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Home My WebLink About185-281Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file, Well History File Identifier Organization (done) ,~ Two-Sided RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. D Maps: [] Grayscale items: [] Poor Quality Originals: Other: [] Other, No/Type [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds TOTAL PAGES: ~' NOTES: ORGANIZED BY: ~BREN VINCENT SHERYL MARIA LOWELL DATE [] Other Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is/ SCANNED BY: ~REN VINCENT SHERYL MARIA LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: IS~ General Notes or Comments about this file: PAGES: Quality Checked (done) RevlNOTScanned.wpd From: NSK Problem Well Supv (n1617@conocophillips.comJ Sent: Thursday, May 14, 2009 1:16 PM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: NSK Probiem Well Supv Subject: 3A-13 (PTD 185-281) Report of failed TIFL Attachments: 3A-13 schematic.pdf; 3A-13 90 day TIO plot.jpg Tom, Jim ~ Kuparuk gas lifted producer 3A-13 (PTD 185-281) failed a diaano~ ' iFi on 05/13/09 and was added to the weekly SCP report. The TIO prior to the test was 110/860/350. A leaking GLV is suspected. Slickline will troubleshoot the GLV's and repair if possible. ~- Attached is a schematic and a 90 day TIO plot. l Please let me know if you have any questions. f.t~c,~~''~b~~~ i~ ~.~Ju~ '~ ':,: G.~~~ Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «3A-13 schematic.pdf» «3A-13 90 day TIO plot.jpg» 8/7/2009 KRU 3A-13 PTD 185-281 5/14/2009 TIO Pressures T/I/O P I ot - 3A-13 1200 1000 800 N a 600 400 200 0 ~+~+~ 14-Feb-09 27-Feb-09 12-Mar-09 25-Mar-09 07-Apr-09 Date 20-Apr-09 03-May-09 200 ~ 150 a E a~ 100 ~ Y O L V 50 0 ~ ~ E; , ~; _, ' ~c~nc~~oPhill~p~ A~~~ka, In~. SSSV (1800-1801, OD:2.875) Gas Lift MandreVVaNe 1 (2261•2262, OD:4.750) Gas Lift MandreWalve 2 (432a4321, 0 D:4.750) Gas Liit MandreWalve 3 (577r5776, OD:4.750) Gas Lift IandreVDummy VaNe 4 (6417-6418, OD:4.750) Gas Lift MandreWafve 5 (675~6756, 0 D:4.750) Gas Lift MandreWalve 6 (7063-7064, OD:5.460) PBR (7105-7106, OD:2.875) PKR (7117-7118, OD:6.151) NIP (71537154, OD2.875) TUBING (a7185, OD:2.875, ID:2.441) Perf (725&7274) Perf (727&7318) ~ KRU 3A-13 3A-7 3 API: 500292148900 Well T e: PROD An le TS: 36 de 7217 SSSV T e: LOCKED OUT Ori Com letion: 12/2/1985 An le TD: 35 de 7630 Annular Fluid: Last W/O: Rev Reason: TAG FILL Reference Lo : Ref Lo Date: Last U date: 11/15I2006 Last Ta : 7363 TD: 7630 ftKB Last Ta Date: 11/9/2006 Max Hole An le: 51 de 3850 Casin Strin - ALL STRINGS Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 107 107 62.50 H-40 SUR. CASING 9.625 0 3321 3178 36.00 J-55 PROD. CASING 7.000 0 7614 6300 26.00 J-55 Tubin Strin - TUBING Size To Bottom ND Wt Grade Thread 2.875 0 7185 5948 6.50 J-55 BTC Perforations Summa ' Interval ND Zone Status Ft SPF Date T e Comment 7258 - 7274 6007 - 6020 A-3 16 4 1/10/1986 IPERF 90 deg. phasing; 4" HJ II Csg Gun 7278 - 7318 6024 - 6056 A-2 40 4 1/10/1986 IPERF 90 deg. phasing; 4" HJ II Csg Gun Gas Lift M andr elsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2261 2257 Meria TMPD GLV 1.0 BK 0.156 1325 8/15/1997 2 4320 3839 Merla TMPD GLV 1.0 BK 0.188 1356 8/15/1997 3 5775 4874 Merla TMPD GLV 1.0 BK 0.188 1346 8/15/1997 4 6417 5355 Merla TMPD DMY 1.0 BK 0.000 0 1/10/1986 5 6755 5611 Merla TMPD GLV 1.0 BK 0.250 1443 8/4/1998 6 7063 5851 Merla TGPD OV 1.5 RK 0.250 0 9/4/1999 Other lu s, e ui ., et c. - JEWE LRY De th TVD T e Descri tion ID 1800 1800 SSSV Baker'FVL' Locked Out 8/17/89 Pulled WRDP on 10/9/95 2.312 7105 5884 PBR BOT 2.500 7117 5893 PKR BOT'HB'w/XO 3.000 7153 5922 NIP Camco'D' Ni le NO GO 2.250 7184 5947 SOS BOT 2.441 7185 5948 TTL 2.441 General Notes Date Note 6/2/2005 WAIVEREDWELL: IAxOA COMMUNICATION • • • ConocoPh~llips ~ ~ ~~~ ~ :~_ ~~~ :. Alaska P.O. BOX 100360 ~ P ~ ~-~- (~ e, ;~ ANCHORAGE, ALASKA 99510-0360 %«~ _., ~~~hos;~ April 17, 2009 Mr. Tom Maunder ~ 1 Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 ~ ~ '~ Anchorage, AK 99501 -_ ~ - .~ ~ . ti ,; -~. s~Cwi~ . ~ ~JG~ Dear Mr. Maunder: 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 March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 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, Perry Klein 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 4/1712009 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 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6!2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Julie Heusser, Commissioner Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: Petroleum Inspector DATE: January 7, 2001 Safety Valve Tests Kuparuk River Unit 3A & 3B Pads Sundayt January 7t 2001' I traveled to the Kuparuk River Field and witnessed the semi-annual safety valve system testing on 3A & 3B Pads. As the attached AOGCC Safety Valve System Test Reports indicate I witnessed the testing of 8 wells and 16 components on 3A Pad and 6 wells and 12 components on 3B Pad with 1 failure observed. The surface safety valve on well 3A-08 had a slow leak when pressure tested. This valve will be serviced and retested by the operator. John Arend conducted the testing today he demonstrated good test procedure and was a pleasure to work with The wellhouses on these two pads were very clean and all related equipment appeared to be in good condition. Summary: I witnessed the semi annual SVS testing at 3A & 3B Pads in the Kuparuk River Field. KRU 3A Pad, 8 wells, 16 components, KRU 3B Pad, 6 wells, 12 components, 19 wellhouse inspections 1 failure 0 failures Attachment: SVS KRU 3A Pad 1-7-01 CS SVS KRU 3B Pad 1-7-01 CS . X Unclassified Confidential (Unclassified if doc. Removed) Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: _Kupamk / KRU / 3A Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3A-01 1851860 64 70 50 P P OIL 3A-03 1852060 3A-05 1852210 64 70 50 P P OIL :3A-08 1852240 64 70 60 P 4 OIL 3A-09 1811940 64 70 60 P P OIL 3A-12 1852390 64 70 60 P P OIL 3A-13 1852810 64 70 40 P P OIL 3A-16 1852840 64 70 70 P P OIL 3A-17 1961320 3A-18 1961330 64 70 50 P P OIL Wells: 8 Components: 16 Failures: 1 Failure Rate: 6.3% [] 90 my Remarks: Surface Safety Valve on well 3A-08 had a slow leak when tested, vzlve to be service retested by operator. 1/9/01 Page 1 of 1 SVS KRU 3A Pad 1-7-01 CS.xls . . Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: John Arend AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk/KRU / 3B Pad Separator psi: LPS 64 HPS 1/7/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE i 3B-03 1850600 64 70 60 P P OIL 3B-04 1850610 64 70 50 P P OIL! 3B-06 1850760 64 70 50 P P oIL 3B-08 1850870 3B-09 1851130 64 70 70 P P OIL 3B-11 1851150 64 70 50 P P OIL 3B-13 1850230 3B-14 1850240: Wells: 6 Components: 12 Failures: 0 Failure Rate: [] 90 Day Remarks: Good Test Pad 1-7-01 CS.xls STATE OF ALASKA ALA~dKA OIL AND GAS CONSERVATION COMMISo,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 817' FSL, 825' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1217' FNL, 927' FEL, Sec. 7, T12N, R9E, UM At effective depth 1059' FNL, 950' FEL, Sec. 7, T12N, R9E, UM At total depth 999' FNL, 958' FEL, Sec. 7, T12N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 763O 6312 6. Datum elevation (DF or KB) RKB 72 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-13 9. Permit number/approval number 85-281 10. APl number 50-029-21489-00 1 1. Field/Pool Kuparuk River Field/Oil Pool feet feet feet Plugs (measured) None Effective depth: measured 7 5 2 3 true vertical 6 2 2 4 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 195 Sx AS II 1200 Sx AS III & 300 Sx Class G 400 Sx Class G & 175 Sx AS I 80' 16" 3290' 9-5/8" 7590' 7" measured 7258'-7274',7278'-7318' true vertical 6007'-6020',6023'-6056' Measured depth 85' 3321' 7614' True vertical depth 85 3178 6299 Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., J-55 @ 7185' Packers and SSSV (type and measured depth) Pkr: Baker 'HB' @ 7117'; SSSV: Baker FVL @ 1800' (Locked open) 13. Stimulation or cement squeeze summary Refracture "A" sands on 8/10/97. Intervals treated (measured) 0RIGJNAL 7258'-7274',7278'-7318' Treatment description including volumes used and final pressure Pumped 245 M lbs 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 4925 psi. 