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Home My WebLink About197-251C:\Users\aebell\Desktop\April 2021 Data Drop\CPA Data Drop 04082021\197251 Resubmitted Transmittal.docx Updated DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20147 KUP 3G-14A 50-103-20138-01 Caliper Survey 06-Apr-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 ***Updated 4/8/2021 data has been depth corrected per request*** Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 1972510 E-Set: 34923 Data Re-submittal Abby Bell Received by the AOGCC 04/13/2021 C:\Users\aebell\Desktop\April 2021 Data Drop\CPA Data Drop 04082021\2021-04-06_20147_06-Apr-21_3G-14A_CaliperSurvey_AOGCCTransmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 20147 KUP 3G-14A 50-103-20138-01 Caliper Survey 06-Apr-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE,INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM PTD: 1972510 E-Set: 34923 Received by the AOGCC 04/08/2021 Abby Bell ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 12, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ~ a`; ~,", -~d~~ ~,E i ~. ~~~~~ ®®®~ ~ ~ ~ ~®®9 g~~~®~ ~~ ~ q 7 ., ~ ~, VC Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, 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 was pumped February 15~' 2009. The corrosion inhibitor/sealant was pumped March 10~' and 11 ~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, i ~~ d > /. 9 0 . ~ r G .•'' M.J. Loveland ;~ l 'yam ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 3/1212009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3G-02 190-137 SF NA 16" NA 1.7 3/11/2009 3G-03 196-122 SF NA 16" NA 1.7 3/11/2009 3G-05 190-075 12'6" 1.80 19" 2/15/2009 4.25 3!10/2009 3G-06 190-069 8'4" 1.20 18" 2/15/2009 3.5 3/10/2009 3G-07A 190-085 25'6" 3.40 18" 2/15/2009 3.4 3/10/2009 3G-11 190-076 22" NA 22" NA 4.25 3/10/2009 3G-14A 197-251 SF NA 17" NA 3.4 3/10/2009 3G-17 190-122 5' 0.80 16" 2/15/2009 2.55 3/10/2009 3G-18 190-125 18" NA 18" NA 4.25 3/10/2009 3G-19A 201-106 18" NA 18" NA 2.55 3/10/2009 3G-21A 198-052 21' 2.80 2'10" 2/15/2009 12.75 3!10/2009 3G-25X 196-136 SF NA 7" NA 2.55 3/10/2009 THE MATERIAL UNDER THIS COVER HAs BEEN MICROFILMED ON OR BEFORE JANUARY 03 2001. M C:LORIhSffFILM.DOC PL ATE__ IA L U N _TH IS M ARK W DER E R Well Compliance Report File on Left side of folder 197-251-0 KUPAI~UK~~T 3~i4X 502 i03~20i3820i ~0 MD 0~770 TVD 060~3~0 /,,Completion Date: 5/9-/438 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8424 SPERRY MPT/GR/EWR4 OH 5/20/98 5/21/98 L DGR/EWR4-MD ~-'ff~AL 5820-7470 OH 5/28/98 5/28/98 L DGR/EWR4-TVD FL~NAL 5296-6031 OH 5/28/98 5/28/98 R SRVY CALC (.~h~95.51-7470. OH 6/9/98 6/12/98 R SRVY RPT PZ-g'fi~RY 5695.51-7479.O OH 6/2/98 6/19/98 Daily Well Ops cS~gt/)-IJ_~' ~Onnn~--__. ~ Are D~ Ditch Samples Required? yes ~nd Re~o Was the well cored? yes~ ..... Analysis Description R~~-Se~;T Sample ~ Comments: Monday, May 01, 2000 Page 1 of 1 .- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X__~. 85' RKB, 53' PAE 3. Address: Exploratory_~. 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 20' FEL, Sec 23, T12N, R8E, UM 3G-14A At top of productive interval: 9. Permit number/approval number: 1020' FSL, 1819' FEL, Sec 23, T12N, FI8E, UM 97-251 At effective depth: 10. APl number: 835' FSL, 2075' FEL, Sec 23, T12N, FI8E, UM 50-103-20138-01 At total depth: 11. Field/Pool: 783' FSL, 2147' FEL, Sec 23, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7470 feet Plugs (measured) None true Medical 6030 feet Effective Deptt measured 7370 feet Junk (measured) None true vertical 5986 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 216 Sx AS I 115' 115' Surface 3080' 9-5/8" 715 Sx AS III & 3115' 3115' 400 Sx Class G Production 5757' 7" 200 Sx Class G & 5789' 5276' Liner 1803' 3.5" 275 Sx Class G 7470' 6031' Perforation Depth measured 7130'-7160' true vertical 5878'-5892' Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, L-80 @ 5671' ._~!'~ -- Packers and SSSV (type and measured depth) ..,.~ Packer: Baker C-2 ZXP @ 567I' · $$S¥: None ! 3. Stimulotion or cement squeeze summory · Perforate "A2" sand on 5/15/98. Intervals treated (measured) 7130'-7160' Treatment description including volumes used and final pressure Perforated using 2-1/2" HC guns w/BH charges at 4 spt, 180 deg phasing, fp was 900 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 300 Subsequent to operation 61 68 1076 1080 167 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Repod of Well Operations ~X Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~'~~- Title: Production Engineering Supervi.s0.r Date f/-~/~ ~ ~.,,, Form 10-404 Rel~ 06x/ 15/88 SUBMIT IN DUPLICATE "ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ . ~LL SERVICE REPORT '~' K1(G-14A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-14A RIG SIDETRACK, SIDETRACK SUPT 0313981435.10 DATE_ DAILY WORK UNIT NUMBER 05/15/98 PERFORATE THE "A2" SAND DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 4 I~ Yes (') NoI (~ Yes O No SWS-JOHNSON SCHWEN~EF~MAN FIELD AFC# CC# DALLY COST ACCUM COS ~ Si~lned ESTIMATE 999055 230DS36GC $15,845 $43,851 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial,,~ut/ef Ann I Final Odter Ann - 300 PSI 900 PSI 0 PSI 0 PSII ~ 0 PSI I 0 PSI DAILY SUMMARY PERFORATE "A2" SAND F/7130' - 7160' W/2-1/2" HC/BH/4 SPF/180 DEG PHASING. TIME LOG ENTRY 08:30 MIRU SWS (JOHNSON & CREW) SLR, TGSM, EMER EVAC PLAN, JOB OVERVIEW. COMENCED RADIO SILENCE MU 2-1/2" HC, GUN#1 ASSEM (ROLLER/10' GUN/ROLLER/GR/CCL) TL=30', MU LUBRICATOR PT TO 3000 PSI 11:00 RIH HAD 300 PSI ON TUBING. TOOL STAOPPED AT 5890' ELM, WORKED DOWN TO 6020'. MADE MULTIPLE ATTEMPTS CONTINUE TO STOP AT 6020' ELM HARD. 13:30 POH REMOVED lQ' ~GUN AND MU SAME ASSEM AS ABOVE W/20' GUN TL=40'. 