The URL can be used to link to this page

Home My WebLink About182-198 ' RECEIVED 1 STATE OF ALASKA • AL.A OIL AND GAS CONSERVATION COMMIION JUL. 1 9 2013 REPORT OF SUNDRY WELL OPERATIONS C 1.Operations Abandon (J Repair Well Li Plug Perforations J Perforate Li Other Li Bright Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development❑ Exploratory ❑ 182-198-0 ' 3.Address: P.O.Box 196612 StratigraphiC Service E' 6.API Number: Anchorage,AK 99519-6612 50-029-20870-00-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028330 PBU 12-19 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL ' 11.Present Well Condition Summary: I I Total Depth to l ept measured 11930 feet Plugs measured 11459 feet true vertical 9217.72 feet Junk measured None feet Effective Depth measured 11459 feet Packer measured See Attachment feet true vertical 8871.02 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 79 20"91.5#H-40 33-112 33-112 1490 470 Surface 2398 13-3/8"72#L-80 32-2430 32-2429.6 4930 2670 Intermediate None None None None None None Production 11160 9-5/8"47#L-80 31-11191 31-8677.34 6870 4760 Liner 1033 7"29#L-80 10887-11920 8464.52-9210.39 8160 7020 Perforation depth Measured depth See Attachment feet nt i� True Vertical depth See Attachment feet SCANNED N O v 0 6 2013 Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11392'-11452' Treatment descriptions including volumes used and final pressure: 1345 GAL EC9360A SURFACTANT,6934 GAL EC9408A POLYMER 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl . Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ Service El ' Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas U WDSPtIJ GSTOR ❑ WINJ ❑ WAG IS • GINJ ❑ SUSP ❑ SPLUC-❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays(a.BP.com Printed Name Nita Summerhays Title Petrotechnical Data Technician Signatur /A. � � Phone 564-4035 Date 7/19/2013 NNW ihiii�i� Ll��i/1� 1/1F RBDMS JUL 2 3 70 Form 10-404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028330 T/I/0=228/180/10 Temp=HOT (RESEVIOR SWEEP MOD) Pumping brightwater chemicals down TBG while on water injection @ 3000 bwpd. Pumped 102 gal. EC9360A(Surfactant) Average of 20.5 gph for 5 hrs. Pumped a total of 102 gal. since start of project. Pumped 415 gal. EC9408A( Polymer) Average of 83 gph for 5 hrs. Pumped a total of 415 gal. since start of project 6/19/2013 ***Job continued to 6-20-13 WSR*** ***Job continued from 6-19-13 WSF **(Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3000 bwpd. Pumped 281 gal. EC9360A(Surfactant) Average of 11.7 gph for 24 hrs. Pumped a total of 383 gal. since start of project. Pumped 1836 gal. EC9408A( Polymer) Average of 76.5 gph for 24 hrs. Pumped a total of 2251 gal. since start of project 6/20/2013 ***Job continued to 6-21-13 WSR*** ***Job continued from 6-20-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping Pumped brightwater chemicals down TBG while on water injection @ 3000 bwpd . Pumped 428 gal. EC9360A (Surfactant) Average of 17.8 gph for 24 hrs. Pumped a total of 811 gal. since start of project. Pumped 1907 gal. EC9408A( Polymer) Average of 78.4 gph for 24 hrs. Pumped a total of 4158 