, ~:}--: -s.'._,' .." ,:i!C;L: .:- . ........ - ,:,/.'-;. 4:-: v: -., ,:*,,., + ,.: v k :. 74 ",5:+ {:,,. 44 (:... ?...--./.; ,3:, ,[:,7 }!i.75,;[ 5462,3{ .... ' ...... 27.~2 5605,72 ....... :oo~o.~ !7057,87 75,5~i 2%5.,?4 ':/i,'0? 218,1.1 -,~75;-~, 2(; --'."'.-'.";.-:'5:"" ., v i 70(:,2+,% '- .... ~"' ....... '-~ !'_.:!2:[7 2~ -'?375.., 5J.-S(i',i ii, :}2 12525'~ -,-.o:,c., .*.., --,::.w ~-: 4,5 '-[27??., 2:}:; ,%'? :-, 4 F 4 ..... -':'., 7,~ :-:,. --,55>:i,.75 i{.-:0'_:.;:!;:05: ! 564.7 .~ ~-"2 i.~5737 -_. (;2 ~t ~"-3£, 7 ~- "? '-~ ARCO Alaska, Inc. Date: September 11, 1996 Transmittal #: 9735 RETURN TO: ARCO Alaska, Inc. Attn.: Bethany Lilly Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. 3G-25 Cement Bond Log 07-25-96 3F-19 Cement Bond Log 07-27-96 3F-18 Cement Bond Log 07-26-96 3F-17 Cement Bond Log 07-27-96 2M-35 Cement Bond Log 07-28-96 2M-34 Cement Bond Log 07-31-96 Receipt (~~ Acknowledge Date' DISTRIBUTION: Sharon Allsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 2700-3520 7460-7876 6OOO-677O 6~60-7045 14000-14775 16240-1656O Chapman/Zuspan NSK Wells Group NSK69 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN- Sherrie NO. 10327 Company: 8/7/96 Alaska Oil & Gas Cons Comm Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2M-34 96170 CDR/CDN 960522 1 2M-34 CDR 960522 1 1 2M-34 :CDN 960522 I I SIGNED: ~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM TO: THRU: David Joh t~~ Chairma¢¢~'- State of Alaska Alaska Oil and Gas Conservation Commission DATE: July 30, 1996 Blair Wondzeli, P. I. Supervisor FROM- Bobby Fost~~ SUBJECT: Petroleum Inspector FILE NO: AFVIG4DD.DOC BOPE Test - Nordic Rig #2 ARCO - KRU - 2M-34 PTD # 96-0079 Kuparuk River Field Tuesdav, July 29,1996: I traveled this date to ARCO's KRU well 2M-34 being completed by Nordic rig #2 and witnessed the BOPE test. As the attached AOGCC BOPE Test Report shows there were 5 failures. Both the upper and lower pipe rams leaked, a kill line valve leaked, the HCR valve leaked and one of the Methane detectors failed. All of this equipment was repaired or replaced after I departed the location and I was notified by the tooipusher after the work was completed and tested. SUMMARY: i witnessed the BOPE test on Nordic rig #2 doing the completion work on ARCO's 2M-34 - 5 hours test time - 5 fa_.~..(cjJ~s. Attachments: AFVIG4DD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: Drlg Contractor: Nordic Rig No. 2 PTD # 90-0079 Rig Ph.# Operator: ARCO Alaska Inc. Rep.: MIKE ELLIS Well Name: 2M-34 Rig Rep.' SHANE Casing Size: 7" Set @ 10,699 Location: Sec. lg T, 11N R. IOE Meridian Umiat Test: Initial..__.._ Weekly X Other 7229/96 659-7115 MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P Well Sign P Drl. Rig P Hazard Sec. P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Test Pressure 500/3500 500/3500 500/3500 P 500/3500 P P/F BOP STACK: Quan. Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams 1 Choke Ln. Valves 1 HCR Valves 1 Kill Line VaNes Check VaNe Test Press. P/F 250/3000 P 500/3500 F/P 1 500/3500 F/P 500/3500 500/3500 500/3500 2 500/3500 N/A F/P F/P MUD SYSTEM: Visual Alarm Tdp Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector F/P P H2S Gas Detector P P CHOKE MANIFOLD: No. Valves 12 No. Flanges 32 Manual Chokes 1 Hydraulic Chokes 1 Test Pressure P/F 500/3500 P 500/3500 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure 0 System Pressure AttainedMastsr' 1 Blind Switch Covers: Nitgn. Btl's: Four Boffies 2100 Avg. 3,000 I P 2,25.0 P ~'f~,[~ut~ 16 sec. ~ minutes ~ sec. P Remedy--. P Psig. Number of Failures: 4 ,Test Time: 5.0 Hours. Number of valves tested 18 Repair or Replacement of Failed Equipment will be made within I days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: FAILURES: Both upper and lower pipe rams leaked- changed out and tested OK. The HCR valve leaked. repaired and tested OK. The outside kill line leaked - changed out and tested OK. A sensor on the methane gas detection had to be changed out. NOTE: All of this equipment was replaced or repaired after ! departed the location. Distribution: odg-Well File c- Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES NO X · I I Waived By: Wrtnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AFVIG4DD.XLS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension _ Stimulate _ Change approved program_ _ Perforate _ Other X.