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 665 399 0 1125 164 Subsequent to operation 1114 1327 0 1144 200 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Form ~/~40'"4 ~e~Ob'~J~ I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent SUBMIT IN DUPLICATE 1jAN 0 1998 A~CO Alaska, Inc. KUPARUK RIVER UNIT __ WELL SERVICE REPORT K1(3A-13(W4-6)) WELL JOB SCOPE JOB NUMBER 3A-13 FRAC, FRAC SUPPORT 0731971910.8 DATE DAILY WORK UNIT NUMBER 08/10/97. REFRAC A SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 t~) Yes O NoI (~) Yes (~ No DS-YOKUM KRALICK ESTIMATE KD1423 230DS36AL $103,166 $113,298 , InitialTbqPress Final~qPre~ InitiallnnerAnn FinallnnerAnn~ ~ ~, InitialO~s ! FinalOuterAnn 0 PSI 1800 PSI 379 PSI 500 PSI I 350 PSI DALLY SUMMARY REFRAC A SAND - PUMP TO COMPLETION - 245.000# IN PERFS - 1006¢ 10/14 IN WELLBORE I TIME LOG ENTRY 06:30 MIRU DS AND LR-I'LE RED 07:00 SAFETY MEETING 07:30 PRIME PUMPS AND PRESSURE TEST 08:00 P/T GOOD TO 10,000 PSI - SET TREE SAVER 08:05 08:25 08:30 PUMP PULSE @ 100 PSI DELTA P 08:45 PUMP SECOND PULSE @ 450 PSI DELTA P 09:00 DATA FRAC - START AT 5 BPM AND UP TO 15 BPM PER PROCEDURE 09:16 BREAKDOWN W/DEl_AY XL GW #50- 25 BPM 100 BBL STAGE TO BEGIN WITH - 6750 PS! S/D - ISlP 1773 PSI - CLOSURE PF!ESSURE @ 1355 PSI S/D - ISIP 1880 PSI- CLOSURE 1483 PSI- CLOSURE TIME 16.6 MIN FINAL TREATING PRESSURE 3765 PSIG - SUBTRACT 50 BBLS PAD (300 BBL TOTAL PAD) STAGE 1 OF FRAC 50# DELAY XL GW 5 BPM / 300 BBLS - UP TO 15 BPM AS.PER PROCEDURE 10:00 11:34 DROP ACTIVATOR AND RATE TO 14 BPM @ 4775 PSIG -CONTINUE DROPPING RATE TO 7 BPM TO Al-TEMPT TO FORCE SCREENOUT 11:45 3985 PSIG LAST PRESSURE- FLUSH JOB TO COMPLETION - 246,006 TOTAL PROP PUMPED - 245,000# PROP IN FORMATION -1006# PROP IN WELLBORE - 14,000 LB OF 13# 10/14 PROP @ PERFS 14:00 BLEED BACK ANNULUS TO 500 PSIG / RDMO LITTLE RED AND DS - 6800 PSIG MAX PRESSURE SEEN DURING BREAKDOWN SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $777.00 APC $5,750.00 $5,750.00 DOWELL $94,416.00 $94,416.00 HALLIBURTON $0.00 $4,516.00 LITTLE RED $3,000.00 $7,840.00 TOTAL FIELD .ESTIMATE $103,166.00 $113,299.00 STATE OF ALASKA A~ OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown __ Stimulate X Plugging Perforate _ Pull tubing Alter casing Repair well Other 2. Name of Operator 5. Type of Well' 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ 7g' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 817' FSL, 825' FEL, Sec. 7, T12N, R9E, UM 3A-13 At top of productive interval 9. Permit num~)er/ap_proval number 1217' FNL, 927' FEL, Sec. 7, T12N, R9E, UM 85-281 // At effective depth 10. APl number 1062' FNL, 935' FEL, Sec. 7, T12N, R9E, UM 50-029-21489 At total depth 11. Field/Pool 999' FNL, 958' FWL, Sec. 7, T12N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7 6 3 0 feet Plugs (measured) true vertical 631 2 feet Effective depth: measured 7523 feet Junk (measured) true vertical 6224 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 5 9' 1 6" 195 SX CS II 1 0 7' 1 0 7' Surface 3273' 9 5/8" 1200 Sx AS III & 3321' 31 78' Intermediate 300 SX Class G Production 7 5 6 6' 7" 400 Sx Class G & 7 61 4' 6 2 9 9' Liner 175 Sx AS I Perforation depth: measured 7258'-7274', 7278'-7318' true vertical 6007'-6020', 6024'-6056' Tubing (size, grade, and measured depth) 2-7/8", 6.5 Ib/ft, J-55 EUE Tbg; Tail @ 7185' MD Packers and SSSV (type and measured depth) Brown HB Packer @ 7117', Baker FVL SSSV @ 1800' 13. Stimulation or cement squeeze summary Intervals treated (measured) 7258'-7318' Treatment description including volumes used and final pressure 702 BBL GW Pad; 436 BBL GW Slurry; 98M lbs Carbo-Lite in formation, FP = 5000 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl GasoMcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3 4 5 3 5 7 1 2 1 0 0 0 1 5 8 Subsequent to operation 1 3 9 0 1 5 6 0 - 0 - 7 0 0 2 2 7 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector 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 ~~ g' ~~/-'~' Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCOAlaska, In, {) Sul3~icliary of Atlantic Ricrffiei(~ ComD~ny WELL. ?~- ?~ '3NTRACTOR REMARKS FIELD- DISTRICT- STATE OPERATION AT RE~ TIME WELL SERVICE REPORT IDAYS DATE / ' ~-/?-~o / y'oo [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeathM I Temp. I Chill Factor Visibility i WInd VM. Report I °F , °F milel I /"~o c ARCO Alaska, Inc 0 Sul~idla~y of Atlantic Richfield ComDany WELL · ~-/.~ NTRACTOR ,/--/~4 (./~,~7-o,,J REMARKS WELL SERVICE REPORT JFIELD - DISTRICT- STATE OPERATION AT REPORT TIME l DAY,~.. iDATE f [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVA~ ~ APPLICATION FOR SUNDRY APPROVALS ~'. Type of Request: Abandon Suspend _ Operation Shutdown Re-enter suspended well I Alte~ casing _ Repair well Change approved program _ _ Plugging _ Pull tubing _ Time extension _ Stimulate ,~ Variance Perforate Other I w 2. Name of Operator ARCO Alaska. Ipc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ 4. Location of well at surface 817' FSL, 825' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1217' FNL, 927' FEL, Sec. 7, T12N, R9E, UM At effective depth 1062' FNL, 935' FEL, Sec. 7, T12N, R9E, UM At total depth 999' FNL~ 958' FWL~ Sec. 7r T12Nr R9E~ UM 12. Present well condition summery Total Depth: measured 7 6 3 0 feet true vertical 63 1 2 feet Effective depth: measured 7 5 2 3 feet true vertical 6 2 2 4 feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) FIKB 72 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-13 g. Permit number 85-281 10. APl number 5o-02 9-21 489 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing I_englh Size Cemented Measured depth True vertical depth Structural Conductor 5 9' 1 6" 195 Sx AS I 1 0 7' 1 0 7' Surface 3273' 9 5/8" 1200 Sx AS III & 3321' 31 78' Intermediate 300 Sx Class G Production 7 5 6 6' 7" 400 Sx Class G 7 61 4' 6 2 9 9' Liner 175 Sx AS I Perforation depth: measured 7258'-7274' · 7278'-7318' true vertical 6007'-6020', 6024'-6056' Tubing (size, grade, and measured depth) 2-7/8", 6.5 Ib/ft, J-55 EUE Tbg; Tail @ 7185' MD Packers-and SSSV (type and measured depth) Brown HB Packer ~ 7117', Baker FVL SSSV ~ 1800' 13. Attachments Refracture A Sand. Description summary of proposal X Detailed operation program _ BOP sketch 14. Estimated date for commencing operation August. 19cj0 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ;~ Gas __ Suspended Service 17. I Signed ~.~t the foregoing is true and correct to the best of my knowledge. · -,.- -- ~,- Title Senior Operatoions En0ineer FOR ~ISSION USE ONLY Date Conditions of approval: Notify Commission so representative mey witness Plug integrity_ BOP Test m Location clearance__ Mechanical Integrity Test Subsequent. form require Original S~¢n~t ~Y David W, doi0i~i~ 10- "?'1 Approved by the order of the Commission Commissioner Form 10-403 Rev 5/03/89 Approved Copy Returned )Approval Date ~ I z~mo SUBMIT IN TRIPLICATE 3A-13 Refrac Sundry Attachment 7/19/90 Kuparuk Well 3A-13 is scheduled for a re-fracture treatment of the A Sand Interval. A Pump Schedule for the job is attached. No workover fluids will be required for this stimulation treatment. Expected Reservoir Pressure for the 3A-13 area is 2600 psi. WELL 3A-13 GW FRAC DATA TABLE STAGE BREAKDOWN I PUMP RATE (BPM) CLEAN VOLUME (BBL) PROPPA I CUMULAT,VEI (POUNDS) IPROPPANT (LBS)I DIRTY VOLUME (BBL) Icu"u *T'w I ST^ .,TS I 25 75 0 0 75 75 44 20 60 0 0 60 135 119 15 45 0 0 45 180 179 SD FOR ISIP, PROVE FLOWMETER. PAD 20 700 0 0 700 880 224 SLURRY 2PPG 20 64 5404 4PPG 20 68 11425 6PPG 20 71 17936 8PPG 20 74 24840 10PPG 20 42 17490 12 PPG 20 20 9889 5404 70 950 924 16829 80 1030 994 34765 90 1120 1074 59605 100 1220 1164 77095 60 1280 1264 86984 30 1310 1324 FLUSH 2 0 42 0 TOTAL 1261 86984 86984 42 1352 1352 VOLUME TO PERFS (BBL) = 44.3 PROPPANT: 16/20M CARBOLITE or LWP THROUGH 10 PPG STAGE 12/18M CARBOLITE IN 12 PPG STAGE PUMP RATE = 20 BPM (Drop to 16 BPM if necessary) Estimated Surface Treating Pressure = 3750 psi (includes perf friction) BREAKDOWN = GW + 40 LB/1000 GAL Silica Flour + 8 Hour Breaker Cut XL during last part (flush) of BD stage. Perform step rate test as shown only if Petrodat gauge is installed; pump @ 20 BPM throughout if it is not. PAD = GW + 40 PPT Silica Flour + 8 Hour Breaker SLURRY = GW + 8 Hour Breaker (no Silica Flour) FLUSH = Slick Diesel JRS 7/19/90 · 3 2 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF i!' I ! I I I HIREL]NE BOP EQUIPMENT ARCO Alaska, Inc. Post Office Box '1u0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: November 17, 1987 Transmittal # 7012 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2U-16 Kuparuk Well Pressure Report (Otis) 9-11-86 2U-5 Kuparuk Well Pressure Report (Otis) 7-15-86 3A-13 Kuparuk Well Pressure Report (Camco) 11-1-87 Static Static Receipt Acknowledged: DISTRIBUTION: D&M SAPC Unocal ARCO Alaska. Inc. is a Subsid,ary of AllanticRichfieldCompany ARCO Alaska, In Post Off; oox 100360 Anchora~> . Alaska 99510-0360 Telephone 907 276 1215 Date: November 5, 1987 Transmittal # 7006 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ lB-2 ~ 1C-4 '"~ iH-4 "J 1H-4 "'-~ 1H-3 ~ 2F-5 "--.5 2C_9 ~ 2F-6 -x.o3C-13 ~"J3A-13 ~ 1L-2 "--o 1L-5 --" 1L-7 ~ 1L-1 "---o 1L-16 -'--o 1E-4 "'~ 1F-16 -"'-~ 1F-lO ~ 1F-9 ~ 1F-4 '"--J lQ-9 Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Camco) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) Sperry-Sun Pressure Build Up Test 'A' Sand Static BHP Survey PBU Well Test Interpretation Plots 'A' Sand Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report)Otis) KOE Buildup Analysis KOE Falloff Analysis KOE Falloff Analyeis KOE Falloff Analysis KOE Falloff Analysis KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysie KOE Falloff Analysis KOE Buildup Analysis KOE Falloff Analysis Kuparuk Well Pressure Report 7-8-87 Static 7-7-87 'C' Sand 8-5-87 Static 8-3/5-87 PBU 8-22-87 7-19-87 AK-MS-70043 7-14/17-87 I00591H 7-15/19-87 6-10-87 7-28-87 6-10-87 'C' Sand 6-13-87 'C' Sand 6-14-87 Both Sands 6-17-87 Both Sands 6-18-87 Both Sands 6-14-87 Both Sands 6-11-87 'C' Sand 6-10-87 Both Sands 6-17-87 Both Sands 6-12-87 'C' Sand 6-9-87 Both Sands 11-3-87 Static Static Static 'A' Sand Receipt Acknowledged: DISTRIBUTION: Ala~ 0il & Gas cons. C0mmissi0r) Anchorage D&M State of Alaska BPAE Chevron Mobil SAPC Unocal ARCO Alaska, Inc. il a Subsidiary of AtlanticRichfieldCompany ARCO Alaska. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE 0 9 - 15- 8 6 T.~3%N SM I TTAL ~. 5761 Please acknowledge receipt and Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run ~3 7585-8532 lA-14 .12-05-05 Run #1 4550-4850 1H-4 12-26-85 Run ~2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run ~4 7850-8450 lQ-9 01-28-85 Run ~1 4898-6534 lQ-13 06-02-85 Run ~1 5300-7621 2C-16 02-19-85 Run ~1 7200-8294 2E-9 01-14-85 Run ~1 6780-8052 2E-15 01-12-85 Run ~1 3350-6874 2E-16 01-12-85 Run ~1 4840-7578 2H-10 12-05-85 Run ~1 6500-7863 3A-7 11-04-85 Run #1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run #1 6426-7768 3A-13 12-29-85 Run ~2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run #1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run ~1 6188-7490 3J-5 12-22-85 Run ¢1 7000-8636 /..~~ A]P~k~ Oil & G.s Cons. Receipt Acknowledged: //~ Date ~Ch~ ane ~~f AK*bl/~ ~~ NSK Files*bl Vault*films ARCO Alaska. Inc. Post Office Bu,, 100360 Anchorage. Alaska 99510-0360 Teiephone 907 276 1215 February 24, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 3A-13 Dear Mr. Chatterton. Enclosed are the Well Completion Report and gyroscopic survey for 3A-13. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG/tw GRU13/L153 Enclosures E B 2 B STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Classification of Service L'Jeli ~ 1. Status of Well OIL_~(X GAS Z SUSPENDED Z ABANDONED Z SERVICE ~_ I 2. Name of Operator 7. Permit Numt)el ARCO Alaska, Inc. 85-281 3. Address 8 APl NumOm P. 0. Box 100360, Anchorage, AK 99510-0360 50 029-21489 9. UOlt or Lease Ndme Kuparuk River Unit 4. Location of well at surface 817' FSL, 825' FEL, Sec.7, T12N, RgE, UN At Top Producing Interval 1217' FNL, 927' FEL, Sec.7, T12N, RgE, ~I At Total Depth 999' FNL, 958' FEL, Sec.7, T12N, RgE, UM 5. E!evation in feet findicate KB, DF, etc.) 72 ' RKB ' 6. Lease Designation and Serial No. ! ADL 25631 ALK 2565 12. Date Spudded 11/25/85 17. Total Depth (MD-TVD) 7630 'ND ,6312'TVD 13. Date T.D. Reached i 14. Date Comp., Susp. or Abano. 12/01/85 ' 12/02/85' 10. Well %umt)e, 3A-13 I 1 F~ei(~ an~! Poo! Kuparuk River Fi eld Kuparuk River Oil Pool 18. Plug Back Depth(MD-TVD! 19. Directional Survey 7523 'MD,6224 'TVD ! YES ~"~ NO ~ T 15. Water Depth, ~i o~!sho,e lG ',~) r~ C~?~]p,e,*~,mns N/A ~eet :JSL 1 20. Depth ~.Nhere SSSV set I 21 Thlc-.ness ~ Pe'm:ii'os: 1800 Ceet \ID [ 1550' fapprox) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL,FDC/CNL,Cal, CET, OCT 23. CASING SIZE WT. PER FT. 16" !62.5# 9-5/8" ! 36.0# 7" 26.0# GRADE CASING, LINER AND CEMENTING RECORD t SETTING DEPTH MD TOP BOTTOM H-60 ~ Surf 107' J-55 i Surf i 3321' ! J-55 I Surf i 7614 ' , i 24. Perforations open to Production (MD-TVD of Top and Bottom and interval, sizeand number) 7278~ - 7318' w/~ spf, 90° phasing 7258' - 7276' 27. N/A ! HOLE SIZE I CEMENTING RECORD 24" ! 195 sx AS I I A%iOU'qT PULLED 12-1/4" 1200 sx AS III & 300 sx Class G 8-1/2" 400 s× Class G & 175 sx AS I 25. TUBING RECORD DEPTH SET ~;,.1D¢ I PACKER SET ~'.IDI SIZE 2-7/8" 7185 l I 7117 ' 26. ACID, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL ~MD)I~MoUNT & KIND OF ,MATERIAL USED f i See attached AddTdum, dated 3/5/86. PRODUCTION TEST Date First Production Date of Test Hours Tested Casing Pressure Flow Tubing Press. I Method of Operation (Flowing, gas lift, etc.) IPRODUCTION FOR iTEST PERIOD I~ [CALCULATED 24-HOU[R [RATE OIL-BBL r T GAS-MCF WATER-BBL i CHOKE SIZE ' GAS OIL RATIO [WATER-BBL OIL GRAVITY ,&PI Icorr) OIL-BBL I GAS-MCF 28. CORE DATA Brief description of lithology, porosity fractures, apparent dips and presence of oil, gas or,.%ater. Submit core ch~ps. None RECEIVED APR 0 ~ ]986 Ala~t<a 0il & GaS Cons. ~mmi~10n Anchorage Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run & well perforated 1/10/86. GRU1/WC11 CONTINUED ON REVERSE SIDE Itl ri Upi iC~,'~ 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A ', GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 5996 ' 6108 ' 30. FORMATION T E_STS Not present Not present 7245' 7382' Include interval tested, pressure data, all flu,ds recovered and gravity, GOR, and time of each phase N/A 3i. LIST OF ATTACH~ENTS Addendum (dated 3/5/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer INSTRUCTIONS General' This form is designed for submitting a complete and correct well com!)let on 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 n 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 nterval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attac}~ed ~ut~p~mental 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~,07 ADDENDUM WELL: 12/11/85 12/30/85 3A-13 Arctic Pak w/175 sx AS I, followed by 55 bbls lightwt Arctic Pak. Rn CET f/7485' WLM - 5870' TOC. Rn GCT gyro. FRACTURE STIb~LATION SUMMARY Begin Frac Work At: 1958 hrs, 2/7/86. AFE: AK0359 Frac'd Kuparuk "A" sand perf 7258'-7274' & 7278'-7318' in 7 stages per 1/31/86 procedure using gelled diesel w/Musol, 100~ mesh & 20/40 sand. Press'd ann to 1650 psi w/diesel. Tst ins to 7000 psi; OK. Stage 1: Pmp'd 40 bbls 5% U-66 Musol @ 5.5 BPM w/final press of 3360 psi. Stage 2: 50 bbls gelled diesel pre-pad @ 18.5 BPM w/final pressure of 5500 psi. Stage 3: 19 bbls gelled diesel w/lO0 mesh @ 20.3 BPM w/final pressure of 4560 psi. Stage 4: 64 bbls gelled diesel pad @ 20.1BPM w/final pressure of 4470 psi. Stage 5: 23 bbls gelled diesel w/20/40 mesh @ 19.7 BPM w/final pressure of 4500 psi. Stage 6: 42 bbls gelled diesel w/20/40 mesh @ 19 BPM w/final pressure of 6200 psi. Stage 7: 43 bbls gelled diesel flush @ 18.4 BPM w/final pressure of 4760 psi. Pmp'd 800# 100 mesh + 2500# 20/40 & 10,008# 20/40 sand. Job underflushed by 2 bbls in 7". Load to recover 273 bbls of diesel. Job complete @ 2022 hrs, 2/7/86. RECEIVED APRO 3 1986 Alaska Oi~ & Gas Cons. gemmission knchomOe Drilling! Superintendent Date UB.$URFAC DIRECTIONAL URVEY [~] UIDANCE r~ONTINUOUS [-~ OOL Company ARCO ALASKA INCORPORATED Well Name 3A-13 (817' FSL, 825' FEL S7, T12N~, R9E~ Field/Location KLWA~, NORTH SLOPE ALASKA RECEIVED F E B 2 8 ]986 Oil & bus ~,~s, u~nmissioa Anchorage i Job Reference No. 71181 SALAZAR Date 26-JA~Y- 1986 Computed By: HALSI'EAD ]CT SI~ECTI]'~AL SU~V '¥ ",JST,]ME~ LI ~Tl~i.~ ~4ETH]]S 3= C]q~JTITI'3'I T]3_ L]~.