16:00 MU LUBRICATOR PT 3000 PSI. RIH TAGED DOWN HARD AT 6020' ELM. MADE SEVERAL RUNS AT IT, BROKE THRU AND RIH TAGGED DOWN AT 7372' ELM. LOG AND TIE IN W/SPERRY SUN MWD/ROP/DGR/EWR4, LOG 5/8/98. 17:00 APPLY 1000 PSI TUBING PRESSURE PERFORATE F/7140'- 7160' W/2-1/2" HC/BH/4 SPF/180 DEG PHASING. TUBING PRESSURE DROPPED AND STABLE AT 850 PSI. 18;.00 POH. LAID DOWN GUN ALL SHOTS FIRED. MU GUN ASSEM #2 2-1/2" HC (ROLLER/10' GUN/ROLLE .R/WT/CCL)TL= 27' ' ...... 20:00 RIH~ TOOL STOPPED AT 6185', HAD TO WORK TOOL DOWN TO 7250' LOGGED UP AND TIED IN. W/900 PSI ON TUBING PERFORATE F/7140' - 7130' 4 SPF/BH/180 DEG PHASING. TBG PRESS AT 900 PSI. POH. ' 21:30 AT SURFACE LAID DOWN GUN ALL SHOTS FIRED. RD EQUIP. 22:30 LF_AVE WELL SHUT IN RETURN BACK TO DSO. SERVICE COMPANY- SERVICE' DAILY COST ACCUM TOTAL $o.oo $60.00 APC $1,640.00 $7,890.00 DN HOLE PWR UNIT $0.00 $2,540.00 DOWELL $0.00 $7,000.00 EZSV- BRIDGE PLUG $0.00 $3,420.00 HALLIBURTON $0.00 $6,356.00 LITTLE RED $3,520.00 $5,900.00 SCHLUMBERGER $10,685.001 $10,685.00 TOTAL FIELD ESTIMATE $15,845.001 $43,851.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 5. Type of Well: 6. Datum of elavation (DF or KB feet): Development X. 85' RKB, 53' PAE Exploratory ~ Stratagrapic ~ Service 2. Name of Operator: ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 2538' FNL, 20' FEL, Sec 23, T12N, R8E, UM At top of productive interval: 1020' FSL, 1819' FEL, Sec 23, T12N, R8E, UM At effective depth: 835' FSL, 2075' FEL, Sec 23, T12N, R8E, UM At total depth: 783' FSL, 2147' FEL, Sec 23, T12N, R8E, UM 7. Unit or Property: Kuparuk River Unit 8. Well number: 3G-14A 9. Permit number/approval number: 97-251 10. APl number: 50-103-20138-01 11. Field/Pool: Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7470 feet Plugs (measured) None true vertical 6030 feet Effective Deptt measured 7370 feet Junk (measured) None true vertical 5986 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 216 Sx AS I 115' 115' Surface 3080' 9-5/8" 715 Sx AS Ill & 3115' 3115' 400 Sx Class G Production 5757' 7" 200 Sx Class G & 5789' 5276' Liner 1803' 3.5" 275 Sx Class G 7470' 6031' Perforation Depth measured 7130'-7160' true vertical 5878'-5892' Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 5671' Packers and SSSV (type and measured depth) Packer: Baker C-2 ZXP @ 5671' · SSSV: None 3. Stimulation or cement squeeze summary Reperforate "A2" sand on 5/17/98. Intervals treated (measured) 7130'-7150' Treatment description including volumes used and final pressure 14. Perforated using 2-1/2" HC guns w/BH charges at4 spt, 180 deg phasing, fp was 1400 psi. Representitive Daily Average Production or Injection OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 300 Subsequent to operation 61 68 1076 1080 167 15. Attachments MIT form Copies of Logs and Surveys run _ Dally Report of Well Operations ~X 16. Status of well classification as: Oil _X Gas _ Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~,~~ Title: Production Engineering Supervisor Date ~Yl,/ l'~J Form 10-404 Re~//(~6/15788 SUBMIT IN DUPLICAT~ ARco Alaska, Inc. KUPARUK RIVER UNIT ,~ ELL SERVICE REPORT '~ K1(G-14A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-14A FRAC, FRAC SUPPORT 0515981806.1 DATE DAILY WORK UNIT NUMBER 05/1 7/98 REPERFORATE "A2" SANDS F/7130'- 7150' DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR I {~ Yes (~') NoI (~ Yes 0 No SWS-JOHNSON SCHWEI~MAN FIELD AFC# CC# DALLY COST ACCUM COST ESTI MATE 999055 230 DS36G L $5,720 $67,770 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initia, J,~Ou/t~r Ann I Final Outer Ann IO00PSI 1400PSI OPSI OPSII ~'_,/ oPs~I OPSI DALLY SUMMARY REPERFORATE "A2" SANDS F/7130' - 7150' 2-1/2" HC/DH/4 SPF/180 DEG PHASING. TIME LOG ENTRY 15:00 MIRU, TGSM JOB OVERVIEW, RADIO SILENCE MU PERF GUN ASSEM 2-1/2" HC/BH/4SPF(ROLLER, 20' GUN, ROLLER, CCL) TL 31'. PT DOPE TO 3000 PSI. 17:00 RIH, TIE IN W/SWS PERF LOG DATED 5/15/98. W/1000 PSI ON TUBING PERFORATED F/7130' TO 7150' TUBING PRESSURE CLIMBED TO 1400 PSI, POH. 19:00 AT SURFACE RD ALL SHOTS FIRED. 20:00 RETURN WELL BACK TO DSO. \ SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,200.00 $13,000.00 DOWELL $8,000.00 $48,000.00 LITTLE RED $0.00 $1,250.00 SCHLUMBERGER $5,520.00 $5,520.00 TOTAL FIELD ESTIMATE $18,720.00 $67,770.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, inc. Development X. 85' RKB, 53' PAE 3. Address: Exploratory . 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface: 8. Well number: 2538' FNL, 20' FEL, Sec 23, T12N, R8E, UM 3G-14A At top of productive interval: 9. Permit number/approval number: 1020' FSL, 1819' FEL, Sec 23, T12N, R8E, UM 97-251 At effective depth: 10. APl number: 835' FSL, 2075' FEL, Sec 23, T12N, R8E, UM 50-103-20138-01 At total depth: 11. Field/Pool: 783' FSL, 2147' FEL, Sec 23, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7470 feet Plugs (measured) None true vertical 6030 feet Effective Deptl measured 7370 feet Junk (measured) None true vertical 5986 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 216 Sx AS I 115' 115' Surface 3080' 9-5/8" 715 Sx AS III & 3115' 3115' 400 Sx Class G Production 5757' 7" 200 Sx Class G & 5789' 5276' Liner 1803' 3,5" 275 Sx Class G 7470' 6031' Perforation Depth measured 7130'-7160' true vertical 5878'-5892' 0~/G//V4 L Tubing (size, grade, and measured depth) ~'~ ~'~"/ 3.5", 9.3 Ib/ft, L-80 @ 5671' Packers and SSSV (type and measured depth) Packer: Baker C-2 ZXP @ 5671' · SSSV: None '-~']~'~' 13. Stimulation or cement squeeze summary Fracture stimulate "A2" sand on 5/18/98. ' .... Intervals treated (measured) 7130'-7160' Treatment description including volumes used and final pressure Pumped 257,038 lbs of 20/40 and 12/18 ceramic proppant into formation, fp was 4015 psi. 14. Representitive Daily Average Production or Injection Data Oil-Bbl Gas-Mot Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 300 Subsequent to operation 61 68 1076 1080 167 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended _ Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~.