~ 6. Datum elevation (DF or KB) 99510 Pull tubing_ Variance 5. Type of Well: Development ~ Exploratory _ Stratigraphic _ Service -- 4. Location of well at surface 114' FSL, 392' FWL, Sec. 27, T11N, R8E, UM At top of productive interval 37' FSL, 1670' FWL, Sec. 5, T10N, R8E, UM At effective depth ORIGINAL At total depth 210' FNL, 1483' FWL, Sec. 8, TION, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 10646' feet Plugs None 4466' feet (Note: Effective depth: measured true vertical Length 80' 4073' measured N(~e true vertical 10646' feet Junk None 446 6' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Cemented 250 Sx AS I 730 sx AS III & 820 sx Class G Rig RKB 41' Pad level 106 feet 7. Unit or Property name Kuparuk River Unit Tubing (size, grade, and measured depth Nc~e Packers and SSSV (type and measured depth) None Size 16" 9 -5/8" 8. Well number 2M-34 9. Permit number 96-079 10. APl number 5o-103-20242 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool still drilling to TD at current time) Measured depth True vertical depth 121' 121' 4194' 2792' RECEIVED MAY 211996 Alasi~a 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal X Detailed operation program _ BOP sketch _ 14. Estimated date for commencing operation 5/23/96 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service I17.I hereby certify that th foregoing is true and correct to the best of my knowledge, Si~ned Title Drill Site Dev. Supv. ~' FOR COMMISSION USE ONLY Conditions of approval: qN~ti~ Commission so representa representa~ Plug integrity _ ~.~.J~D~..~,,,~---~-W~r~~ clea_ranc Mechanical Integ~' Approved by the order of the Commission-h--~ Form 10-403 Rev 06/15/88 ~"' ,..,..._~ IApproval _ .,.~ re~~lO- I~ // _ ~ CommissiOner - Dat~ ,~ /k3 //~'r- ~ ~~ SUBMIT I1~ TI~IISLICATE KRU 2M-34 Annular Pumping Permit Application Additional Information Please see the attached "Cementing Details" form for Well 2M-34 for basic details on the cementing operation. Additional information is offered below in support of ARCO Alaska Inc.'s opinion that the surface casing cement job will provide adequate sealing capability for annular pumping operations, and that the well has been cased and cemented according to regulation (AAC 25.030). Surface Hole TD: 4204' MD / 2796' TVD Surface Hole Conditions: No problems were seen while drilling in the surface hole. Tight spots were seen in the Ugnu while tripping from 2852' MD but were not seen during the later trip at TD. Casing was run to bottom without problems, with precautionary circulation occurring at 1900'. No fill was seen on bottom. All circulation while drilling and running casing saw full returns. Casing Placement: The fluted hanger was landed as planned. The surface casing shoe was placed at 4,194' MD, 10' off bottom. 10-20' off bottom is the planned standard with fluted casing hanger assemblies. -'--'- Cementing Details: Full returns were seen while circulating on bottom prior to cementing and during the cementing operation itself until partway through the displacement. Returns were suddenly lost when 286 bbls out of 315 bbls of displacement fluids had been pumped. Pump pressures continued to steadily increase at the same rate indicating that the cement column in the annulus was continuing to rise. Eight bbls of the 70 bbl water spacer which preceded the cement slurry was seen at surface at 278 bbls into the displacement, indicating that the cement had almost reached the surface. Excess on the lead cement was 150% (2.5 times the calculated gauge hole volume) and 15% on the tail cement. These excess factors are based on historical data and are calculated with the intent of bringing cement to surface during the primary job. Because cement was not seen at the surface, a top job was performed. A 1" line was run to 120' MD, the annulus was flushed with water, and cement was circulated to surface. No cause was found for the lost circulation other than the hydrostatic pressure caused by the cement. Data from the cement job indicates that cement entered the annulus and continued to rise in the annulus even after losing circulation. The water spacer was seen at surface prior to losing circulation. Previous 2M wells with lost circulation during the cement job have not shown any indications of problems during annular pumping operations (i.e., 2M-33). Based on the data, there should be an adequate seal for safe annular pumping operations. Diagnostic Logs: None. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510~0360 Telephone 907 276 1215 May 16, 1996 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Annular Pumping Approval for KRU Well 2M-34 Dear Mr. Johnston: Kuparuk River Unit Well 2M-34 was permitted to drill on May 2, 1996. The permit application included a request to approve this well for annular pumping operations for the period of one year. The application included information specified in the proposed regulations 20 AAC 25.080, but approval was contingent on the subsequent submittal of a Form 10-403 describing the well's surface casing cement job. Information included in the permit to drill application is not repeated here since it has already been submitted to the AOGCC. We believe that the 2M-34 surface cement job will provide an adequate seal for annular pumping operations and that the well has been cased and cemented according to regulation. ARCO Alaska, Inc., requests approval to commence annular pumping operations on this well as needed for waste disposal as described in the Permit to Drill application. Please note that this is the among the first attempts at obtaining annular pumping approval in this fashion, and the Commission's assistance is requested in structuring the application process to meet the needs of both the AOGCC and the operating companies. If you have any questions or input on the request for approval, please contact the Drilling Engineer, Denise Petrash at 263-4183, or myself at 265-6206. Sin,cerely, / Drill Site Development Supervisor AR3B-6003-93 242-2603 CASING AND LEAK-OFF FRACTURE TESTS Well Name: Supervisor: KRU 2M-34 Date: 5/14/1996 R, L. MORRISON JR. 9 5/8, 40#, L-80, BTC Casing Size and Description' Casing Setting Depth: Mud Weight: 8.6 41 94' TMD 2792' TVD ppg EMW = Leak-off Pressure (PLO) + MW 0.052 x TVD EMW = 580 psi / (0.052 x 2,792 ft) + 8.6 ppg ~ ~, ~ '~ ~ .G ~- ~'1 2, ~; 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 g00 8OO 70O 6OO 500 40O 3oo 20O 100 0 [] LEAK-OFF TEST ~ ~ CASING TEST1 === = STROKES ARCO Alaska, Inc. Well#: Casing Size 2M'34I~__75 °.,) Field: IKUPARUK Hole Diameter H~le Shoe Depth 12 1/4" Cementing Details Date: 5/1 3/96 Float Depth I % washout 9 5/8" Centralizers Mud Spacer Lead Cement Tail Cement Displacement 4,194' 4,105' -- State type used, intervals covered and spacing Ran 51 GEMECO bowspring centralizers. Run in center of first 2 its. and on next 49 collars. The float equip, was Weatherford. Weight I 0.2/1 0.0 Gels before 12/32 Type Water YP(prior cond) 28 lbs/100 ft2 Gels after 4/1 1 Type [Mix wtr temp AS 3 I 60 Additives .23 #/sk D29 YP(after cond) IPV(prior cond) 20 lbs/100 ft21 24 cP Total Volume Circulated 980 bbls Volume 7O No. of sacks 73O Additives G , 0.266 #/sk D29, 0.2% D46 0.3% D65, 1% S1 Rate(before tail at shoe) 8 Weight 12.1 PV(after cond) 15 cP Weight 8.3 PPG Yield 1.94 Reciprocation length 15' Theoretical Displacement 311.52 Weight 15.8 Yield 1.1 5 Calculated top of cement Surface top job. Qp 0453 5/13/96 Rate(tail around shoe) 6 BPM Reciprocation speed 10 fpm ~,ctual Displacement 315.02 Bumped plug I FIoats held NoI Yes Str. Wt. Up 180 Str. Wt, Dn 150 Str. Wt. Mud 150 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent Information. Reciprocated pipe while circulating and until top plug was dropped. Had full returns while circulating and cementing. Lost all returns after pumping 286 bbls of displacement, had 8.8 ppg fluid to surface 278 bbls into displacement. Displaced with 4 bbls. cement followed by 16 bbls. cement rinsate followed by 295.02 bbls.mud. Did not bump plug, floats held. Performed top job on annulus with 63 sx. (22 bbls.) AS3. Had 12.0 ppg returns to surface. Cement Company Dowell IRig Contractor Parker ISignature R. L. Morrison Jr. TONY KNOWLE$, GOVERNOR May 2, 1996 ~SI~A 01I, ANI) GAS 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi, Dflg En~ Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, 'AK 99510-0360 Re~ Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River Unit 2M-34 ARCO 'Alaska, Inc. 96-079 114'FSL, 392'FWL, Sec 27, T1 IN, R08E, UIVi 210'FNL, 1483'FWL, Sec 08, T10N, R08E, UM Dear Mr Zanghi: 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 operations until all other required permitting determinations are made. Approval for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic lop that were run. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J~h, aaston Chairman ~ BY ORDER OF THE COMMISSION ljb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ~ ALASKA OIL AND GAS CC~SERVA~ON COMMISSION PERMIT TO DRILL 20 AAC 25.005 1'~. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-En~ry E] Deepen r~ Service r'~ Development Gas E] Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 106' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25590, ALK 2676 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25,O2,5) 114' FSL, 392' FWL, Sec. 27, T11N, RSE, UM Kuparuk River Unit Statewide At top of productive intewal (@ TARGET ) 8. Well number Number 37' FSL, 1670' FWL, Sec. 5, T10N, R8E, UM 2M-34 #U-630610 At total depth 9. Approximate spud date Amount 210' FNL, 1483' FWL~ Sec. 8, T10N~ R8ET UM 5/1 3/96 $200~000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of ac,~es in property 15. Proposed depth (MD and TVD) property line 2M-17 16832' MD 3610 @ TD feet 10.5' @ 480' feet 2501 6390' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 700' feet Maximum holeangle 74.87° ~w.