~TI]N: T2N]ENTI&L- I'~T'--R. P]_ ~T T ]N: LZNE~1R Vr-~TiC~L S:CTI]N: fl~qIZ, liST. CO~4PUT~TI]q D~T'-: 26-,J~q-4S -'~ .; i &R'O ~L~Sq~, I~C. 3~-13 NDRTH SLOPF,~L~Sq~ [NT~:R°OL~NTE3 V~LJSS FOR :'VEN 10,3 ENSURE} V:RTICAL V-RTIC~L ]EPTH OEPTi 3E~FH 0.09 0.30 -72.00 100.03 100.00 2~.00 200.00 200.30 1Z~.O0 300.00 300.30 22~.00 ~00.00 ~00.00 325.00 530.33 500.00 ~2~.00 500.03 ~00.09 523.00 ?00.00 700.00 52~.03 ~00.03 800.00 72~.00 ~O0.OO '~.9~ ~27.9~ 1900.00 999.99 927.99 llO0.OD 1099. }~ 1027.99 1200.00 1199.9~ 1127.99 1300.00 1299.9~ 1227.99 l~DO.O9 1399.~ 1527.98 1500.00 1~99.98 1500eOD 1599.)~ 1527.9~ l?O0.DD 16~9.9~ 1627.98 1~00.00 17~9.~8 1727.~ l~O0.~ 1899.~5 1827.95 2000.23 1~9.71 1927.71 2100.30 2098.90 2025.90 2ZO0.O0 Z1~7.24 2125.2~ 2330.00 Z2~.55 2222.55 2400.03 2391.~1 Z31~.31 2500.03 2~87.11 2415.11 2500.00 2582.22 2513.22 2700.00 2675.82 Z$0~.82 2~00.00 Z766.99 259~.9~ 2~00.00 Z8~5.03 2783.03 3100.00 29~5.77 3200.00 ~093.85 3021.86 3300.00 315}.$9 3091.$~ 3~30.00 3229.5~ 3157.5~ 3500.09 ]2~.~0 3222.~0 3500.00 3358.~2 32~6.~2 3?00.00 3~22.99 3350.~9 3~90.~3 3485.79 341~.7~ 3~0.33 3550.1~ 3~7~.14 COJPS~ V::RTICAL P33_~$ 0 0 N O 0 5 N ?,. ¢ 0 ? S 3a 0 11 S ~1 0 11 S B? 0 11 $ 8~ 0 12 S 61 0 11 S 51 ,~ ~3 S 1i '3 : '3.00 3.00 41 ~ 0.04 ].47 q2 :_ -'). 1<, 3.11 19 : -0.22 3.1) ~ ':_ -9. 17 '3. 12 15 -3.1~ 4~ -. -O.B-' D.il 36 : -0.37 J.5~ 57 ~ -1.~3 3.13 2~ W -~.41 1.1] al W -2.91 3.05 29 '4 -3. 2') S. 3~ 12 4 -3.53 45 ~ -3. ~ ].23 15 ,~ -~.29 3.22 2~ ~ -~.~2 3.3.~ 22 ~ -3.~35 3. 32 5~ 'J -1 .74 3.35 0 Z5 S 7 0 22 S 13 0 13 S 0 17 S ,3 O 15 S 52 0 15 S 42 0 5? '~ 35 2 14 'q 15 5 50 N 0 11 52 N 0 15 ~a N ~ 17 32 q I 26 7 N ~ 30 32 '~ 2 NTRTq/S]'JTq ~.tST/n "ST i~Z3T. J. 30 '3. ,35 '- }.! ~ :. ".~1 1. ~_'~ 1.~9 - 5 · l -" 3.75 - ,.~ 2. ~I 17.53 ',.J 5 ~ I. 57 ~ 5~~, 73 - ~7 ~. I c:, 319.5t I 8.47 ~7). ~2 "l 9.27 517.~2 'J 7°09 ~5~.77 '~ 2.7+ 745.3) '1 0.55 ~7o. 1'+ 'i 5. J5 '1' SO'~DUT~TI]",I OfiT:: _25-J~N-~5 ~'.~'" ] 31-13 NJRTH SLgP~,aLiS<~ - F ~E~SURED 3EPTH 4000.00 4130.30 4Z00.00 4300.00 4400.O0 4500.00 4530.33 4700.00 4200.00 4900.00 500O 5100 5200 5~00 5500 5500 5730 5~00 5~00 .03 .09 .03 .00 .09 .03 .00 6300.33 6100.00 6gO0.O0 6300.00 6430.33 6500.00 6500.03 6100.03 $330.00 6~30.00 7O 71 7Z 75 76 75 00.03 O0.O0 00.00 DO.OD 00.00 00.03 00.03 30.00 V!RTIC~L DEPT~ 3616.~3 3686.33 3755.29 3824.75 3894.39 3964.13 ~034.Z2 4175.1~ 4316.35 ~457.~3 ~599.33 ~539.~7 ~672.~0 4745,07 ~B18.~5 48~2.5~ ~'~57.3~ 5042.37 5117.36 5192.13 $266. B6 5341.14 5416.96 5492.50 55fi8.57 5645.04 57ZZ.Z3 5879,24 5959.57 $041.00 $1ZZ.B3 5205.13 5287.~6 5312.15 I~T':~.)L'~TZ3 VaL'J-S :OR -V;:q 100 F:- T L',: SJ~-S=fi V:RTIC~L 3544.93 351~.08 3583.Z9 3752.75 3822.39 3~2.13 3~62.22 ~032.66 4103.13 4173.72 ~2~.35 4315.0~ ~.3q~ 5.93 4457.0] ~52~ .~.7 ~.509.45 4673,~7 ~7~6.25 497~.37 5045.3b 51Z3.13 519~.,36 53i:, .')5 5 ~.2.). 6'3 54.95.5? 5573.04 5650.23 572~.31 5807.24 588~.57 5~69.0J 5050.,~3 5133.13 6215.4~ 524J.1~ V:RTI-aL 903L. F ' 5:"Ti]"J,.. S:V:RiTY F:-'T ') ~ .3 / 10 .'0 1043.01 0.83 1114.6.6 9.31 1186.76 3.23 1237.52 122~.79 ].1~ 1.3 } ~. 91 1470.7~ 15~1.Zl ~.IZ 1532.25 9.1~ 175Z.61 1{22.:~7 9.13 1 ~52. 95 2032. 5~. ]. 81 !131.72 1173.2~ 3. g37!.~ 'D. 1 ~, 1~37.49 3.15 . ., ~7:5~.~TM 1.1l Z~ 33.3~ !.'2" ]'9o%.3~ 1.15 3026.~ 1.51 3153.75 3213.2~ 1.23 3325.?~ 2.12 j3~2.36 ].DC 3~39.30 2~36.37 :~51.55 'q 13. i'~ ~ 2~31. =517.:1 Iq 1~. ~3 ~ 2317. gS~ ~. ~ '~ 2~. 1~ r~ 25.~. ' 71 5.22 ',~ 33. 7.] ., _" ~i.. - 'TeZ,,~2 ',~ ~.~ ,,; _ 7 ', ".~ f9l1. . 4', I 55.22 w 2TM.._.' :~'13.~J '~ 64.24 '4 2.~7~. 5'J3~. ~7_ I 72.95 '~ '~. . ~,. .~13'].i ~ 'q 82.00 ?!53..~3 "J 90.9::) W 2277.~7 ~ 106.61 '.~ 53)).52 q 122.57 .)'"~AqTiJ?: ,'~ · i '4 J T '-~ '.] '- ' %1 'r \q C2~PgT~TI]~ O~T=: ZS-JSN-q$ ~i;- ~ ARCg ~LaSKa, I~C. 3~-13 KJP~RJK N]RTH TRUE 4E&SURE3 VERTIS~L ]EPTH DEPT~ 0.00 O.O0 lO00.O0 999.~4 2000.03 19)9.F1 3000.00 293w.37 ~000.00 3515.~3 5~00.~ &316.J5 6000.30 50~2.37 7000.00 5800.31 7530.~3 5312.15 [NT:~a3LATEO VAL.JE.~ :OR ]EVI~TI]q AZI~Orfl 3EG MIN D'G MI~ -?Z.O0 927.9J l~2T.?l 2867.07 35~.93 ~2~.35 ~970.37 572~.31 ~2~.13 0 O N 0 3 0 25 S 7 57 5 Z? N 1 35 1 N 1 2~. ~5 24 N 0 43 0 N 3 13 41 23 N ~ I 7 3:5 15 N 3 25 3~ 35 N ~ 12 -YEN lOS) V:RTI-AL SECTI]N , . . O.O0 -1.53 l?3Z.~l Z~37.~,~ 3~55.33 =::T ]: DOS LE ,) SEV ' :2. IT Y 3.i0 ;. 70 i).83 '3 · 52 3.30 1 }5'J. itt,:.,. 310'" . .,~ 3 '.; ~,'~.,. 3~-13 K J~'fiR ,J< N]RTH SLJPE,aL&SK~ i'iT;:~PDL~T.=,D V~LUES "DR EVE'~ 100 TRU= SJ~-S -a 4E&SURE2 VZRTIC~L V;RTI',&L DEPTH DEPT4 JEDTH 0.00 OoOO -72.00 72.32 72.00 0.00 172.00 172.00 100.00 272.00 272.00 20).00 372.03 372.30 300.30 472.00 472.90 403.00 5?2.03 572.00 $?g. O0 6TZ.O0 603.00 772.0J 77Z.00 702.00 a72.03 B72.39 803.00 972.31 972.J0 1372.31 1072.30 1003.33 1172.31 1172.00 1100.00 1272.31 1272.00 1203.00 1372.02 1372.00 1300.00 1~72.02 1472.99 1402.00 1572.02 1572.00 1503.00 1572.02 1672.00 1603.00 1772.22 1772.20 1703.00 1~72.04 1872.00 1BOS.'JO 1~72.1~ 1972.30 19J].03 Z)TZ.BO 1072.~0 2174.23 2172.30 Z1J).OO 2276.55 Z272.90 2203.03 2379.~D 2372.00 24B4.15 2472.30 2~90.03 25B~.22 2572.00 2533.33 2B3S.Sg Z772.00 2793.00 291g.~1 2872°00 3170.18 3072.00 3000.00 3312.~3 317~.00 ~103.00 3~55.~1 32T2o00 3520.33 3372.00 530~.00 3716.72 3~72.00 340~.00 3~33.7~ 3572.00 35~0.00 4079.55 3572.20 35~.00 ~24.08 3772.00 3700.00 ~367.~$ 3872.20 COJqS~ V=RTI"aL ]EV'ZITI3~J ~ZI~JTH S~CTISN S~V qlT¥ DES ~IN · O '~ S 3~ 23 ,: -0.33 0 7 ~ ~ 57 : -0.23 0 10 N ~5 35 = -9.15 0 11 ~ ~5 5~ ~ -'3.17 O 12 N ~Z 21 = -9.1~ 3 11 S 70 55 c -3.29 0 11 ~J 77 5~ -. -9.35 0 gl S 17 ~5 ~ -13.71 4 11 13 17 31 36 3.03 3.25 3.13 J.l} 3.71 0.16 2.07 ].17 3.21 }.11 2.32 3.75 -- · 1 · 7 '3 ?,.1~ *.15 2.77 9.17 j e ~~'. ].1~ ~.Z1 ,-T a~30 ~LAS<A, !NC. 3~-13 KUP~RU~ ND~TH SLOPS,4L4SK4 TRU~ ~E~SURE] V~RTIS&L ]{PTq DEPTq 4511.26 3972.00 4553.57 $072.00 4795.48 $172.00 ~937.25 ~272.00 5078.70 ~372.00 5219.87 5472.00 5350.18 ¢5?2.00 5~99.36 ~$7Z.30 5536.97 5?72.00 577Z.~5 4872.03 5906.15 G972.00 6D39.53 5072.00 6173.09 517Z.O0 6306.85 5272.00 6~0.25 5372.00 65?2.75 5~72.00 6734.51 5572.D0 6835.10 5672.00 6~53.88 57?2.30 7090.89 5~72.90 7215.33 597Z.00 7337.32 5072.00 7~59.75 5172.00 7581.22 5272.00 7530.03 5312.15 INT=RPDL~TED VALJ6S FDR EV'E~ 103 FE=r 0= SJ3-SE& VtRTI~L COJqS~ V=qTICAL D]3' EG ]=VIITIJN AZiM:JT~ SECTIQN S6V~RITY J£G ~IN 0~3 ~Iq F~'~T DES/100 3903.00 ~O09.0O ~103.00 3203.00 ~3OO.O0 4400.00 ~5Ol.O0 ~500.00 ~7D3.00 5~00.00 45 36 N 0 19 E 1407.90 0.63 45 11 N 3 2D 'N 1538.65 '].Z2 45 7 N 0 15 ~1 160B.60 3.15 45 4 ~ 0 lO ~ 179~.4'~ 44 55 N 0 1~ 4 1~97.92 5.2~ 4~ 51 N 3 2I ~ 1905.9'~ ,].4~ 44 Z4 N 3 55 '~ Z,)O~.:)7 0.51 4~ 53 N 1 jl ~ 2131.2~ 0.75 43 5 N 2 ¢1 ~ g195.55 1.12 41 $6 N 3 3~ W 2236.7~ D.75 ~90J.O0 5000.00 5100.00 5200.00 5~00.00 55JD.O0 5600.90 5703.00 5~00.00 41 29 N ~ ) ,,4 23?5.47 D.25 41 2~, N '4 23 '4 245~.5'~ 41 ~7 N ~ ~2 ,~ 2532.11 .}.5~ ~1 ~5 N 4 55 '4 1'5~]. 41 15 N 5 27 W Z72}.17 40 ~') N 5 ~ W Z~16.10 ~O 14 N 5 55 ~ 2~01. )0 1.2~ 39 35 ~ ~ 4~ W 3983. 39 35 ;4 ~ 19 g 3:D~5.'96 1.2~ 37 g7 N a 15 ~ 31~5.23 1.'3t 5¢00.00 500D.O0 5100.00 5203.00 5243.13 35 39 H 7 1~_ 4 ~'I'~.26 3. 7~ 33 5 N 7 55 .4 32)0.13 3a 35 xl S 12 '4 373 ~.72 34 35 ~J .t I~ '~ ~3~.!~ SUJ:-S-a~ '=DTH =~.::T ; ' T ~RCO ~L4S~4, INC. KJ~ARg~ Ng~TH SL2PF_, AL3,$K~, TOP TOP P~T3 ro qUP~RUq ' KJ~JK C qUP&RUK & KU~4~UK ~ INTSq~OLITE) V~LJES FOR N]T PRESENT N]T PRESENT 7382.]0 7523.00 7530.D0 ' H3 S :"i ~]RI'L3NS 3~I)~= ~I~' 5996.15 5224.07 5312.15 5Z~0.15 a,~'O a,L~S<,6, INC. 3~-13 KJD~IRJK NINTH TOP -]6SE T3P B6SE PST3 73 KJPARU< A vl=~SJmEJ C, EDTH ~:LDW K~ NDT '137 PRESENT 7245.30 719Z.30 ?523. O0 7530.'00 5995.15 510~.,D'~ 5224.07 5312.1D g~l I~= ~17' 3J~-~-~ FINAL ',IEA S',JR F: D WF_-LL L'3-ATI]N ~T T,D: TeJ~ SJ~-S:& V~qTIC~L V:RTI'~L HD~,I:]NT&L 3-D6,(TU;!- 31 S T ~ N' = a i I 'q'J T -~ :::T ] ,-- _q 7639.00 5312.15 ~24,J.1~., 3~'5._D~ '~ _~ 1? '~ SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A-13 FIELD KUPARUK COUNTRY USA RUN TWO DATE LOGGED REFERENCE 00007]]8] WELL 3A- 13 (817' FSL, 825' FEL, S7, T12N, R9E) HORIZONTAL PROJECTION REF 00~0'71191 ~AI.E = 1/lO(X] IN/FT 4000 lOOO SOUTH -~000 WEST -4000 -9000 -2000 - 1000 0 1000 2000 ~000 4C00 Ei~ST ~JTH WELL 3A- 13 (817' FSL, 825' FEL, S7, T12N, R9E) VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN vERTICAL OEPTHS HORIZ SCALE = 1/ iOOO !N/FT WELL 3A- 13 (817' FSL, 825' FEL, S7, T12N, R9E) VERTICAL PROJECTION 17~!. -2000 - 1 ~ 0 0 1 ~ 2000 3000 4000 ' ' I' ' ' I ~ ;-1 :: i:.~:i::~ · I ...... ~: ~] ' : ' ~ I -'~': I l_ '~ ~'[' ~'. ' E : : ' '' :~[~~ 1-'~: ,~ :'ti .... [ ' l: ' [ - I - ' '- ' ' ' : ' ~ I '~ ' I ' ' '~ ' : ' ' ~:' ~'''i~ ~'I' : ' '/.'. .,,~ ..... ~ i, ~1 '' ~='"?