~ ,~~ Title: Production Engineering Supervisor Date Form 10-404 Rev ~ SUBMIT IN DUPLICATE" ~ AR~CO Alaska, Inc. KUPARUK RIVER UNIT _ELL SERVICE REPORT K1(G-14A(W4-6)) WEL~. JOB SCOPE JOB NUMBER 3G-14A FRAC, FRAC SUPPORT 0515981806.1 DATE~ DAILY WORK UNIT NUMBER 05/18/98 PUMP "A" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 .{~ Yes (~') NoI (~ Yes O No DS-GALLEGOS JOHNS FIELD AFC# CC# DALLY COST ACCUM COST Signe~///' ,,-~ ~/' ESTIMATE 999055 230DS36GL $148,953 $217,615~' · Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer A~n' I Final ~r Ann 1400 PSI 1500 PSI 500 PSI 500 PSII 0PSI I - 50PSI DALLY SUMMARY I P UMP "A" SANDS FRAC WITH 257038# UP TO 144f PPA 12/18 PROPPANT AT PERFS. FLUSHED TO COMPLETION, LEAVING 700# PROPPANT IN PIPE. TIME LOG ENTRY 07:09 MIRU DOWELL FRAC EQUIP., LI'I-I-LE RED PUMP AND APC DIESEL TRANSPORT AND VACUUM TRUCK. 08:20 HELD JOB SITE SAFETY MEETING. 09:00 PRESSURE TEST TREATING LINES TO 9270 PSI. 09:05 PUMP 94 BBLS NON-XLINK GEL FOR BREAKDOWN 30 BPM AND 5548 PSI. PUMP 225 BBLS X-LINKED 50# GEL AT 15 BPM AND 6491 PSI. PUMP 25 BBLS WITH I PPA 20/40 PROP. 15 BPM AND 6084 PSI. PUMP 94 BBLS SEAWATER AT 15 BPM AND 4266 pSI. SHUT DOWN. 10:37 PUMP DISPLACEMENT, DATA FRAC AND FLUSH. 75 BBLS GEL AND 74 BBLS SEAWATER, 5 TO 15 BPM AND 5177 PSI. SHUTDOWN FOR ISIP 2147 PSI. 12:15 PUMP 155 BBLS OF 50# X-LINKED GEL AT 5 TO 15 BPM AND 4573 PSI. FOR PAD. 12:33 PUMP 17830# OF 20/40 AT 2PPA PROPPANT, AT 15 BPM AND 4097 PSI. 12:47 PUMP 249835 # OF 12/18 PROPPANT 6 TO 14 PPA, 15 BPM AND 3635 PSI. ' 14:00 PUMP 59 BBLS OF FLUSH, I'NCLUDING 35 BBLS OF DIESEL ON TAIL END FOR FREEZE PROTECTION. MAX TREATING PRESSURE 4015 PSI. SHUTDOWN, INFORMED LEAD OPERATOR OF WELL CONDITION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $7,800.00 $20,800.00 ARCO $400.00 $400.00 DOWELL $138,753.00 $186,753.00 HALLIBURTON $0.00 $892.00 LI'i-I'LE RED $2,000.00 $3,250.00 SCHLUMBERGER $0.00 $5,520.00 TOTAL FIELD ESTIMATE $148,953.00 $217,615.00 0 I::! ILI-- I I~1G S E FI~./I r' ~c: 02-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3G-14A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,695.51' MD 5788.00' MD 7,470.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 9, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3G-14A (Permit No. 97-251) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes made to the completion during the recent operations to sidetrack KRU 3G-14. 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 RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r~ GAS r-~ SUSPENDED E~ ABANDONED~] SERVICE r~ ARCO Alaska, Inc ~ 97-251 4 Location of well at sudace J ...... ~i_..~r ~~ 9 Unit or Lease Name 2538' FNL, 20' FEL, Sec. 23, T12N, R8E, UM ~ ~ t,fi [Fj[~.~ f' Kupamk River Unit At Top Producing Inte~alr~ [ '~ ' "" ;10 Well Number 1020' FSL, 1819' FEL, Sec. 23, T12N, R8E, UM 3G-14A At Total Depth 11 Reid ~d Pool 783' FSL, 2147' FEL, Sec. 23, T12N, RSE, UM KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Sedal No. Kupamk River Oil Pool Rig RKB 85', Pad 53'J ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or ~and. J 15 Water Depth, if offshore 16 No. of Completions 06-May-98 07-May-98 0~May-98I NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Dire~ional Su~ey 20 Depth where SSSV set 21 Thic~s of pe~akost 7470' MD & 6030' ~D 7370' MD & 5986' ~D YES ~ NO ~ N/A feet MD 1600' APPROX 22 T~e Ele~dc or ~her Logs Run 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5~ H-40 SURF. 115' 24' 216 sx AS I 9.625' 36.0~ J-55 SURF. 3115' 1225' 715 sx AS III, 400 sx Class G 7' 26.0~ 1-80 SURF. 5789' 8.5' 2~ sx Cla~ G 3.5' 9.3~ L-80 5646' 7470' 6.125' 275 sx Cla~ G 24 Perorations open to Produ~ion (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH S~ (MD) PACKER S~ (MD) 3.5' 5672' 5657' 7130'-7160' MD 5878'-5892' ~D 4 spf 26 ACID, FRACTURE, CEME~ .DEP~ INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7130'-7160' 257038~ up to 14~ ppa 1~18 proppant at peffs. 27 PRODUCTION TEST - ~ Method ~ ~ ' ~ Date First Produ~ion of Operation (FIo~ng, gas lift, etc.) ~,P ~ ~ ~ ~98 Rowing Date of Test Hours Tested PRODUCTION FO] OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE ~ GAS-OIL ~TIO ~27/98 20.00 TEST PERIOI: ~ 0 ~1 176~ 56 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 155 -]5 24-HOUR RATE: 70 4 ~7 25° 28 CORE DATA BHef description of lithology, porosity, fra~ures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7018' 5828' Bottom Kuparuk C 7040' 5838' Top Kuparuk A 7040' 5838' Bottom Kuparuk A 7283' 5947' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/20/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:3G-14A WELL_ID: 999055 TYPE: AFC: 999055 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD: START COMP:04/25/98 RIG:NORDIC BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20138-01 04/25/98 (C1) TD: 0' PB: 0' MOVING RIG TO 3G-14 SUPV:MC/DB Moving rig from 2T-202 to 3G-14. MW: 0.0 04/26/98 (C2) TD: 0' PB: 0' MOVING RIG TO 3G-14 MW: 0.0 SUPV:MC/DB Move rig from 2T-202 to 3G-14. Move over well and attempt to level rig. Incurred structural damage above drillers side rear hydraulic jack. Move off well to evaluate damage. Waiting on Nordic assessment of damage. 04/27/98 (C3) TD: 0' PB: 0' RIG REPAIR SUPV:MC/DB Rig repair. MW: 0.0 04/28/98 (C4) TD: 0' PB: 0' 04/29/98 (C5) TD: 0' PB: 0' 04/30/98 (C6) TD: 0' PB: 0' 05/01/98 (C7) TD: 0' PB: 6947' 05/02/98 (C8) TD: 0' PB: 6947' RIG REPAIR MW: 0.0 SUPV:DH Rig repair. Install braces between cantilever beams. Build wind break. RIG REPAIR SUPV:DH Continue to repair rig. MW: 0.0 RIG REPAIR SUPV:DH Rig repair. MW: 0.0 RIG REPAIR. MW: 0.0 SUPV:DH PJSM. DS ON FOOT AND BEAM FOR MAG PARTIAL INSPECTION. SPOTTING RIG OVER WELL. SUPV:DH PJSM. COMPLETE MAGNAFLUX OF ALL BEAMS. MW: 0.0 05/03/98 (C9) TD: 0' PB: 6947' RIH W/TBG TO LAY CMT PLUG MW: 9.6 LSND SUPV:DH RIG REPAIR. PJSM. ACCEPT RIG @ 0600 05/03/98. TEST BOPE TO 3500~. 