~ms~rfac~ 1654 pslg At total deplh (TVD) 3200 psig 18. Casing program Settir~ Depth size Specifications Top Bottom Quant~ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stave data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+_200 CF 12.25" 9.625' 40.0# L-80 BTC 4114' 41' 41' 41 55' 2794' 730 Sx Arcticset III & HF-ERVV 820 Sx Class G 8.5' 7' 26.0# L-80 BTCMOE 16791 41' 41' 16832' 6390' 170SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measu~'ed) true vertical feet Effective depth: measured feet Junk (measured) true vertical feel Casing ConductorStructural Length Size Cemented Meas~.L,ed~e~l~~,~ L L~ i V ~'~ [4 ' ~' ~ .~n~.E~'ertical depth Surface Intermediate ProductionAPR '1 8 '1 Liner Pedoration depth: measured AI~S~2~ Oil & GaS OOF1S. true vertical A,,[;I,~l 20. Attachments Filing fee X Property plat r~ BC~Sketch X Diverter Sketch X Ddlling program X Drilling fluid program X Time vs depth plot ~] Refraction analysis r-~ Seabed report ~-1 20 AAC 25.050 requirements X 21. I hereby certify tha~ the foregoirl{g is true and correct to the best of my knowledge Signed .' Title Drill Site Develop. Supv. Date ~ ~ / Commission Use Or~/ Permit Number 'TAP¥"r~ber I Approval date / / I See cover letter for ~ r,~ -~'~ 150- ~0'~ - ~,--0 ¢q,-c~.-00 ! 5'/"'~/~('r? I °ther req..~irements Condition's of approval Sampies required E] Yes [~ No Mud iogrequired' [-] Yes [~[ No Hydrogen sulfidemeasures ~ Yes [] No Directional surveyrequired ~ Yes r~ No Required working pressure for BOPE E] 2M ~ 3M E] 5M [~ 10M E] 15M Other: dr!gini! Stgn a dy David W. Johnstonby order of ~/' /("///, Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate , , . . . , . . . 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2M-34 Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,155')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (16,832') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve. Run cased hole cement bond logs on electric line. Secure well and release rig. Move in and rig up Nordic #2. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run completion assembly. Set packer and pressure test tubing and annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. DRILLING FLUID PROGRAM Well KRU 2M-34 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators General Notes: Weight up to TD 10.3 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,654 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2M-34 is 2M-17. As designed, the minimum distance between the two wells would be 10.5' @ 480' MD. Drilling Area Risks: Risks in the 2M-34 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 7" casing will be topset above the Kuparuk and Nordic Rig #2 will drill out a 6-1/8" hole, and run a 5" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.3 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ?.ECE1VED /:,,.~NULAR PUMPING OPERATIt..~S WELL KRU 2M-34 Incidental fluids developed from drilling operations will be pumped down the surface/production casing annulus of an existing well or the nearest dedicated disposal well (2M-23). (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2M-34 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2M-34 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. A list of all publicly recorded wells within 1/4 mile of the disposal operation is included in this permit application. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 200-300' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set _+100' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 3243 psi The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4 8 8 8 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 (g) (1). ARCO ALASKA, [nc. Pad 2M 34 slot ~r54 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT Baker Hughes [NTEQ Your ref : 34 Version ~6 Our ref : prop1474 License : Date printed : 11-Apr-96 Date created : 1-Dec-95 Last revised : 11-Apr-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is can~red on n70 16 17.458,w150 5 54.03 Slot location is n70 16 18.579,w150 5 42.618 Slot Grid coordinates are N 5948985.372, E 488232.651 Slot local coordinates are 114.00 N 392.00 E Reference North is True North Main calculation performed with 3-D Mini~.a~ Distance method Object wellpath 33 Version #11,,33,Pad 2H 9A Version #7,,9A,Pad 2M PMSS <3542-4022'>,,9,Pad 2M PGMS <O-12177'>,,9St,Pad 2M PMSS <O-3464'>,,23,Pad 2M PGMS <O-7119'>,,12,Pad 2M PMSS <O-10399'>,,6,Ped 2M PGHS <O-9810'>,,14,Pad 2M PGMS <O-7947'>,,17, Pad 2M PMSS <1579-3318'>,,1,Pad 2M PGMS <O-9800'>,~lA,Pad 2M PGMS <O-7855'>,,27, Pad 2M PGNS <O-9835'>,,28,Pad 2M PGMS <O-6765~>,,26,Pad 2M PGMS <O-7445'>,,25,Pad 2M PGMS <0 - 9130'>,,19,Pad 2M PGMS <O-7510'>,,3,Pad 2M PGMS <0 - 10598'>,,21,Pad 2M PGMS <0 - 7926'>,,18,Pad 2M Pr.