-~'=~-~'-':-'. .: . . ~"'"':~ ........... : ....... ~ ...... ¢~': ....: ......... ~ ":: -t" :-: ' ~ ......[ : :: : : L ..........--ZL~t:-'-' ~ .... ~ ...... Lb L.L~..2 ' ; ....... , .... ..._ [ ....... _.~ _ :~ .................... ..... ..... ~ .................. I ....................... . . . i , '. i' ............ ~ .... ~ ........................ ; .............. . - . : .... ~ ...............................~ ............. ............................ ~ ......... t ......... ~ ........... < .,............. ~ ................. I - _ : _ I : ...................... "~ '--'~'""-~---~..;+:.--..~~'-',--..---.- - ~ _.: ..... :: _.:.Z~ "- -' t, ;_.-.' ....... , ...... ! :...: ............. ~ ......... ':: :':::: 'z':":' -: ..... : : '":"7= . T"=' :'::':~: :::::Z::: :~:-~ .: :::71::1' ,, I : ' - , .......... PROJECTION ON VERTICAL PLANE 3S3, - 1'73, SCALED 1N VERTICAL OEPT~ HORIZ SCALE = 1/ 1000 IN/F* EXACT RAOIUS OF CURVATURE METHO0 TIE-IN LOCATION MEASURED DEPTH O. 0 FT TRUE VERTICAL DEPTH 0.0 FT DISTANCE NORTH 0.0 FT DISTANCE EAST 0.0 FT BOTTOM HOLE COURSE LENGTH COURSE AZIMUTH LOCAT I ON MEASURED DEPTH TRUE VERTICAL OEPTH DISTANCE NORTH DISTANCE WEST ~472.1 FT 3S7.9 OEO 7630.0 FT 8307.S FT 3469.8 FT 126.7 FT REF 000071181 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. -OPERATOR, ~WEI~L~NAM~ AND ~UI~BEI~, Reports and Materials to be received by: / Date Required Date Received Remarks Comp let ion Report Well History y~_~ / _ 0 (__TL ._.:L.~ ~~__.~.~ Samples Mud Log Core Chips , ,, core Deacription Registered Survey Plat / - Inclination Survey Drill Stem Test Report~ Production Test Reports Log Run . - . _ ~ STATE OF ALASKA ALASKA O~- AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well CJass~flcatlon of Service V, ei~ OIL_ --XX GAS _-- SUSPENDED ~ ABANDONED .~ SERVICE 2. Name of Operator i 7. Permit Numbe, ARCO Alaska, Inc. I 85-281 3. Address P. 0. Box 100360, Anchorage, AK 99510-0360 i 8 AP1 Number ; 50 029-21489 4. Location of well at surface 817' FSL, 825' FEL, Sec.7, T12N, RgE, UN At Top Producing Interval 1217' FNL, 927' FEL, Sec.7, T12N, R9E, UN At Total Depth 999' FNL, 958' FEL, Seco7, T12N, R9E, UN 5. Elevation in feet ~indicate KB, DF, etc.! !~ 6. Lease Designation aha Serial No. 72' RKB i ADL 25631 ALK 2565 12. Date Spudded 11/25/85 i 9. Unit or Lease Name ~1 Kuparuk River Unit 10. Well Numbe, 3A-13 11. F.ei(] and Pool Kuparuk River Fi eld Kuparuk River 0il Pool 17. Total Depth (MD-TVD) 7630 'MD ,631 2'TVD 13. Date T.D. Reached i 14. Date Comp., Susp. or Aband. 15. Water Depth, it of!sh~]'e 16 N:~ 12/01/85 " 12/02/85' N/A +eet ',.IS L 1 18.Plug Back Depth (MD--I-VD). 19. Directional Survey 20. Depth ?,here SSSV set 21 Th~c- ness ,~f 7523 'MD ,6224 'TVD ! YES -)(X NO ~ [ 1800 ~eet ',.~D . 1550' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL,FDC/CNL,Ca], CET, GCT 23. CASING SIZE WT. PER FT. GRADE TOP 16" 62.5# H-40 Surf 9-5/8" 36.0# J-55 i Surf ' 1 7" ! 26.0# J-55 Surf I 7614' 8-1/2" 400 sx Class G & 175 sx AS I 24. Perforations open to Production iMD-TV CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD I ] BOTTOM HOLE SIZE CE:V1ENTING RECORD IA,MOUNT PULLED I 107' 24" i 195 sx AS I I i 3321' 12-1/4'~ 1200 sx AS III & 300 Sx Class G D of Top and interval, size and numDer) 7278' - 7318' W/4 spf~ 90° phasing 7258' - 7274' Bottom and 25. SIZE 2-7/8" TUBING RECORD 1 DEPTH SET i,~,lD~ I PACKER SET 7185' I 7117' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL ~ZID) I AMOUNT & KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.~ I PRODUCTION FOR OIL-BBL GAS-MCF Date of Test Hours Tested iTEST PERIOD Flow Tubing Casing Pressure "CALCULATED.I~,OIL'BBL GAS-MCF Press. 24-HOUR RATE IIFI 28. CORE DATA IWATER-BBL CHOKE SIZE I GAS OIL RATIO WATER-BBL OIL GRAVITY APl Icorr; FEB 2 8 1986 Gas Cons. Form 10-407 Rev. 7-1-80 NOTE: Tubing was run & well perforated 1/10/86. DAM/WC39 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk £ Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH ,I Not present i' -- Not present -- 7245' :! 5996' 7382 ' , 6108 ' 30. FORMATION TESTS Include interval tested, pressure data, a,l f,u,ds r¢,c()'.,.,ed anc~ gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS We]] History (completion detai]s), Cyroscopic Survey (2 copies) 32. ! hereby certify that r, he foregoing is true and correct to the best o~ my knowlegae Associate Enoi neer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report ar~(t log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, ai: ,niection, 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 n~easurements 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' In.dicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: D-eca.e a~c s..:m,t :-e "Final Report" 2. :~'e '.'st '~,ec-esday a'te' a c~.aD e "as Dee- ass g~ec ~. ~e s ~ ~:~ec a~a~c"e~ 2- 5o,~ reda -es .sen gobs.e: c~ -eso. colD,etlon arc -eo.esen:aPve :est ca:a n : ocKs :'o~:cec T-e "Final Repo~" '?~ ma~ :e .se: 'o' 'erc'~-g t~e e~'.e ocera~cr ' sza~e ~s a.a au e Accou~t,ng cost center code Alaska I North Slope Borough Alaska Fie c LeSse 3- ~ t I ,',e ~c Kuparuk River I ADL 25631 [ 3A-13 Au:h. or ~,'~ C. no I? t e AFE AK0359 Completion Nordic 1 Cceratc, ARCO Alaska, Inc. Spudded Or W C oegun ARCo W Date Complete Date an: as of ~ O0 am 1/10/86 1/11/86 Comp,ere recor'~ 'or each cay reDoEe~ API 50-029-21489 56.24% 1/10/86 ,l'Total number of wells ,act,ye o, ,nact,ve) on cost center prior to p~ugg,ngand abandonment of !h~s I 0315 hrs. 7" @ 7614' 7523' PBTD, GIH w/gun 10.0 ppg Accept ri~ @ 0315 hrs, 1/10/86. csg to 3000 psi. GIH w/gun #1. NU & tst BOPE. RU SOS, tst 7" @ 7614' 7523' PBTD, RR Diesel in tbg & ann Perf w/4" gun, 4 SPF, 90° phasing f/7278'-7318' & 7258'-7274' Rn 235 jts, 2-7/8", 6.5#, J-55 RUE 8RD tbg w/SSSV @ 1800', PBR @ 7105', "D" Nipple @ 7153', HB pkr @ 7117' & TT @ 7185' Set pkr, tst pkr & SSSV, shear PBR. NU & tst tree. Displ well to diesel. Secure well w/BPV. RR @ 2345 hrs, 1/10/86. RECEIVED FEB 2 8 1986 Alaska Oil & Gas Cons. comrmssion Anctmmge ~C O~d TS Ne~, TS me ease: - g Da:e 2345 hrs, C:ass,':cat;c.s c gas etd Oil 1/10/86 Ty~e co-2:et,o~ s eg e Single mroCuc.qg method C"',:'al -ese~.o - -a~e s Flowing Kuparuk Sands ~cter: a :est ~a~a 7523' PBTD Rotary The abo.~e ~s Correct Signature /,~ or form prec-arat,o 4d d,stq:eut,on. see P"oCeoures Manual. Section 13. Drt!'ir.g. Pages 86 and 87 Drilling Superintendent ARCO Alaska. Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 01-28-86 TRANSMITTAL ~ 5532 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints/ Schl/ Open Hole/ One * of each / 3A-13 5" DIL/SFL-GR 12-01-85 Run =1 2" DIL/SFL-GR 12-01-85 Run #1 5" Den/Neu (poro) 12-01-85 Run 2" Den/Neu (poro) 12-01-85 Run 5" Den/Neu (raw) 12-01-85 Run 2" Den/Neu (raw) 12-01-85 Run #1 Cyberlook 12-01-85 Run #1 1800-7597 1800-7597 5100-7571 5100-7571 5100-7571 5100-7571 7000-7546 3A-14 5" DIL/SFL 12-09-85 Run #i 2" DIL/SFL 12-09-85 Run ~1 5" Den/Neu (poro) 12-09-85 Run ~1 2" Den/Neu (poro) 12-09-85 Run #1 5" Den/Neu (raw) 12-09-85 Run #1 2" Den/Neu (raw) 12-09-85 Run. gl Cyberlook 12-09-85 Run ~1 0145-7795 0145-7795 7250-7770 7250-7770 7250-7770 7250-7770 7300-7650 3A-15 5" DIL/SFL-GR 12-17-85 Run ~1 2" DIL/SFL-GR 12-17-85 Run =1 5" Den/Neu (poro) 12-17-85 Run A1 2" Den/Neu (poro) 12-17-85 Run =! 5" Den/Neu (raw) 12-17-85 Run ~1 2" Den/Neu (raw) 12-17-85 Run ~! Cyberlook 12-17-85 Run A1 1800-7982 1800-7982 4640-7956 4640-7956 4640-7956 4640-7956 7450-7933 Receipt Acknowledged: State of AK*bl/se Rathmell*bl Date: NSK Clerk*bl D & M*bl Drilling*bi Vault*films ARCO Alaska. Inc. ,s · Sul~s~aiar¥ of Allant~cRtcl'tf~el~lComg·n¥ ARCO Alaska, Inc. Post Office Box ~00360 Anchorage A;aska 995!0-0360 '~eiephone 907 276 1215 January 21, 1986 o. Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 3A-13 Dear Mr. Chatterton' Enclosed is a Well Completion Report for 3A-13. The bottomhole location, geologic markers, TVDs, and tubing details will be submitted when the gyroscopic survey is run and the well completed. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L16 Enclosure STATE OF ALASKA ALASKA ( .AND GAS CONSERVATION CO /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED l-~x ABANDONED ~ SERVICE r-- 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-281 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50- 029-21489 4. Location of well at surface 817' FSL, 825' FEL, Sec.7, T12N, RgE, UH (approx) At Top Producing Interval To be submitted when gyro is run. At Total Depth To be submitted when gyro is run. 