05/04/98 (Ci0) TD: 0' PB: 6947' RIH, PICKING UP 3.5" DP MW: 9.6 LSND SUPV:DH Circ, ensure well is dead. RIH with tubing. POH, laying down tubing and jewelry. Set bridge plug @ 5812' 05/05/98 (C11) TD: 0' PB: 5820' RIH W/BHA ~2 MW: 9.6 LSND SUPV:DH Test casing to 3500#, ok. Mill window off whipstock from 5789 to 5820' Perform EMW test. 05/06/98 (C12) TD: 6380' PB: 5789' CBU F/WIPER TRIP @ 6654' SUPV:DH DRLG AND SURVEYS F/5820 T/6654' MW: 9.6 LSND 05/07/98 (C13) TD: 6380' PB: 5789' POH F/LINER SUPV:DH Drilling from 6380' to 7470' MW:ll.5 LSND 05/08/98 (C14) TD: 7470' PB: 7370' CUTTING DRILLING LINE SUPV:DH Run 3.5" liner. Pump cement. MW:ll.5 LSND 05/09/98 (C15) TD: 7470' PB: 7370' CLEANING MUD TANKS SUPV:DH Run 3.5" tubing. MW: 0.0 LSND 05/10/98 (C16) TD: 7470' PB: 7370' RIG RELEASED @ 0600 HRS 5 MW: 0.0 SUPV:DH Nipple down BOPE, NU tree and test. Release rig @ 0600 hrs. 5/10/98. End of WellSummary for We11:999055 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(3G-14A(W4-6)) WELL JOB SCOPE JOB NLJMBER ' " 3G-14A FRAC, FRAC SUPPORT 0515981806.1 DATE DAILY WORK UNIT NUMBER 05/18/98 PUMP "A" SANDS FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES DS-GALLEGOS JOHNS FIELD Signed ESTIMATE Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 1400 PSI 1500 PSI 500 PSI 500 PSI 0 PSII 50 PSI DAILY SUMMARY I -"brdt'w]5 PUMP "A" SANDS FRAC WITH 257038# UP TO 14# PPA 12/18 PROPPANT AT PERFS' FLUSHED TO COMPLETION ' ILEAVING 700# PROPPANT IN PIPE. TIME LOG ENTRY 07:09 MIRU DOWELL FRAC EQUIP., LITTLE RED PUMP AND APC DIESEL TRANSPORT AND VACUUM TRUCK. 08:20 HELD JOB SITE SAFETY MEETING. 09:00 PRESSURE TEST TREATING LINES TO 9270 PSI. 09:05 PUMP 94 BBLS NON-XLINK GEL FOR BREAKDOWN 30 BPM AND 5548 PSI. PUMP 225 BBLS X-LINKED 50# GEL AT 15 BPM AND 6491 PSI. PUMP 25 BBLS WITH 1 PPA 20/40 PROP. 15 BPM AND 6084 PSI. PUMP 94 BBLS SEAWATER AT 15 BPM AND 4266 PSI. SHUT DOWN. 10:37 PUMP DISPLACEMENT, DATA FRAC AND FLUSH. 75 BBLS GEL AND 74 BBLS SEAWATER, 5 TO 15 BPM AND 5177 PSI. SHUTDOWN FOR ISIP 2147 PSI. 12:15 PUMP 155 BBLS OF 50# X-LINKED GELAT 5 TO 15 BPM AND 4573 PSI. FOR PAD. 12:33 PUMP 17830# OF 20/40 AT 2PPA PROPPANT, AT 15 BPM AND 4097 PSI. 12:47 PUMP 249835 # OF 12/18 PROPPANT 6 TO 14 PPA, 15 BPM AND 3635 PSI. 14:00 PUMP 59 BBLS OF FLUSH, INCLUDING 35 BBLS OF DIESEL ON TAIL END FOR FREEZE PROTECTION. MAX TREATING PRESSURE 4015 PSI. SHUTDOWN, INFORMED LEAD OPERATOR OF WELL CONDITION. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3G-14A(W4-6)) WELL JOB SCOPE JOB NUMBER 3G-14A RIG SIDETRACK, SIDETRACK SUPT 0313981435.10 UNIT NUMBER DATE DAILY WORK 05/15/98 PERFORATE THE "A2" SAND DAY OPERATION COMPLETE I SUCCESSFUL 4 YES I YES .__ Initial Tbg Press I Final Tbg Press I Initial Inner Ann 300 PSII 900 PSII 0 PSI DAILY SUMMARY KEY PERSON SWS-JOHNSON SUPERVISOR SCHWENDERMAN Final Inner Ann I I 0 PSI Initial Outer Ann I 0 PSI I Final Outer Ann 0 PSI PERFORATE "A2" SAND F/7130' - 7160' W/2-1/2" HC/BH/4 SPF/180 DEG PHASING. TIME LOG ENTRY 08:30 11:00 MIRU SWS (JOHNSON & CREW) SLR, TGSM, EMER EVAC PLAN, JOB OVERVIEW. COMENCED RADIO SILENCE MU 2-1/2" HC, GUN#1 ASSEM (ROLLER/10' GUN/ROLLER/GR/CCL) TL--30', MU LUBRICATOR PT TO 3000 PSI RIH HAD 300 PSI ON TUBING. TOOL STAOPPED AT 5890' ELM, WORKED DOWN TO 6020'. MADE MULTIPLE ATTEMPTS CONTINUE TO STOP AT 6020' ELM HARD. 13:30 POH REMOVED 10' GUN AND MU SAME ASSEM AS ABOVE W/20' GUN TL=40'. 16:00 MU LUBRICATOR PT 3000 PSI. RIH TAGED DOWN HARD AT 6020' ELM. MADE SEVERAL RUNS AT IT, BROKE THRU AND RIH TAGGED DOWN AT 7372' ELM. LOG AND TIE IN W/SPERRY SUN MWD/ROP/DGR/EWR4, LOG 5/8/98. 17:00 APPLY 1000 PSI TUBING PRESSURE PERFORATE F/7140'- 7160' W/2-1/2" HC/BH/4 SPF/180 DEG PHASING. TUBING PRESSURE DROPPED AND STABLE AT 850 PSI. 18:00 20:00 POH. LAID DOWN GUN ALL SHOTS FIRED. MU GUN ASSEM #2 2-1/2" HC (ROLLER/10' GU N/ROLLER/WT/CCL)TL= 27' RIH. TOOL STOPPED AT 6185', HAD TO WORK TOOL DOWN TO 7250' LOGGED UP AND TIED IN. W/900 PSI ON TUBING PERFORATE F/7140' - 7130' 4 SPF/BH/180 DEG PHASING. TBG PRESS AT 900 PSI. POH. 21:30 AT SURFACE LAID DOWN GUN ALL SHOTS FIRED. RD EQUIP. 22:30 LEAVE WELL SHUT IN RETURN BACK TO DSO. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(3G-14A(W4-6)) WELL 3G-14A JOB SCOPE FRAC, FRAC SUPPORT JOB NUMBER 0515981806.1 DATE DALLY WORK UNIT NUMBER 05/17/98 REPERFORATE "A2" SANDS F/7130' - 7150' OPERATION COMPLETE I SUCCESSFUL YESI YES DAY 1 KEY PERSON SWS-JOHNSON Final Inner Ann I Initial Outer Annlo PSI 0 PSI Initial Tbg Press I Final Tbg Press Initial Inner Ann 1000 PSII 1400 PSI 0 PSI DAILY SUMMARY SUPERVISOR SCHWENDERMAN Final Outer Ann 0 PSI I REPERFORATE "A2" SANDS F/7130'- 7150' 2-1/2" HC/BH/4 SPF/180 DEG PHASING. TIME 15:00 17:00 LOG ENTRY MIRU, TGSM JOB OVERVIEW, RADIO SILENCE MU PERF GUN ASSEM 2-1/2" HC/BH/4SPF(ROLLER, 20' GUN, ROLLER, CCL) TL 31'. PT BOPE TO 3000 PSI. RIH, TIE IN W/SWS PERF LOG DATED 5/15/98. W/1000 PSI ON TUBING PERFORATED F/7130' TO 7150' TUBING PRESSURE CLIMBED TO 1400 PSI, POH. 19:00 AT SURFACE RD ALL SHOTS FIRED. 20:00 RETURN WELL BACK TO DSO. ~'%SURVEY CALCULATION AND FIELDWORKSHEETJob No. 0450-97492 Sidetrack No. 1 Page 1 of 1 i~~II~=L~ Company AflCO ALA§I~,A, INIC. Rig Contractor & No. Nordic Drilling - Rig #2 Field KUPARUK RIVER UNIT Well Name & No. PAD 3G/14A Survey Section Name Definitive Survey , BHI Rep. ERWIN SALVATIERRA ~J~r~ WELL ~ATA ...... , . _ 'Target TVD (F'D Target Coord. N/S Slot Coord, N/S -2538.