~ls <0 - 12125'>,,13~Pad 2M Pr.~ts <O-7020'>,,15,Pad 2M PGMS <O-8931'>,,5,Pad 2M PGMS <O-9070'>,,20,Pad 2M PGMS <O-7800'>,,10,Pad 2M PGMS <O-7450'>f~24,Ped 2M PGMS <0 ' 9515'>,,11,Pad 2M PGMS <0-6848'>,,16,Pad 2M PGMS <0-10340'>~7,Pad 2M PGM$ <0-8598'>~,22,Pad 2M Closest approach with 3-D minin~Jn distance method Last revised Distance M.D. Diverging from M.D. 9-Apr-96 25.0 300.0 3480.0 5-Apr-96 2538.2 4155.0 7720.0 11-Nov-92 268.0 0.0 1400.0 5-Apr-96 268.0 0.0 1400.0 27-Apr-92 137.0 360.0 16800.0 11-Nov-92 147.8 1451.2 4980.0 11-Nov-92 313.0 0.0 460.0 22-0ct-92 88.0 0.0 0.0 22-0ct-92 10.5 480.0 480.0 5-Jan-93 373.0 0.0 1250.0 5-Jan-93 373.0 0.0 16501.1 11-Nov-92 382.7 1150.0 1150.0 22-0ct-92 400.1 620.0 620.0 22-0ct-92 201.9 120.0 120.0 1-Ju[-91 187.0 0.0 16460.0 3-Apr-92 37.0 0.0 16600.0 9-Apr-92 425.2 600.0 600.0 3-Apr-92 87.0 100.0 16820.0 3-Apr-92 12.0 120.0 16831.8 3-Apr-92 108.3 580.0 580.0 9-Apr-92 42.8 1100.0 1100.0 30-Jul-92 269.9 1467.5 1467.5 30-Jul-92 62.0 0.0 16454.0 3-Apr-92 195.0 1300.0 16631.8 30-Jul-92 1~1.1 300.0 16501.1 3-Apr-92 227.0 540.0 540.0 1-Jut-91 23.4 975.0 975.0 22-Feb-93 225.5 2950.0 8440.0 3-Aug-94 112.0 20.0 320.0 PGMS <0-13385 ~32,Pad 2M Pr.~s <O-9350,>,,30,Pad 2M PGNS <O-11003'>,,2,Pad 2~ PNSS <1078~-13015'>,,29,Pad 2~ PMSS <O-11241>,,29,Pad 2~ PC, MS <O-12151,,8,Pad 2N PC.~S <O-12370'>,,4,Pad 2~ 31 Version ~6,,31,Pad 2M 2M-G Version #~,,2M-G,Pad 2M 2M-F/M VersJon#4,,2M-F/M,Pad 2M 35 Version #8,,35,Pad 2M 18-Feb-93 11-Nov-92 11-Nov-92 8-Dec-95 1-Feb-93 6-Jan-93 11-Nov-92 1-Apr-96 13-Mar-96 13-Mar-96 lO-Apr-96 234.3 406.7 163,2 443.0 443.0 282.1 343.0 75.0 100.5 42.8 25.0 JO0.O 3860.0 3740.0 120.0 120.0 220.0 20.0 700.0 600.0 925.0 700.0 10700.0 3860.0 3740.0 12680.0 11000.0 10328.8 3411.6 700.0 600.0 925.0 10328.8 W e s f 1 ' 400.00 9600 8800 8000 7200 6400 5600 4800 4000 3200 2400 1600 800 0 800 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 800 SURFACE LOCATION: A D ~ ~r~ A T A ~VA T 114, FSL, 392' FWL Bose Permoffo~fl~ _ 0 ~ _ soo /EOC ~° Structure ; Pod 2M W~II ; ~4 , i west Sok Sonds Field : Kuporuk River Unit Loco$ion : Nodh Slope, Al~sko] 9 5/8 Comng P~ h~ _ 2400 CreWed by :j .... For: D PET~SH~ S 41 1 1 DEG W ~ _ 3200 Plot Reference is ~ Vemion ~6. ! ~ ! ~ ***P~NE OF PROPO~L*** ~ _ 4000 C~rdin~es ore in feet reference slot ~. } - 5600 _ _ 8000 _ 8800 _ _ 9600 0 _ . RKB ~A~ON: 147' Begin ~gle D _ ___ I KOP ~D=700 80U _ ~ 3.00 TMD=700 - I TD LOCATION: I o B FROST WD=1417 7MD=1455 DP=140 , , 1600_ ~27.00 / UGNU SNDS ~D=1447 ~D=1467 DEP=152 I 210' ~L, 1483' ~L I - ~36.o0 BUILD 3 DIe / ~00' I I SEC 8 TION RgE - ~;;.00 T/ W SAK SNDS W0=2021 TMD=2150 DEP:530 I · ' ' I 2400_ ~63 %~.00 Eoc WD=254~ TMD=31g6 DEP=1410 ~~ B/ W SAK SNDS ~D=26g4 TMD=3772 DEP:lg65 - ~ ~ ~ 9 5/8" CSG PT ~=2794 TMD=4155 DEP=2335 camp bsl. ~ ' ' ~ TABASCO SNOS WD=2942 TMO=4722 DEP=2881 3200_ XX MAXIMUM ANGLE ~0oo- ~~ 74.87 DEG ~ a~ac50 ~EGIN TURN 10 TARG~ WD=4319 IMD=10000 DEP=7970 - END TURN ~D=4405 mD=~0329 DEP=B2S7 4soo_ BEGIN ANGLE DROP WD~ TMD=15429 DEP=13199 - HRZ MIDPOI~ ~D=5921 TMD=15959 DEP=15694 5600_ B/ HRZ ~D=5970 ~D=16058 OEP=IS791 ~~ DROP 2 DEG / 1~' K--I MARKER ~D=6070 TMD=16268 DEP=15964 %C307~.~.oo T/ UNIT C / EOD ~D=6155 TMD=16425 DEP=14092 %~ 62.00 - ~5~6'00 T/ UNIT A ~D=6160 TMD=16451 DEP=14099 6~0_ TARGET ANGLE TARGET - T/ A3 SNDS TVD=6173 TMD=16454 DEP=14118 _n~oo DEG ~, / 7" CSG PT ~:8ggo TMD=I8832 DEP=14427 Y200 0 800 1600 2400 5200 ~00 4800 5600 6400 ~200 8000 8800 9600 ] 0400 11200 12000 ] ~800 ] 3600 ] 4400 ] 5200 Scale 1 · 400.00 Vertical Section on 221.11 azimuth with reference 0.00 N, 0.00 W from slot #34 tCre~ed by : jones For: D PETRASHi Dote plotted : l 1-Apr-96 Plot Reference is 54 Version j~6. ~Coordlnotes ore in feet reference slot #34. ITrue Vertical Depths ore reference RKB (Porker X245).i I I ¥ 28O 6O 40 0 260 240 220 I I I I I I 900 1000 200 180 I I Ai~CO ALASKA, Inc. Strucfure : Pod 2M Well : 34 Field : Kuporuk River Unit Location : North Slope, Alaska ~ Wesf 160 140 120 100 80 60 700 5500 3400 300 % % % lOO 140o 900 lOOO 11oo 1600 1300 1400 Scale 1 · 10.00 2o 40 60 22OO )oo 11oo 9OO 1000 60 40 ., 20 O O 0 20 40 60 80 © 160 I 180 _200 280 260 240 220 200 1 BO 160 140 120 1 O0 80 60 <-- Wesf 4O 0 20 40 60 Scole 1 ' 10.00 Creo~ed by : jones For: D PETRASIt Date plotted : 1 l-Apr-96 Plot Reference is 54 Version ~6. Coordino~es are in feet reference slot ~. T~e Ve~l Depths ore reference RKB (Po~er ~245). 