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 72' RKB J ADL 25631 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3A-1 3 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Date Spudded 11/25/85 13. Date T.D. Reached 1 2/01/85 18. Plug Back Depth (MD+TVD) 7523 'MD 17. Total Depth (MD+TVD) 7630 'HD 22. Type Electric or Other Logs Run D I L/CR/SP/SFL, FDC/CNL ,Ca 1 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 1 2/02/85 N/A feet MSL I. YES ~ NO ;~X N/A feet MD 1550' (approx) 23. CASING SIZE 16" 9-5/8" 7" CASING, LINER AND CEMENTING RECORD WT. PER FT. 62.5# 36.0~ 26.0# GRADE H-40 J -55 J -55 SETTING DEPTH MD TOP BOTTOM Surf 107' Surf 3321' Surf 7614' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None HOLE SIZE 24" 1 2-1/4" 8-1/2" CEMENTING RECORD AMOUNT PULLED 195 SX AS I I 1200 sx AS I!1 & 300 s Class G 400 sx Class C & 175 s AS I 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) N/A IAMOUNT& KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ .. Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE m~ I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cor,,e chips. None i: ECEIVED Form 10-407 TEHP3/WC41 Subm.t in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and grav ty, GOR, and time of each phase N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed '4~ ('~'Tt."JX.~ L(,A,./ Title Associate Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". TEMP3/WC41 a Form i0-407 ARCO Oil and Ga~ Company '~, v Well History - Initial Report- Daily Pr~p&r~ ~nd submit the "lnlt~l I~¢)rt" on the fir~ Wednesday after a well is spudded or workover operations ere started. Daily work prior to sPudding should be ~mmarized o~1 the form giving inclusive dates only. District Field Alaska IC4~mn~, ~n~q or bOrOUgh North Slope Borough ICeaae or Unit ADL 25631 Title Drill lStltl Alaska Kuparuk River Auth. or W.O. no. AFE AK0359 Parker 141 Operator rail no. 3A-13 AP1 50-029-21489 I ARCOW, 56.24% IHour Prior status ~f a W.O. 2330 hrs. Date and depth as of 8:00 a.m. ARCO Alaska, Inc. Spudded or W.O. begun ID~te Spudded I Complete record for each clay reported 11/26/85 11/27/85 11/28/85 thru 12/02/85 11/25/85 16" @ 107' 523', (416'), TOH f/new bit Wt. 9.3· PV 14, YP 12, PR 9.5· WL 14.8, Sol 5 Accept ri~ @ 1900 hrs, 11/25/85. NU diverter sys. Spud well @ 2330 hfs, 11/25/85. Drl 12¼" hole to 523'. 16" @ 107' 2667', (2144'), TIH Wt. 9.2, PV 12, YP 10, PH 9.0, WL 14.8, Sol 5 TIH, DD & surv 12¼" hole to 2667', TOH f/angle bldg assy. 1983', 4.7°, N 3.3W, 1982.86 TVD, 5.03 VS, 5.03N, .29W 2300', 14°, N12E, 2294.75 TVD, 58.94 VS, 59.43N, .92E 2612', 19.2°, N 7.4W, 2593.87 TVD, 146.06 VS, 147.34N, 2.74E 9-5/8" @ 3321' 7630', (4963'), Rn'g 7" csg Wt. 10.0, PV 13, YP 7, PH 8.0, WL 10.6, Sol 13 Drl & surv 12¼" hole to 3441' TD, short trip to HWDP, circ hi-vis sweep, POH. RU & rn 84 jts, 9-5/8", 36#, J-55 HF/ERW BTC csg w/FC @ 3239', FS @ 3321'. Cmt w/1200 sx AS III w/lO#/sx coalite, followed by 300 sx C1 "G" w/2% S-1 & .2% D-46. Displ using rig pmps, bump plug. CIP @ 0230 hrs, 11/28/85. ND diverter. NU &tst BOPE. RIH w/BHA, tag FC, tst csg to 1500 psi. DO flt equip + 10' new formation. Conduct formation tst to 12.5 ppg EMW. Turbine drl & surv 8½" hole to 7619', cond hole, 25 std short trip, TOH. RU Schl, rn DIL/GR/SP/SFL f/7605'-3321', cont w/GR to 1800'. Log FDC/CNL f/7605'-7000' & 5200'-5100' Log CAL f/7605'-6500' RD Schl. RIH to 7619', drl to 7630' TD, 10 std short trip, CBU, POH. rams to 7" &tst. RU to rn 7" csg. 2824', 27.3°, N4.3W, 2788.49 TVD, 229.66VS, 230.51N, 5.78W N1E, 3161.18 TVD, 515.50VS, 517.60N, ll.14W N2.5E, 3262.25 TVD, 629.15VS, 632.29N, 7.63W N1W, 3960.72 TVD, 1423.42VS, 1433.03N, 2.57E N1W, 4509.16 TVD, 1975.43VS, 1987.53N, 7.11W N4.5W, 4803.64 TVD, 2255.70VS, 2268.10N, 20.59E N5W, 5325.49 TVD, 2721.91VS, 2733.25N, 56.52W N6W, 5745.23 TVD, 3077.19VS, 3086.96N, 90.58W NSW, 6189.99 TVD, 3400.29VS, 3407.66N, 129.96W 3297', 47.6 3450', 49.7 4513', 45.7 5293', 44.6 5700', 42.7 6400', 41.5 6950' 39° 7500' 33° ~hg The above is correct Signature For form preparation an(~rdistribution, see Procedures Manual, 'Section 10, Drilling, Pages 86 and 87. ITitle Drilling Superintendent i ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Rel:~rt" on the first Wednesday after allowable has been assigned or wel! is Plugged. Abandoned. or Sold. "Final Rel~rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On worl(overs when an official test is not required uOon comoletion, report completion and representative test data in blocks prowded The "Final Report" form may be useO for reporhng the entire operation if space is avadao,e District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK0359 Parker 141 Operator ARCO Alaska, Inc. Spudded or WO. begun Spudded 12/03/85 Date and depth as of 8:00 12/11/85 ICounty or Parish Lease or Unit Title IA.R.Co. Date Complete record for each day reported North Slope Borough Accounting cost center code State Alaska ADL 25631 Well no. 3A-13 Drill AP1 50-029-21489 W.I. rTotal number of wells (achve or ,nachve) on th~s ICost center prior to plugging and 56.24% Jabandonment of th,s well 1 IHour I Prior status ~f a 11/25/85 / 2330 hrs. / 7" @ 7614' 7630', (0'), RR Rn 174 jts, 7", 26#, HF/ERW BTC csg w/FS @ 7614', FC @ 7525' Cmt w/100 sx Cl "G" w/8% D-20, .2% D-46, .5% D-65 & .5% D-112, followed by 300 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Bump plug. ND BOPE, Instl pack-off, NU &tst tree to 3000 psi. Pmp 50 bbls diesel into 9-5/8" x 7" ann. RR @ 1700 hrs, 12/2/85. Well was Arctic packed w/175 sx AS I. O~c TD New TD Released r~g Date 1700 hrs. Classifications foil. gas. etc.) 0il 7630' TD Depth 12/2/85 Type completion (s~ngle. dual. etc.) Single Producing method Official reservoir ~'ame(s) Flowing Kuparuk Sands Potential test data 7523 ' PBTD Rotary ¢,ell no. Date Reservoir P,oducing Interval Oil or gas Test t,me Produchon Od on test Gas per day Pump size. SPM X length Choke s~ze T P C.P. Water % GOR Grav,ty Allowable Effective date corrected The al3ove is correct Signature For form preparation al~ distribution. see Procedures Manual. Section 10. Drilling. Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3S01 Porcupine Drive Anchorage, AK 99501 ~uouECT- State Reports Dear Mr. Chatterton' Enclosed are the December monthly reports for the =olluwing wells' ZA-7 2H-6 3A-13 3F-12 3J-ii L-29 L2-29 LA-!3 2H-7 3A-!4 3F-13 3J-!2 !6-!5 L3-5 ~.-!4 2H-8 3A-15 3F-14 ~-23 '6-!9 L3-!9 1H-4 2H-9 3A-16 3F-15 ~-24 ;6-20 _~F-8 ~X-8 3F-11 3J-10 ~-27 '~_~-21 you have any euestions, please call me at Sincerely, ~. Gruber Associate Engineer JG/tw "" !3/L0 o.--,IJ 5 Enclosures RECEIVED JAN 1 z, 1986 0il & Gzs C, ur, s. ~ra~ Uomm~s,siorl - STATE OF ALASKA ALASKA O.,_ AND GAS CONSERVATION COI,..,,IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS -- Drilling wel~X~ Workover operation __ 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well atsurface 817' FSL, 825' FEL, Sec.7, T12N, R9E, UN (approx) 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. 72' RKB ADL 256:31 ALK 2565 I 7. Permit No. 85-281 [3. APl Number 50 029-21489 i9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-13 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of December ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2330 hfs, 11/25/85. Drld 12-1/4" hole 'co 3341'. Ran, cmtd, & tstd 9-5/8" csg. Dr]d 8-1/2" hole to 7619'. Ran logs. Cont'd drlg 8-1/2" hole to 7630'TD (12/01/85). Ran, cmtd, & tstd 7" csg. PBTD = 7523' Secured ~,el] & RR (~ 1700 hfs, 12/02/85. 13. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set 6 107'. Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe 6 3321' Cmtd w/1200 sx AS II1 & 300 sx Class "G". 7", 26.0~/ft, J-55, BTC csg w/shoe ~ 7614'. Cmtd w/400 sx Class "G" & 175 sx A5 I. 14. Coring resume and brief description Hone 15. Logs run and depth where run DIL/GR/SP/SFL f/7605' - 3321'; GR to 1800' FDC/CNL f/7605' - 7000' & 5200' - 5100' Cal f/7605' - 6500' 16. DST data, perforating data, showsof H2S, miscellaneousdata None RECEIVED 1986 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE Report this form is required for each calendar month, regardless of the status of operations, and must be f~led ~n duplicate w~th the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TENP3/NR1 0 Submit in (JUDllcate ARCO Alaska, Inc. Post Office B~. ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 12-19-85. TRANSMITTAL # 5473 Transmitted herewi*~h are the following items. Please acknowledge receipt and return one signed copy of ~his transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each 1Q-4/f 03-18-85 Run 01 4570.0-9471.0 ref#'70997--£~d~f~ ~2H-9/w 12-02-85 Run 01 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run 01 2856.0-7960.0 ref# 71002 "~2H-12 /, 11-07-85 Run 21 2743 0-6829 0 ref# 79947 ~2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# 7095~CC~d/d "~2V-16// 06-03-85 Run #1 2973.0-7168.0 ref-~ 70952-r~d~p ~3A-lOM 11-09-85 R~n #1 3179.0-7014.0 ref# 70960 ~3A-!!', 11-16-85 Run #1 3208.0-7330.0 ref# 70989 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref# 71003 ~'-3A-13;/ 12-01-85 ~un 01 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 R~n #1 0144.5-7818.0 ref# 71073 3C-9~ 07-10-85 Ru~ #1 3920.0-8332.5 ref# 70996--~ 3F-8-/ 11-09-85 Run #l&2 0115.0-7040.0 ref~ ~0q94 ~3F-9/~, 11-17-85 Run 01 3410.0-7770.0 ref# 70990 "~3F-10'~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 3F-11~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 ~J3J-9-/ 11-24-85 R~n #l&2 0~91.0-6789.0 ref# 71034 3J-10-~ 12-08-85 Run 01 0096.5-7348.5 ref# 71074 Receipt Acknowledged 'STATE OF ~S~* ARCO Date: ARCO Alaska, Inc. - Post Office Bo. 0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures t EC£1VED ~ L,~ COns. Co~issio~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompan¥ - STATE OF ALASKA ALASKA O1~ AND GAS CONSERVATION CON..,ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drillingwe~'~ Workover operation ~ i2. Name of operator ~ 7. Permit No. ! ARCO Alaska, lnc. 85-281 i Address P. O. Box 100360, Anchorage, AK 8. APl Number 99510 50 029-21489 14. Location of Well atsurface 817' FSL, 825~ FEL, Sec,7~ T12N~ R9E, UM (approx) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 72' RKB ^DL 25631 ALK 2565 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3A-13 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. November 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 2330 hfs, 11/25/85. Drld 12-1/4" hole to 3341'. Ran, cmtd, & tstd 9-5/8" csg. hole 'co 6459', as of 11/30/85. Drld 8-1/2" t3. Casing or liner run and quantities of cement, results of pressure tests 16", 62.5#/ft, H-40, weld conductor set L~ 107' Cmtd w/195 sx AS II. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe @ 3321' Cmtd w/1200 sx AS I11 & 300 sx Class "G". 14. Coring resume ano brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 1 7. I hereby certify that the foregoing is true and correct to the best of my knowledge. SI TITLE Associate Engineer DATE /~ dt-~ NOTE Reporut/ on this form is required for each calendar month, regardless of the status of operations, and must be f~led in duplicate ,,~th the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10~04 DRH/NR57 Submit in duplicate November 22, 1985 Mr. J. B. Kew~n Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska q9510-0360 Re: Kuparuk River Unit 3A-~ ARCO Alaska, Inc. Permit No. 85-281 Sur. Loc. 817'FSL, 895'F~., Sec. 7, T]2N, R9E, ~. Btm~ole Loc 10]_~'F~,, I~9~'FEL, Sec v. T]O~.,, R9E ~ Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain mdditionm7 permits required bv law from other governmental agencies prior to commencing operations at the well site · To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission mav be present to witness testing of the equipment before the ~urface casing shoe is drilled. !~here a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may w~.tness testing before drilling below the shoe o~ the conductor pipe. /~ tr!~~ursF / C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Co~nnission BY ORDER OF ~F COM~ZSSION be Enclosure cc: Department of Fish & Game, Habitat Section w/o enc]. Dep~rtment o£ Environmental Conservation w/o e~cl. Mr. Doug L. Lowery ARCO Alaska. Inc. Post Office Box ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 ~985 November 18, ~ Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3A-13 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3A-13, along with a 5100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment We estimate spudding this well on December 1, 1985. any questions, please call me at 263-4970. If you have Sincerely, · ' 'ng Engineer PD/L178 Enclosures .. STATE OF ALASKA - ALASKA O~- AND GAS CONSERVATION CON,,ClISSION PERMIT TO DRILL 20 AAC 25.005 ! la. Type of work. 2. Name of operator ARCO Alaska, Inc. DRILL -)(-X_ lb. Type of wel __ REDRILL _ -- DEEPEN _ EXPLORATORY _ DEVELOPMENT OIL ~--'~X __ DEVELOPMENT GAS ~ 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 817' FSL, 825' FEL, Sec.7, T12N, R9E, UN At top of proposed producing interval 1252' FNL, 1194' FEL, Sec.7, T12N, R9E, UP At total depth 1012' FNL, 1222' FEEs Sec.7, T12N, R9E, UM -/~/f- ~' 5. Elevation in feet lindicate KB, DF etc.) 6. Lease designat,on and serial no. RKB 72', PAD 41' ADL ~ ALK 2565 12. Bond information (see 20 AAC 25.025~ Statewide Type Surety and or number SERVICE _ STRATIGRAPH SINGLE ZONE MULTIPLE ZON ~-.~ C: ~--' 9. Unit or lease name'- Kuparuk River tJnit 10. Well number 3A-1 3 11. Field and pool Kuparuk River Field Kuparuk River O'.'l Pool Federal Insurance Compa~y-- #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi. NW of Deadhorse miles 16. Proposed depth /MD & TVDI 7613' MD, 6308' TVD feet 14. Distance to nearest property or lease line 101 2 ' (~ TD feet 17. Number of acres in lease 2560 19. If deviated !see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT 1862 feet. MAXIMUM HOLE ANGLE 43 : . (see 20 AAC 25.035 Icl Proposed Casing, Liner and Cementing Program 15. Distance to nearest dr~lltng or completed 3A-1 2well 26' ~ surface feet _ 18. Approximate spud (]late I .~'/ /~' ~' ' 2683 [ pSI~~g;~ 80u~ Surface 3084 ps,g~:~ 6051 ft. TD ITVDi __ SIZE Hole Casing 24~' 1 6" ]2-1/4" 9-5/8" 8-1/2" 7" CASING AND LINER Weight Grade I Coupling Length 62.b# H-4U ' Weld' 80' 36.0# J-55/HF-ERW BTC 3273' 26.0¢ J-55/HF-ERW BTC 7582' 22. Describe proposed program: SETTING DEPTH MD TOP TVS I MD BOTTOMTVD 32' 32' t 112~ 112' 32' I 32' 3305' 3172' 31' ' 31' 7613' 6308' QUANTITY OF CEMENT i~nclude stage datat 200 cf 1050 sx AS I11 & 300 sx Class G 400 sx Class G ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7613' MD (6308' TVS). Selected intervals will be iogged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" surface pipe. The stack and related equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2683 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. 3A-13 will be 26' away from 3A-12 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) 23. I hereby cer~that the foregoing is true and correct to the best of my Knowledge ~.SIGNED .//Z~/~~'~./~-//~/. ~ ~ TITLE Regional Drilling Engr. DATE .~'4,~;2/~~ Ine space B/~w TC~' ~orn~lss~on use CONDITIONS OF APPROVAL Samples required N/iud log required ~YES ~,NO ~YES ~'-NO _ Permit number Approval date ,~~1 ,4, ~~1"~/2~ / 8~ Form 10401 (JFB) PD/PD178 t / / , R~v 7-1 Directional Survey requ~rea J APl numbe? / ----~' 'YES _--NO J 50 ~ _'-: ,L,-' "~ i SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE November 22; 1 9R5 by order of the Commission Submit ~n triplicate PERMIT TO DRILL 3A-13 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. _ _ - ~].000-, .................. --~-2000_ · --BASE PERMAFROST -TVD-t552 ............... KOP TVD--1862 TMD=1862 DEP-O -3..--TOP--UGNU-SNDS .... TVD-2OO2':TflD'2002 -OEP-5 - _ _ 9 BUILD 3 DEG : ........ !5 PER !00 FT' - - .... ~---~000 · ~-. ~ K-12 TVD=2972 TMD 3046 DEP 355--- _ _ __--- :-:- _ --~ ......... __ TVD-3.1.Z2:T,D=3305: DEp 520_ . - - - .. ; X ~E~AGE ANGLE ........ · ............ ~__4ooo ...........~.. _._ 4~ DEG 17 587 TMD~5249 DEP~1853 : . X T/ZONE D TVD'~967 T~'~145 DEP=~152 - - ' ....~-- T/ZONE C TVD 5985 T~ 7170 OEP ~, ', T/ZONE A TVD"6051 TffiD'7261 DEP"~2~2 - : : ~ TARGET CNTR TVD-610Z TMD=7338 DEP=32~ . . _ -?OO0_ ] 000 .... :~000 ";-,..L ~ . LL., 2000 - - 4000 ' VERT-I CAL:-SEC/ION ........ .-:-j ,_-- :?! · ..... . :'.-. k b., HORI~ONT^L PROJECTI ON SCALE 1 IN. = 1000 FEET ARCO ALASKA-' -!NC.' PAD 3A. WELL NO, 13 REVISED PROPOSAL KUPARUK F,ELD. NORTH SLOPE. ALASKA EASTMAN WHIPSTOCK. INC. WEST-EAST 2000 1 000 0 1 000 2000 I I I I ...... 