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SSD :Target Description Target Coord. E/W Slot Coord. E/W -20.00 Magn. Declination 27,420 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m0 10mi"] Vert. Sec. Azim. 232.33 Magn. to Map Corr. 27.420 Map North to: OTHER i ii iii ! i i i SURVEY DATA .. Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F'D (DD) (DD) (FT) (F'l') !.FT) (F'~ (Per lO0 F'r)Drop (-) Left (-) GMS 5695.51 47.56 219.12 5212.76 1321.25 -949.37 -935.34 TIE IN POINT -- 106-MAY-98 MWD 5789.00 48.19 219.30 93.49 5275.47 1388.06 -1003.10 -979.17 0.69 0.67 0,19 KOP- INTERPOLATED !', 06-MAY-98 MWD 5955.58 61.91 217.85 166.58 5370.67 1520.33 -1109,67 -1063.99 8.27 8.24 -0.87 4 3/4' M 1C 1.5 DEG AKO ,06-MAY-98 MWD 5986.19 62.70 218.77 30.61 5384.90 1546.62 -1130.94 -1080.79 3.71 2.58 3.01 I 06-MAY-98 MWD 6017.97 64.39 219.84 31.78 5399.06 1574.34 -1152.95 -1098.82 6.11 5.32 3.37 "1 06-MAY-98 MWD 6049.74 65.61 224.43 31.77 5412.49 1602.67 -1174.29 -1118.13 13.64 3.84 14.45 06-MAY-98 MWD 6080.77 66.01 228.38 31.03 5425.21 1630.82 -1193.80 -1138.62 11.68 1.29 12.73 ......... 06-MAY-98 MWD 6113.25 66.65 232.89 32,48 5438.25 1660.54 -1212.66 -1161.62 12.87 1.97 13.89 , 06-MAY-98 MWD 6145.01 66.49 233.09 31,76 5450.88 1689.68 -1230.20 -1184.89 0.77 -0.50 0.63 ......... 06-MAY-98 MWD 6207.40 66.28 232.73 62.39 5475.87 1746.85 -1264.68 -1230.49 0.63 -0.34 -0.58 06-MAY-98 MWD 6302.66 65.54 231.61 95.26 5514.76 1833.81 -1318.01 -1299.17 1.32 -0,78 -1.18 ,,. , 07-MAY-98 MWD 6396.02 65.39 229,82 93.36 5553,53 1918.70 -1371.78 -1364.91 1.75 -0.16 -1.92 07-MAY-98 MWD 6491.87 65.12 230.93 95.85 5593.65 2005.69 -1427.30 -1431.95 1.09 -0.28 1.16 ............ , 07-MAY-98 MWD 6585.41 64.36 229.45 93.54 5633.57 2090.23 -1481.46 -1496.94 1.65 -0.81 -1.58 ,~'~ 07-MAY-98 MWD 6682.17 64.35 228.21 96.76 5675.44 2177.29 -1538.88 -1562.60 1.16 -0.01 -1.28 ...... 07-MAY-98 MWD 6777.49 63.15 231.49 95.32 5717.61 2262.68 -1594.00 -1627.92 3.33 -1.26 3.44 .... ,.. , 07-MAY-98 MWD 6873.73 62.74 234.98 96.24 5761.40 2348.36 -1645.29 -1696.56 3.26 -0.43 3.63 07-MAY-98 MWD 7057.73 63.45 233.58 184.00 5844.66 2512.34 -1741.09 -1829.77 0.78 0.39 -0.76 07-MAY-98 MWD 7253.38 63.46 234.66 195.65 5932.10 2687.28 -1843.67 -1971.58 0.49 0.01 0.55 07-MAY-98 MWD 7400.17 63.13 234.24 146.79 5998.07 2818.32 -1919.91 -2078.27 0.34 -0.22 -0.29 ..... 07-MAY-98 MWD 7470.00 63.13 234.24 69.83 6029.63 2880.58 -1956.31 -2128.82 0.00 0.00 0.00 Projected Data - NO SURVEY i i ii i i i i ii i i i Kuparuk Unit Kuparuk 3G 3G-14A S UR VEY REPORT May, 1998 Your Ref: API.50103201380t Last Survey 07-May-98 Job# AKMMS0207 KBE- 85.51' DRILLING C=ERVICE5 ORIGINAL Survey Ref: svylO Sperry-Sun Drilling Services Survey Report for 3G-14A Your Ref: API-501032013801 Kuparuk Unit Measured Depth (fi) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 5695.51 47.560 219.120 5127.41 5212.92 5787.00 48.190 219.300 5188.78 5274.29 5828.60 49.800 218.900 5216.07 5301.58 5860.07 53,360 218.600 5235.62 5321.13 5891.05 56.690 218.340 5253.38 5338.89 5923.34 58.930 218,080 5270.58 5356.09 5955.58 61.910 217.850 5286.49 5372.00 5986.19 62.700 218.770 5300.72 5386.23 6017.97 64.390 219.840 5314.88 5400.39 6049.74 65.610 224.430 5328.31 5413.82 6080.77 66.010 228.380 5341.03 5426.54 6113.25 66.650 232.890 5354.07 5439.58 6145.01 66.490 233.090 5366.70 5452.21 6207.40 66.280 232.730 5391.70 5477.21 6302.66 65.540 231.610 5430.58 5516.09 6396.02 65.390 229.820 5469.35 5554.86 6491.87 65.120 230.930 5509.47 5594.98 6585.41 64.360 229.450 5549.39 5634.90 6682.17 64.350 228.210 5591.27 5676.78 6777.49 63.150 231.490 5633.43 5718.94 6873.73 62.740 234.980 5677.22 5762.73 7057.73 63.450 233.580 5760.48 5845.99 7253.38 63.460 234.660 5847.92 5933.43 7400.17 63.130 234.240 5913.89 5999.40 7470.00 63.130 234.240 5945.45 6030.96 Local Coordinates Global Coordinates Dogleg Vertical. Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 949.07 S 934.24W 5987611.46 N 497423.80 E 1319.48 1001.65 S 977.14W 5987558.89 N 497380.89 E 0.704 1385.57 1026.01 S 996.93W 5987534.53 N 497361.09 E 3,938 1416.12 1045.24 S 1012.36W 5987515.31 N 497345.66 E 11.337 1440.09 1065.11S 1028.15W 5987495.44 N 497329.86 E 10,771 1464.73 1086.58 S 1045.05W 5987473.97 N 497312.96 E 6.971 1491.23 1108.68 S 1062.30W 5987451.87 N 497295.71 E 9.264 1518.39 1129.95 S 1079.10W 5987430.61 N 497278.90 E 3.707 1544.68 1151.96 $ 1097.12W 5987408.60 N 497260.87 E 6.113 1572.40 1173.30 S 1116.44W 5987387.26 N 497241.55 E 13.644 1600.73 1192.81S 1136.93W 5987367.76 N 497221.05 E 11.683 1628.88 1211.67 S 1159.93W 5987348.90 N 497198.06 E 12,868 1658.60 1229.21S 1183.20W 5987331.36 N 497174.78 E 0.767 1687.74 1263.69 S 1228.80W 5987296.90 N 497129.18 E 0.627 1744.90 1317.02 S 1297.48W 5987243.58 N 497060.48 E 1.325 1831.86 1370.79 S 1363.22W 5987189.82 N 496994,73 E 1,752 1916.75 1426.31S 1430.26W 5987134.32 N 496927.68 E 1.089 2003.75 1480.47 S 1495.25W 5987080.18 N 496862.68 E 1.645 2088.28 1537.89 S 1560.91W 5987022.77 N 496797.01 E 1.155 2175.35 1593.01S 1626.23W 5986967.67 N 496731.67 E 3.333 2260.74 1644.30 S 1694.87W 5986916.39 N 496663.02 E 3.257 2346.42 1740.10 S 1828.08W 5986820.62 N 496529.79 E 0,781 2510.40 1842.68 S 1969.89W 5986718.08 N 496387.96 E 0,494 2685.34 1918.92 S 2076.58W 5986641.86 N 496281.25 E 0.340 2816.38 1955.32 S 2127.13W 5986605.47 N 496230.69 E 0.000 2878.63 Comment Tie-in survey Window'Point Projected Survey Kuparuk 3G Continued... 14 May, 1998 - 10:39 - 2 - DrillQuest Sperry-Sun Drifting Services Survey Report for 3G-14A Your Ref: API-501032013801 Kuparuk Unit Kuparuk 3G All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from' Well and calculated along an Azimuth of 232.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7470.00ft., The Bottom Hole Displacement is 2889.28ft., in the Direction of 227.410° (True). 