80 120 760 720 680 640 600 I I I I ~I I 1900 ~00 1500 ARCO ALASKA, Inc. Structure : Pad 2M Well : 34 Field : Kuparuk River Unit Location : North Slope, Alaska < West 560 520 480 440 400 360 320 280 I I 1000 1500 6O0 11oo 4200 1400 1200 1500 1300 24O ,900 100o Scale 1 · 20.00 200 160 120 I I V 20O0 600_ _ 640_ _ 680_ _ 720_ 760_ _ 1800 800_ _ 840 I I I 760 720 I I 680 1800 160O I I I 640 600 1500 6O0 20O0 1800 2OO 1600 1900 kPR lS ""'~ 1700 1800 I I I I I I I 560 ;520 480 440 400 360 < Wesf 1500 320 1400 1500 1600 1700 24O 2200 I I I I I 200 160 120 Scale 1 · 20.00 _720 _ _760 _ _800 840 I I V 20" I JPARUK RIVER UNI DIVERTER SCHEMATIC 4 j 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) I 16" CONDUCTOR. r,~,,,,-.~,,', Oil :x 2. SLIP-ON WELD STARTING HEAD. ~,i,,~,~: ..... 3. DIVERTER ASSEMBLY WITH ONE 2-1/16'- 2000 PSI BALL VALVE. /- ..... ' ...... 'J" 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16' HCR KNIFE VALVE WITH 16' DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 1. 16" - 2000 PSI STARTING HEAD 2_ 11 "- 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 1;~5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-500OPSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KIH LINES 6. 1 35/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 1 35/8" - 5000 PSI ANNULAR 13 5/8" 5000 PS, E OP STACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. Ot3SERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 5 CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND FIOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6~ CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8, OPEN TOP PIPE RAMS AND CLOSE BO'I-rOM PIPE RAMS, TEST BOTTOM RAMS TO 250 PSI AND 30(X) PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING Jl' AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO 7ERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION, 11, TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY ~S AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL A~ATE 3-1/2' TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. WELL PERMIT CHECKLIST FIELD ~ POOL ~{ q 0! ~ 0 INIT CLASS 1-0;I PROGRAM: exp [] dev ~ redrll [] serv [] wellbore se9 [] ON/OFF SNORE (~ J~ ADMINISTRATION D~TE ENGINEERING 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ................... Lease number appropriate ................ Unique well name and number ............... Well located in a defined pool ............. Well located proper distance from drlg unit boundary. Well located proper distance from other wells ...... Sufficient acreage available in drilling unit ...... If deviated, is wellbore plat included ......... Operator only affected party .............. Operator has appropriate bond in force ......... Permit can be issued without conservation order ..... Permit can be issued without administrative approval. Can permit be approved before 15-day wait ........ REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg. . 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. N 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~,~ N 26. BOPE press rating adequate; test to ~6~7~ psig. ~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... -.Y ~J~- 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. · .~~----N~ 31. Data presented on potential overpres~ .... Y N 32. Seismic analysis of shallo~ ......... Y N ~i Seabed cond'ltio~s~~-~ off-shore) ........ Y ~ [exploratory only] p~,J~ GEOLOGY: ENGINEERING: COMMISSION: ~ ~ ~;~/' Comments/Instructions' " '"'"'~ / ~/_'_' l.?' -~ HOW/lib - A:~FORMS%cheklist rev 11/95 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. AUG 0 ~ 3996 O{I & Gas Co~s= .Commissio~ Ancho~e * ALASKA COMPUTING CENTER * . ****************************** . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2M-34 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20242-00 REFERENCE NO : 96170 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2M- 34 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20242-00 REFERENCE NO : 96170 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 6 ORIGIN : FLIC REEL NAME : 96170 CONTINUATION # : PREVIOUS REEL : COb~4F~VT : ARCO ALASKA, INC., KUPARUK 2M-34, API# 50-103-20242-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/ 6 ORIGIN : FLIC TAPE NAME : 96170 CONTINUATION # : 1 PREVIOUS TAPE : COf4PiENT : ARCO ALASKA, INC., KUPARUK 2M-34, API # 50-103-20242-00 TAPE HEADER KUPARUK RIVER MWD LOGS WELL NAME: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUblBER : LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL : ELEVATION(FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: BIT RUN 1 ......... 