5000 TD LOCATION ~ ~0~:~' F#L. ~222' FE:L ~:C, 7. T12N. RgE: 4000 - TARGET LDCAT I ON, 1200' FNL. 1200' FEL - ~"EC , 7. T12N . RgE 3000 - .z o 2000 - 1000 - 1 000 . · T^Rt~ET CENTER TVD-6;107 Tt'ID-7'338 DEP:3,284. NORTH 3263 WEST 37'4 '~ SURFA~ SURFACE LOCATION, ......... 817' -FSI.. 826'- FEL S~_C.._ ?. T1 ,~_ RgE: N --6 DEG 32 MI N.-.:~A~ .-:, ~ .-- 3284' (TO TARGET) ' ' ' ! i Ii · I : : : ~ ,I i .... .1--- ~ . ' : * ; . ~ , ; · .~, .... ,.: . . _ . ii ~ ~ ' ~ i ~ ! i i ·' -" ..q ~ . ~ , , . , , ~ . ~ . ~ . ~_i~ :. I'll!i *!! :,ii ' ~ '' ' " ' : ' , i [ :~ I I ,I-- ~ : . 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' · ' I-:: '~-' '! -" :'' --~-~ ..... "'--/ _~_%..:' ~._ '. :_ '.:__ ::z __:_ ::_'_' .... ::r _~.~..,,%___~. ,;,~,.,, i~___i~ -' :--'___~: :: _-------: i~ ix -~-;'---c-..::~-~;~:o -_:_~i ii! ! .... -'--- ..... -'~--I~°°"-"' ~' -:'~~----- ----':'-~----~"'~:'---~-- ___ , .............. .... O----~'"'"'--~,., ---ff -- - 8..0_. _%-,o-___ ~....._-.: --:---~. .............. :~.."-:-f--'-.:..' ;.;..-~ ,'"",Z' ..._ .---'.~ose i ,,-,,,- 1- .~nn .... !--~ :-'-~ -'i ~ ........ --'"':--- "'"~ ...--T -',:-2---%:- --':'--- i ~ '.-7 -b --'-'1.%2049]~_-.-.-~__i__:;~'"_'%'.__7F : .; , __1 '~---~---~5~," ' --' !, ,,' .__ :__-_:--; : -4-: ..... :_,,__ -t, -. · · i ! ; : - .... j , . · . i~ ' - ' I ' ...... ~ .! .... : . , i. ;- t -'--"- - ¢ ~ j , . ! , '. . , i ,. , ! i ......... ~.- t . _ ,. i .... : ~ , , ! · ; _ -- .' i 'i ' : ' i i' ": ]' 5 Ix'':'-:' '! ': c ~::::! - - I ; - i ---4- " KUPARUK R VER UNIT 20" -D~ VEF~TER SCHEMAT ~C · DE S CR I P T I ON I. 16' C~CTOR. 2. TAhi,(O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOVNER QUICK-C~CT ASSY. 5. TAhi<O UPPER QU]CK-C~CT ASSY. 6. 20' 20(;X) PSI DRILLING SPO0. W/lO" OUTLETS. ?. I0' NCR BALL VALVES W/I O' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE ~ Ah, I'll. AR PREVENTER. 8. 20' 2000 PSI ANI"IJLAR PREVENTER. MAINTENANCE & OPERAT)ON I. uP-ON INITIAL INSTALLATION. CLOSE PREVENTER ANE) VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE A~4JLAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANINIULAR PREVENTER I N THE EVENT THAT AN IhFLUX OF ~LLBO~ - FLUIDS OR GAS IS DETECTED. IF NECESSARY, MAhEJALLY OVERRIDE AND CLOSE APPROPR I ATE VAL YE TO ACHIEVE ~IND DIVERSION. DO NOT SHUT IN ~LL UI'~:DER ANY C I, ECU. N~;..T,A~NC~E$. < 7 , 6 > > 13-5/8' ~ PSI RSRRA BOP 5TACK I. 16' - 2000 PSI TAI~ STAR'rING I-EAD 2. I1' - 3000 PSI CASING 4. 1~8' - ~ ~1 P]~ 5. 1~8' - ~ ~I ~I~I~ 6. 1~8" - ~ ~1 ~ ~ ~I~ ~ ~ T~, 7. 13-5/8' - 5000 PSI ~ ACCL~ATOR CAPACITY TEST I. O-~(:X ~ FILL AC~ATOR R~IR TO I:~ LEVEL WITH HY~IC FLUID. 2. A~ THAT AC~ATCR PRE~ IS 3000 PSI WiTH 1500 PSI DONI~TEEN~4 ~ T~-[ REGU_ATC~. 5. ~ TII~, TI-EN CLCI~ ALL UNITS SII~JLTAI~_IcEY AND RECORD TI-Ii TIldE At~D PRESSURE REMAIN1NS AFTER ALL UN~T5 ARE CLOSED WITH CHARGING ~ (]=F. 4. RECORD ON NADC REPORT. TIE ACC~PT~ LONER LIMIT IS 45 SE~ CU3SING TIN[ ~ 1200 PSI RE]w~INING 5 4 2 KUPARUK 13-5/8" BOP STACK TEST I. FILL BOP STACK ~ ~ Ma~IIF~D WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK ~ SCREWS IN I~E_LL~ ARE: FULLY I:~'TRACTED. SEAT TEST PLUG IN I~LLI-E_AD WITH ~ING JT AI~D RUN IN L~ SCREWS. 3. CL~ N~NJ_AR PRE~ N~ ~ KILL ~ CHI3Q[ LIllE VALVES ADJAI3DVT TO BCP STN:::X. ALL OTi~'R VALVES N~) CHCKES SH~JLD BE [PEN. 4. FRESIIJ~ UP TO ZSO PSI AM:) HCLD FOR I0 MI~ IN- ~ PRE~ TO~ ~ HOLD FOR I0 MI l~ BLEED PRESg-__~ TO 0 5, CPEN AhNJ. AR PREVENTER AM) MANJAL KILL AN:) CIHCKE LINE VALVES. CLOSE TC]~ PIPE RN~3 A~D HCR VN_VES ON KILL AM) ~ LINES. 6. TEST TO 250 PSI AhD 5500 PSI AS IN STEP 4. 7. ~IN.E TESTING ALL VALVES. LII~ESo ~ CHCKES WITH A 250 PSI LOW ~ 3;_rzCO PSI HIGH. TEST AS IN STEP 4. DO NOT PR~S"S'tJ::~ TF~T MCr C:HCKE THAT N3T A FLLL CLOSING POSITIVE SEAL CHO<E. C]~LY ~TIQN IF_ST CHCKE5 7HAT DO NOT FULLY CLOSE__. 8. (]:~N TCP PIPE ~ N~D CLOSE BOTT(]~ PIPE TEST BOTTCM PIPE ~ TO ~ PSI AN:) 5500 PSI. 9. CPEN BOTTCM PIPE ~. BACK OUT RLN~NG JT AhD I0, CLOSE BLIND ~ At~ TEST TO 950 PSI At~) 3500 PSI. II. OPEN BLII~D ~ ~ RETRIEVE TEST PLUG. MAKE SURE hIN~IIFOLD AhD LINES ~ FLLL C:F M3N-FREEZING FLUID. SET ALL VALt/ES IN DRILLING I::K3SITI~ 12. TEST STAI~[]mIPE VALVe_So KF]IYo KELLY COCKS. DRILL PIPE SN:t'TY VALVE, N~D II~SII::E B(DP TO 2.50 PSI AN:) 35OO PSI. 15. RECORD TEST II~FCI:Ba~TION C:N BL~ PRE~ER TEST FI:Ii~NL SI(~L AM) SEI~D TO [:;RILLING SLPERVISCR. 14, PERFCR~ CCM:~ETE ~ TEST AFTER NIPPLING UP WEEKLY THEREAFTER FLI~CTICNALLY OPERATE ~ E~ILY. 16' CONDUCTOR BOP STACK 5 i 008400 ~ R6 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton: Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~J. Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG 0 1985 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AllanticRichlieldCompany 7 8 18 NOTES S:CRDINAT~S ,~RE A.S.P,ZONE 4 SECTION _,NE DISTANCES ARE TRUE. HOR:ZONTAL POSITIONS BACED CN THE D.S.-3A WEST ~ 3AMID PER LHD ~ ASSOC. 4. VERTICAL POSITION BASED CN 3A EAST & 3A MID PER LHD B ASSOC. 5.CC. ELEVATIONS iNTERPOLATED FROM S/C D~G. CED- RlXX- 3020 rev. ~ ~ ~ F ROBERT ~ELL ~ ~ ~.<,. '. ..'. ;,- ~ IflEREBY CERTIFY THAT I ,AM PROPERLY REG~STE:IRED ~.N::) L~SCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT THIS PLAT REPRESENTS A SURVEY MACE UNDER MY DIRECT SUP=__RV, SION AND THAT ALL DETAILS ARE CORRECT AS Of AUGUST 14,1985 LOCATED IN PROTRACTED SEC.T,T. / I\l= J J ~ A~s~ 0il& Gas Cons. Commi~sl~h ,z J~ 7 8~[' 'I 9, ~nchorage AS BUILT CONDUCTORS I- 16 l- ¥=$,9g§,860.05 LAT= 70°2~'0~.520'' X= 507,712.01 ' 0NC= 1,,9)%6' ''..J2'3'' 478' :$L, 736' eEL, 35.9 0]. ~0.8 PAC 2- Y=5, ~g6, ~. 17 LAT= 70°7,,' 3;. 7~B'' 503' =SL, 7~3' ;GL. 35.8 ~,, .,'. ~ :27' :SL, 7~g':{L, !6.7 :.3, ~- ¥:5,~gS,g32. 72 ~A'~ 73°2a' 1~.235'' 5~1' :SL, 756' :EL, 36.7 ?,5. ~.~ :- ~=5,~6.. , ~55. 61 ~:- ~ ...... ~ ,~.. " 6- ¥=5,~6,~80.~$ :At= ?0°2~' 10.7~9'' x= 507,679.66 LONG- 1~9°56' I~.96]'' 5~9' :$L, 7§$' :[k, 36.5 OG, ~O.~ 7- ~=5,~97,00a.~0 :it= 70°2S' 19. x= 537,673.25 LONG: Is9055' 15 L~[: 70~ :~.' [ :. i~!'' LONG: l.~°~' 15 LAT= 70°24' 11.893'' LONG= 1~9°55' 15 ~EL, 36.3 0,3, ,1. ~'~ LAT= 70°2~' ! . 1 ~" LONG= 1~9~5' 15 ~ ~" FEL, 36.3 LA~= ~0~2~' 12.37!'' LONG= 1~:~55' l§ F£L, 36.2 0G, ~ ~ P~' L~t= 70°2~'12.5J~'' LONG= ~EL, 36.1 SG, -1.~ '' LAT = 700 ~' ~:L, 36.9 ~3, ~l.- ' ~'=.~,3?:~'~_ ~: , :EL, ]5.~ g3, ~. ' : . 9,-':~L, !5. 5 "l, .:.. · · ARCO Alask~,ln~. CONDUCTOR AS- BUILT LOCATIONS Do,e AUG. 16, 1985 Sca[. I' Droffed ~¥:E_~ O~. no. NSK 8- f=5,ggT,029.03 ;'= 507,566.81 5&7' FSL, 781' ~- f=5,997, 101.2& ~= 507,6~7.70 720' r~L, 800' 10- ¥=5,9~-, 125.66 ~= 5_ .6~0.89 i44' : :~, 806' Il- ¥=5,gg-, 149.8~ x= 50',53~.~ 7§8' FSL, 813' 12- ¥=5,997, 173.97 507,627.~6 792' FSL, 819' 13- Y=5,997, IgB.O9 ~: 59~,!31.~ ~17' :~_. ~25' 15- [LIVID ~55' ;GL, g3B' CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ~--~/~ ~, ITEM APPROVE DATE (2) Loc ~._ . //'"f ~-~o.F"~ (2 t~i-u a) (8) ' ' (3) Admin ~ //'-/J¥~.J' 9. (/9' thru 12) 10. . (10 and 12') 12. (13 'thru 1. Is the permit fee attached .................................. YES NO REMARKS 2. Is well to be located in a defined pool .................... 3. Is well located proper distance from property li;e ......... 4. Is well located proper distance from other wells ......... 5. Is sufficient undedicated acreage available in this pool i i} 6. Is well to be deviated and is wellbore plat included .... 7. Is operator tile only affected party ..................... i 8. Can permit be approved before ten-day wait .................. 13. 14. 15. 16. 17. 18. 19. 20. 21. · · e · · · e e~ · · · e · e e · Does operator have a bond in force .................................. zk__,. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ..................... Will all casing give adequate safety in collapse tension :nd burstl Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ <s) Boer, >.'",TX ' ~-"' ftt; :> ,; ,~.. (22 thru/'2365 22. 23. 24. 25. 26. (6) Add: % '~'~ ' ~c,--" 27. ~ ,: f :) .. . - .' Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ;",,' Does BOPE have sufficient pressure rating - Test to ~-~.~ psig .. ~/77/ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. Additional Remarks: 77,£7_.! ~/7' ' Geology: Engineering: WVA ,~/__ MTM/. -HJH '.,?' JAL ~-,,,~ rev: 03/13/85 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. ,. -- II .. .J '1 ' - · ....... ,- -- 'i': ; · ) ' ":' '" - :: :-' ? : :1,) · . ... · ". T:: -:I,. . · , + : · · e · , · -. · - : · · - . + , . - , .. .. .. · .' · -. · · · ·