14 May, 1998 - 10:39 - 3 - DrillQuest WELL LOG TRANS~HTTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. .Anchorage, Alaska 99501 May 28, 1998 RE: MWD Formation Evaluation Logs 3G-14A, ,M~-MM-80207 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ .~i Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~, .Anchorage, AK 99518 3G-14A: 2" x 5" MD Resistivitv& Gamma Ray Logs: 50-103-20138-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20138-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. mi:IIi_LING c:EilR~/Ir'm c: WELL LOG TRANSMITTAL To: State of Alaska .Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~ 2'7- MWD Formation Evaluation Logs 3G-14A, May20,1998 AK-MM-80207 1 LDWG formatted Disc with verification listing. API#: 50-103-20138-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACH]gD COPY OF THE TRANSMITTAL LETTER TO THE ATrEN~ON OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. TONY KNOWLE$, GOVERNOR ALASi~A OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 31. 1997 Michael Zanghi Drilling Superintendent ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 ae~ Kuparuk River Unit 3G-14A ARCO Alaska Inc. Permit No: 97-251 Sur. Loc.: 2538'FNL, 20'FEL. Sec. 23, TI2N. R8E. UM Btmhole Loc: 871'FSL, 2096'FEL. Sec. 23. T12N. R8E. UM Dcar Mr. Zanghi: Enclosed is thc approved application for permit to rcdrill thc above rcfcrcnccd well. The permit to redrill docs 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 dctcrminations arc made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice max' be given bv contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christcnson Commissioner BY ORDER OF THE COMMISSION dlffEnclosurcs CC: Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X I lb Type of Well Exploratory Stratigraphic Test Development Oil X · Re-Entry Deepen Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 85', Pad 53' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547, ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 20' FEL, Sec. 23, T12N, RSE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1123' FSL, 1770' FEL, Sec. 23, T12N, R8E, UM 3G-14A #U-630610 At total depth 9. Approximate spud date Amount 871' FSL, 2096' FEL, Sec. 23, T12N, R8E, UM 1/1/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-15 7384' MD 1123' @ Target feet 25' @ surface feet 2560 6036' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 5787' feet Maximum hole angle 62.4° Maximum surface 3080 psig At total depth (TVD) 3725 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~lht Grade Couplin~l Length MD TVD MD TVD (include sta~le data) 6-1/8" 3-1/2" 9.3# L-80 EUE-mod 1747' 5637' 5173' 7384' 6036' 330 sxs Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 7040 feet Plugs (measured) true vertical 6162 feetORIGINAL Effective depth: measured 6947 feet Junk (measured) true vertica 6096 feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16" 216sxAS Ic,p E E i V3 ;D115' Surface 3078' 9-5/8" 715 sx ASIII, 400 sx Class 3115' Intermediate Production 6994' 7" 200 sx Class G 7031' 6156' LinerDEC '! 9 1997 Perforation depth: measured 6564'-6576', 6588'-6604', 6620'-6654' MD true vertical 5823'-5831', 5840'-5851' 5863'-5887' 'I-VD Alaska Oil ,t, fin.~ Rnn.~_ C,~mission 20. Attachments Filing fee X Property plat BOP Sketch X ~v~r~-~rt~e Ddlling program X Drilling fluid X program Time vs d~l~th plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoir~ is true and ~'orrect to the best of my knowledge (Contact William Isaacson at 263-4622 with questions.) Signed~ -d / Title Drilling Superintendent / ,,-,~"~ Commission Use Only ] nl~t~'er ",) I Approval date ~'q I See cover letter for Permit Number APl ~:) other requirements Conditions of approval Samples required Yes No ,~ Mud log required Yes __ No Hydrogen sulfide measures Yes ~ No__ Directional survey required Yes ,~' No __ Required working pressure forBOPE 2M __ 3M __ 5M "~ 10M __ 15M __ Other: ~'O¢ ~r"~'~'r P~¢"~~ ' ORIGINAL SIGNED Commissioner by order of Approved by' RC)_~_~ .~ .~..._ . ~Y the commission Date .......... Form 10-401 Rev. 7-24-89 3'hrfstensorl Submit in triplicate REDRILL PLAN SUMMARY Well 3G-14A Type of well (producer/injector)' Surface Location: Target Location: Bottom Hole Location- MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 2538' FNL, 20' FEL, SEC 23, T12N, R8E, UM 1123' FSL, 1770' FEL, SEC 23, T12N, R8E, UM 871' FSL, 2096' FEL, SEC 23, T12N, R8E, UM 7384' 6036' Nordic Rig 2 1-1-98 10 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casing 9.6 >25 15-35 85 -95 20-30 30-40 __ 8.5-9.5 Kick off to weight up 9.6-9.7 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 12.0 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page I Casing/Tubing Proqram: Hole size Csg/Tbg 6-1/8" 3-1/2", 9.3#, L-80, EUE-Mod Tubing 3-1/2", 9.3#, J-55, EUE-Mod Length Top (MD/'rVD) Btm (MD/TVD) 1747' 5637'/5173' 7384'/6036' 5608' 29'/29' 5637'/5173' Cement Calculations: Casing to be cemented: 3-1/2" in 6-1/8" open hole Volume = 330 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 55%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 3080 psi and is calculated using a gas column to surface. The expected leak-off at the window cut in the 7" casing is estimated at 14.