96170 BOSSE MORRISON WELL CASING RECORD 1ST STRING 2ND STRING 2M-34 501032024200 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 6-AUG-96 BIT RUN 2 ......... 96170 BOSSE LUTRICK BIT RUN 3 27 llN 8E 114 392 145.40 145.40 104.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 4200.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 3RD STRING PRODUCTION STRING Well drilled 13-MAY through 22-MAY-96 with CDR/CDN. All data was collected in two bit runs. $ $ PAGE: **** FILE H~ER **** FILE NA~E : EDIT .001 SERVICE : FLIC VERSION · O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED f4F~RGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 4104.0 16802.5 BASELINE DEPTH .............. 88888 0 16533 0 16530 5 16507 0 16498 0 16490 0 16483 5 16477 0 16470 5 16462 5 16457 5 16454 5 16439 5 16432 5 16427 5 16423 0 16402.5 16391.5 16361.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... MWD 88888.5 16533.5 16531.0 16508.0 16501.5 16493.5 16483.0 16477.5 16470.5 16464.0 16457.5 16454.0 16440.0 16432.0 16426.0 16422.0 16402.5 16391.0 16361.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE '. 16351.0 16337.5 16323.5 16321.5 16308.5 16300.0 16290.0 16277.0 16271.0 16260.5 16246.0 16243.0 16232.5 16224.5 16216.5 16213.5 16209.0 16203.0 16189.5 16129.0 16114.0 16111.5 16098.0 16079.5 16047.5 16032.0 16017.5 160 O1.5 15999.5 15995.0 15976.5 15962.0 15952.5 15924.5 15887.5 15877.5 15873.0 15861.5 15850.0 15838.0 15821.0 4200.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ 16350.5 16337.0 16322.0 16320.5 16306.5 16298.5 16289.5 16276.5 16270.0 16259.5 16244.5 16240.5 16230.0 16221.5 16214.5 16212.5 16206.5 16201.0 16188.0 16132 0 16116 5 16115 0 16101 0 16082 5 16050 5 16035 0 16021 0 16003 5 16002 0 15997 0 15978 0 15961 5 15953 5 15927 0 15889 0 15876 0 15870 5 15859 0 15852 5 15840 5 15822.5 4200.0 BIT RUN NO. MERGE TOP MERGE BASE 1 4104.0 16175.0 2 16175.0 16802.0 The depth adjustments shown above reflect the MWD GR to the CBT GR logged by SWS. Ail other MWD curves were carried with the GR. This file also contains the Very Enhanced QRO resisitivity with 2' average that LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: was reprocessed at GeoQuest. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630169 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0Pff4~630169 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD 0H~4~630169 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD 0tff4~630169 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD Okff4M630169 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD 014~ 630169 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630169 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630169 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630169 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630169 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630169 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630169 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630169 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630169 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CBT GAPI 630169 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: ** DATA ** DEPT. 16802.500 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD DEPT. 4104.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.~ -999.250 NPHI.MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD -999.250 GRCH. CBT -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD 52.900 GRCH. CBT -999.250 22.442 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 VRA . MWD FET.MWD PEF. MWD VRA .MWD FET.MWD PEF. MWD -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~iE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAi~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPI~ER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUNNUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SO?4MARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 4104.0 16175.0 $ LOG H~ER DATA DATE LOGGED: 22 -MAY- 96 SOFTWARE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (~EMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) .. HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : FAST 2.5 4.0 MEMORY 16800.0 4104.0 16802.0 90 57.3 75.5 TOOL NUMBER RGS059 NDS086 8.500 4200.