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3725 psi and a gas gradient of 0.11 psi/ft, this shows that formation breakdown would not occur before a surface pressure of 3080 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi. See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 3G-14A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing is expected to have good quality cement up to and above the planned kick-off window, which should isolate the K-10 and K-5 from the sidetrack operations. If the Formation Integrity Test shows that the K-10 and K-5 intervals are not isolated and will not hold the desired equivalent mud weight, a cement squeeze at the window could be performed to help isolate these intervals. Off-set drilling data shows that wells in the area of 3G-14A have been drilled to TD with 12.4 ppg mud and no loses. The kick-off point in 3G-14A is below any zones which would be of pressure concern prior to weighting up for the Kuparuk interval. None Directional: KOP: Max hole angle: Close approach: 5787' MD / 5274' TVD 62.4° (in sidetrack portion) No Hazards 48.2° (in original portion) Page 2 Lo_~_cl_ in__cl Program: Open Hole Logs: Cased Hole Logs: GR/Resistivity GR/CCL Notes: All drill solids generated from the 3G-14A sidetrack will be hauled to CC-2A in Prudhoe Bay for grind and inject. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or to ~'~Farl<~r 245to be disposed by annular pumping o the perml e r~_pr i_~ ¢.r~nnec~bd to at That [Ime.~ JThe permitted well will be within the Kuparuk River Uni~' Page 3 RECEIVED ! 9 199 Alaska Oil & Gas Cons. C0mmissio-~ Anchorage KRU 3G-14A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. RU E-line unit. RIH with 3-1/2" Baker 'N-2' bridge plug for 9.3#/ft tubing and set at 6402' MD RKB (in middle of 15' pup below packer). Once set, bleed wellhead pressure to 0 psi and verify positive set of bridge plug. 2. RU slickline unit. RIH and pull dummy valve from GLM at 6314' MD RKB, leaving an open pocket. WORKOVER RIG WORK: 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Verify well is dead. Load pits w/water. Circulate well to water. 3. Set BPV. ND tree. NU and test BOPE. . Screw in landing joint. Pull tubing hanger to rig floor. Spot a 250' cement plug on top of permanent production packer and bridge plug in 3-1/2" tubing. Pull above cement plug top and reverse circulate tubing clean. POOH standing back tubing and laying down all jewelry. 5. PU Baker 7" 'N-I' permanent bridge plug on E-line. RIH and set bridge plug at 5812' MD RKB. POOH RD E-line. Test wellbore to 3500 psi, testing bridge plug and cement plug to ensure isolation from perforations. . MU and RIH with bottom trip whipstock and window milling assembly. Tag bridge plug and set down weight to set whipstock. Shear free with milling assembly, circulate well to milling fluid, and mill window in 7" casing. POOH LD milling assembly. 7. RIH w/ 6-1/8" bit, MWD / LWD, and steerable drilling assembly. Slide out window, kick-off well, and directionally drill to total depth as per directional plan. Short trip to window in casing. POOH. 8. Run 3-1/2" liner to TD w/150' of overlap to top of milled window. 9. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 10. Pressure test casing and liner lap to 3500 psi for state test. 11. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 12. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 13. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 8 days Expected Case: 10 days Upper Limit: 17 days No problems milling window, drilling new hole, or running completion. Difficulties encountered milling window, or drilling new hole. WSI 12/15/97 Page 4 ARCO ALASKA, Inc. Structure : Pad .~G Well : 14A Field : Kuparuk River Unit Location : North Slope, Alaska -< West {feet} Created U7 nn¢. For: B [SAACSON 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 Oote plotted : 17-Nov-97 I I I I I I I I I I I I I I I I I I I I I I I I 900 Plot Reference i~ Coordinatee ere ;n feet reference elot #14. I 7 Co$irig True Vertical Depths~ce RKB (Nordic Il). I SURFACE LOCATION: I 25.38' FNL, 20' FEL KOP - Sidetrack Pt SEC. 25, T12N, RSE i !ooo 11oo 1200 2375' (TO TARGET) 232.33 AZIMUTH ***Plane of Proposal*** Marker TARGET - To Tc Top Unit A: Top Unit A Base Kup Sand., TO - Casing Pt Base HRZ p 1300 0 1400 ~ --4- ! 500 ~ I 1123' FSL, 1770' FEL 1600 SEC. 25, T12N, RSE I TARGET TVD=5820 1700 TMD=6919 DEP=2375 SOUTH 1619 WEST 1750 TD LOCATION: 871' FSL, 2096' FEL SEC. 2.3, T12N. RSE 1800 1900 5100 5250 5400 5550 5700 5850 I--- 6000 I 6150 6500 49.07 KOP - SIDETRACK PT TVD=5274 TMD=5787 DEP=1387 ' ~ 56 16 DLS: 9.00 de§ per 100 ft D=5984 DEP=1547 · N~ ~..~~1"V0=5627 TMD=6502 DEP=2005 ~ '"'--.,... K-1 MARKER TVD=5755 TMD=6777 DEP=2250 %,. ~ TARGET T/ C4 TVD=5820 TMD=6919 DEP=2375 T/ UNIT A 1-VD=5829 TMD=6958 DEP=2592 '% '" LT %.. "'-....f/ UNIT A2 TVD=5857 TMD=6998 0EP=2445 %x "'~....T/ UN. IT A1 TVD=5906 TMD=7104 DEP=2539 KUP SNDS TV0=5943 TM0=718¢ 0EP=2609 _ % ~D - CSG PTTVD=6036 TMD=7384 DEP=Z787 62.36 DEG 1200 1.350 1500 1650 1800 1950 21 O0 2250 2400 2550 2700 2850 Verfic(~l Section (feet) -> Azimuth 232.3.3 with reference 0.00 N, 0.00 E from slot #14 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST PREVENTER 7 6 PIPE RAM ~ 5 BLIND RAM~= I MUD I cross4 3 P PE RAM LL~ I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. 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. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSETOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 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 BO'Iq'OM RAMS TO 250 PSI AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11 "- 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16" - 5000 PSI SINGLE GATE W/ BLIND RAMS 6.7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER RECEIVED i99T Alaska 0il & Gas Cons. Commission Anchorage NORDIC RI(; LEVEL I 73'-0' 25'-0" ~TIRES: 40--57 ~ SPIRAL STAIRS _ EMSCO F-800 TRIPLEX MUD PUMP '-" ..- 12'-4' -- 28'-6' 12'-4' EMSCO f-800 (~ TRIPLEX MUD PUMP SPIRAL . STAIRS cobol ICONSOLE 5Y -o' ~ RE)~OVAB~ BOP ENCLOSURE = 8'-0' ~- 5'-6"- ~ORDIC RIG g2 LEVEL 2 } /1~1 .... · ~ I'I I .,~,~ z~- .~ /I - ~ ~ , ~',11~ .... ~'~!c'~ fl i ~ --=:~--.. ~ ,,. II I I I I I1/ ~ 1- ~ 2~'-~ H~'T NORDIC RIG g2 LEVEL 3 I UNf~ I IsP°°L I USTE~ AIR HEA'IER MUD TANK 750 BBLS CHOKE MANIFOLD OF'F'IC£ HYDRAUUC RAC~ WATER TANK /GLYCOL TANK i 15'-6' 84'-0' 24'--0' 15'-6" ! 7'-11' -'-' · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~/~//~---~ ("b INIT CLASS W E L L NAM E/~2~¢:2/~,/' .~ ~ '//-Z2,,~ GEOL AREA ~::~ ? ~.~ PROGRAM: exp E] dev/~redrll/~ serv [] wellbore seg ~ ann. disposal para req ['i UNIT# ?//¢:~ ~ ON/OFF SHORE ~z~ ! ADMINISTRATION ENGINEERING GEOLOGY 1. Permit fee attached ..................... N 2. Lease number appropriate ................... Y N 3. Unique well name and number .................. Y N 4. Well located in a defined pool ................. Y N 5. Well located proper distance from drilling unit boundary .... N 6. Well located proper distance from other wells .......... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included . 9. Operator only affected party ................~N 10. Operator has appropriate bond in force ............ N 11. Permit can be issued without conservation order ...... N 12. Permit can be issued without administrative approval ...... N 13. Can permit be approved before 15-day wait .......... N REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................ Surface casing protects all known USDWs ........... Y ~ ~,.. CMT vol adequate to circulate on conductor & surf csg ..... Y CMT vol adequate to tie-in long string to surf csg ........ .,.¢-.,Y N CMT will cover all known productive horizons .......... ~,~N Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................ Ifa re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. ~N ~/ (g .._~'_ If diverter required, does it rneet regulations ...... N Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ ~ N BOPE press rating appropriate; test to "Z2~O'~ .psig. N Choke manifold complies w/APl RP-53 (May 84) ........ N t,/' Work will occur without operation shutdown ........... N Is presence of H:,S gas probable ................ N __ 30. Permit can be issued w/o hydrogen sulfide measures .... ,Y,, N~)Y N ' 31. Data presented on potential overpressure zones ...... 32. Seismic analysis of shallow gas zones ............. /N' 33. Seabed condition survey (if off-shore) ............ / Y N 34. Contact nan'~e/phone for weekly progress reports .... ,,,<.. Y N [exploratory only] GEOLOGY: ENGINEERI_NG' COMMISSION: B E W _~_~~/¢-../~i'/,' D W J ~ JDH ~ RNC~ CO Comments/Instructions' 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. Sperry-Sun Drilling Services LIS Scan Utility Wed May 20 10:15:21 1998 .Reel Header Service name ............. LISTPE Date ..................... 98/05/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/05/20' Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MM-80207 E. CRIBBS D. HEIMS ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 3G-14A 501032013801 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 20-MAY-98 23 12N 08E 2538 20 85.50 84.00 53.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 5789.0 6.125 7470.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM L GOETTINGER FOR S MOOTHART OF ARCO ALASKA, INC. ON 05/19/98. 5. MWD RUN 2 REPRESENTS WELL 3G-14A WITH API#: 50-103-20138-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7470'MD, 6031'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 5749.5 7417.5 RPD 5775.0 7424.5 RPM 5775.0 7424.5 RPS 5775.0 7424.5 RPX 5775.0 7424.5 FET 5789.0 7424.5 ROP 5820.0 7470.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 5820.0 7470.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type ................. J0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OMHM 4 1 68 20 6 R?D MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 5749.5 7470 6609.75 3442 5749.5 ROP 9.6099 1734.19 129.769 3301 5820 GR 43.2214 592.594 149.048 3337 5749.5 RPX 0.4665 2000 8.77895 3300 5775 RPS 0.5352 2000 8.56996 3300 5775 RPM 0.2494 2000 17.6839 3300 5775 RPD 0.1383 2000 13.6715 3300 5775 FET 0.3003 19.6816 1.33807 3272 5789 Last Reading 7470 7470 7417.5 7424.5 7424.5 7424.5 7424.5 7424.5 First Reading For Entire File .......... 5749.5 Last Reading For Entire File ........... 7470 File Trailer Service name ............. STSLIB.001 Service Sub Level Name,.. Version Number ........... 1.0.0 Date of Generation ....... 98/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/20 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPD RPM RPS RPX FET ROP $ LOG HEADER DATA DATE LOGGED:- SOFTWARE 5749.5 5775.0 5775.0 5775.0 5775.0 5789.0 5820.0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY 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: STOP DEPTH 7417.5 7424.5 7424.5 7424.5 7424.5 7424.5 7470.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 07-MAY- 98 ISC 5.07 DEPII 2.22A / SP4 5.03 MEMORY 7470.0 5820.0 7470.0 49.8 66.6 TOOL NUMBER P0882SP4 P0882SP4 6.130 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OH~4)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CA~KE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.1. LSND 11.50 42.0 9.2 2500 314 1. 020 .579 1.000 · 970 .6 Name Service Order Units Size Nsam Rep Code Offset DEPT FT 4 1 68 GR MWD 2 API 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 0 4 8 12 16 20 24 28 Channel 1 2 3 4 5 6 7 8 63.3 Name Min Max Mean DEPT 5749.5 7470 6609.75 GR 43.2214 592.594 149.048 RPX 0.4665 2000 8.77895 RPS 0.5352 2000 8.56996 RPM 0.2494 2000 17.6839 RPD 0.1383 2000 13.6715 ROP 9.6099 1734.19 129.769 FET 0.3003 19.6816 1.33807 Nsam 3442 3337 3300 3300 3300 3300 3301 3272 First Reading 5749.5 5749.5 5775 5775 5775 5775 5820 5789 Last Reading 7470 7417.5 7424.5 7424.5 7424.5 7424.5 7470 7424.5 First Reading For Entire File .......... 5749.5 Last Reading For Entire File ........... 7470 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/20 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/05/20 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/05/20 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File