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 690 MUD AT MAX CIRCULATIONG TE~fPERATURE : MUD FILTRATE AT (NIT): 2.160 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ******RUN 1 DRILLED 4204'-16175'***** RES TO BIT:42.55',GR TO BIT:52.97' DEN TO BIT:95.54',NEUT TO BIT 102.52' MISSING DATA CAUSED BY INT. BATTERY USE DATA FROM 15400'-16100' WITH CAUTION ******RUN 2 DRILLED 16175'-16802'***** RES TO BIT:23.45',GR TO BIT:33.87' DEN TO BIT:50.36',NEUT TO BIT 57.34' $ LIS FORMAT DATA 72.0 72.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NLWB SAMP ELEM CODE (HEX) 630169 O0 000 O0 0 2 1 1 4 68 0000000000 DEPT FT RA LW1 OttMM 630169 O0 000 O0 0 2 1 1 4 68 0000000000 RP LW1 OH~IM 630169 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 OHFiM 630169 O0 000 O0 0 2 1 1 4 68 0000000000 ROP LW1 FPHR 630169 O0 000 O0 0 2 1 1 4 68 0000000000 FET LW1 HR 630169 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630169 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 630169 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 630169 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 630169 O0 000 O0 0 2 1 1 4 68 0000000000 CAIiNLW1 IN 630169 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI LW1 PU-S 630169 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 16175.000 RA.LW1 -999.250 RP.LW1 -999.250 DER.LW1 ROP. LW1 134. 588 FET. LW1 -999. 250 GR. LW1 -999. 250 RHOB. LW1 DRHO. LW1 - 999. 250 PEF. LW1 -999. 250 CALN. LW1 - 999. 250 NPHI. LW1 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11 ..50 PAGE: DEPT. 4103.500 RA.LW1 -999.250 RP.LW1 -999.250 ROP.LW1 -999.250 FET. LW1 -999.250 GR.LW1 -999.250 DRHO.LW1 -999.250 PEF.LW1 -999.250 CALN. LW1 -999.250 DER. LW1 RHOB. LW1 NPHI. LW1 -999.250 -999.250 51.500 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ~ER 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SU~9~ARY VENDOR TOOL CODE START DEPTH MWD 16065.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TI~E) : TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) STOP DEPTH .......... 16802.5 22-MAY-96 FAST 2.5 4.0 MEMORY 16800.0 4104.0 16802.0 90 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: MINIMUM ANGLE: MAXIMUM ANGLE: 57.3 57.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ TOOL NUMBER RGS059 NDS086 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) '. 8.500 4200.0 BOREHOLE CONDITIONS MUD TYPE '. LSND MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S) : 50.0 MUD PH: 9.5 MUD CHLORIDES (PPM) : 500 FLUID LOSS (C3): 5.0 RESISTIVITY (OHb~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 2. 690 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT) : 2.160 MUD CAKE AT (MT): NEUTRON TOOL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REMARKS: ******RUN 1 DRILLED 4204'-16175'***** RES TO BIT:42.55',GR TO BIT:52.97' DEN TO BIT:95.54',NEUT TO BIT 102.52' MISSING DATA CAUSED BY INT. BATTERY USE DATA FROM 15400'-16100' WITH CAUTION ******RUN 2 DRILLED 16175'-16802'***** RES TO BIT:23.45',GR TO BIT:33.87' DEN TO BIT:50.36',NEUT TO BIT 57.34' $ LIS FORMAT DATA 72.0 72.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: 10 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFZB SAMP ELEM CODE (HEX) 630169 O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT RA LW2 OH~M 630169 O0 000 O0 0 3 1 1 4 68 0000000000 RP LW2 OH~k~630169 O0 000 O0 0 3 1 1 4 68 0000000000 DER LW2 OH~ff4630169 O0 000 O0 0 3 1 1 4 68 0000000000 ROP LW2 FPHR 630169 O0 000 O0 0 3 1 1 4 68 0000000000 FET LW2 HR 630169 O0 000 O0 0 3 1 1 4 68 0000000000 GR LW2 GAPI 630169 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LW2 G/C3 630169 O0 000 O0 0 3 1 1 4 68 0000000000 DRHO LW2 G/C3 630169 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LW2 BN/E 630169 O0 000 O0 0 3 1 1 4 68 0000000000 CALNLW2 IN 630169 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI LW2 PU-S 630169 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 16802.000 RA. LW2 ROP. LW2 22. 442 FET. LW2 DRHO . LW2 -999. 250 PEF. LW2 DEPT. 16065.000 RA. LW2 ROP . LW2 - 999.250 FET. LW2 DRHO . LW2 - 999.250 PEF. LW2 -999. 250 RP. LW2 - 999. 250 DER. LW2 -999. 250 GR. LW2 -999. 250 RHOB. LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 -999.250 RP.LW2 -999.250 DER.LW2 -999.250 GR.LW2 242.137 RHOB.LW2 -999.250 CALN. LW2 -999.250 NPHI.LW2 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 6-AUG-1996 11:50 PAGE: 11 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/ 6 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 6 ORIGIN : FLIC TAPE NAME : 96170 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2M-34, API# 50-103-20242-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 96/08/ 6 ORIGIN : FLIC REEL NAlViE : 96170 CONTINUATION # : PREVIOUS REEL : COF~IENT : ARCO ALASKA, INC., KUPARUK 2M-34, API# 50-103-20242-00