gal. since start of project 6/21/2013 ***Job continued to 6-22-13 WSR*** ***Job continued from 6-21-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3000 bwpd. Pumped 357 gal. EC9360A(Surfactant) Average of 14.875 gph for 24 hrs. Pumped a total of 1168 gal. since start of project. Pumped 1810 gal. EC9408A( Polymer) Average of 75.4 gph for 24 hrs. Pumped a total of 5968 gal. since start of project ***Job continued to 6-23-13 WSR*** 6/22/2013 • • Daily Report of Well Operations ADL0028330 ***Job continued from 6-22-13 WSR*** (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 3000 bwpd. Pumped 15 gal. EC9360A(Surfactant) Average of 15 gph for 1 hr. Pumped a total of 1183 gal. since start of project. Job completed Pumped 51.25 gal. EC9408A( Polymer) Average of 51.25 gph for 1 hr. Pumped a total of 6009 gal. since start of project. Job completed ***Over pump remaining polymer per PE*** Pumped 162 gal. EC9360A (Surfactant) Average of 13.5 gph for 12 hrs Pumped 915 gal. EC9408A ( Polymer) Avera e of 76.25 gph for 12 hrs Final valve positions upon LRS departure; SV=open, WV MV=open, IA/OA=OTG 6/23/2013 FWHP 350/220/20 FLUIDS PUMPED GALS 1345 EC9360A SURFACTANT 6934 EC9408A POLYMER 8279 TOTAL Perforation Attachment ADL0028330 SW Name Operation Date Perf Operation Code _ Meas Depth Top Meas Depth Base TVD Depth Top ND Depth Base 12-19 9/30/1988 SQZ 11327 11328 8775.05 8775.77 12-19 9/30/1988 RPF 11328 11344 8775.77 8787.33 12-19 9/30/1988 SQZ 11344 11346 8787.33 8788.78 12-19 9/30/1988 SQZ 11351 11352 8792.4 8793.12 12-19 9/30/1988 RPF 11352 11392 8793.12 8822.14 12-19 4/19/1992 RPF 11392 11431 8822.14 8850.56 12-19 4/19/1992 RPF 11431 11432 8850.56 8851.29 • 12-19 4/19/1992 RPF 11432 11452 8851.29 8865.9 12-19 7/25/2006 SPS 11465 11500 8875.42 8901.1 12-19 7/25/2006 SPS 11500 11505 8901.1 8904.77 12-19 7/25/2006 SPS 11510 11550 8908.45 8937.88 12-19 7/25/2006 SPS 11559 11560 8944.5 8945.24 12-19 7/25/2006 SPS 11560 11584 8945.24 8962.92 12-19 7/25/2006 SPS 11584 11585 8962.92 8963.65 12-19 7/25/2006 SPS 11590 11598 8967.34 8973.24 12-19 7/25/2006 SPS 11602 11620 8976.18 8989.46 12-19 7/25/2006 SPS 11639 11649 9003.49 9010.88 12-19 7/25/2006 SPS 11649 11684 9010.88 9036.77 12-19 7/25/2006 SPS 11684 11688 9036.77 9039.73 12-19 7/25/2006 SPS 11688 11689 9039.73 9040.47 • Casing / Tubing Attachment ADL0028330 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 91.5# H-40 33 - 112 33 - 112 1490 470 LINER 1033 7"29# L-80 10887 - 11920 8464.52 - 9210.39 8160 7020 PRODUCTION 11160 9-5/8"47# L-80 31 - 11191 31 - 8677.34 6870 4760 SURFACE 2398 13-3/8" 72# L-80 32 _- 2430 32 - 2429.6 4930 2670 TUBING 10747 5-1/2" 17# L-80 29 - 10776 29 - 8389.06 7740 6280 TUBING 24 5-1/2" 17#L-80 10769 - 10793 8384.34 - 8400.53 7740 6280 TUBING 21 4-1/2" 12.6# L-80 10793 - 10814 8400.53 - 8414.73 8430 7500 • TUBING 94 4-1/2" 12.6# L-80 10820 - 10914 8418.8 - 8483.11 8430 7500 TUBING 4 5-1/2" 17# L-80 IPC 11620 - 11624 8989.46 - 8992.41 7740 6280 TUBING 9 3-1/2" 9.2# 13Cr80 11624 - 11633 8992.41 - 8999.06 10160 10530 • • 0 Packers and SSV's Attachment ADL0028330 SW Name Type MD TVD Depscription 12-19 PACKER 10685 8251 5-1/2" Baker S-3 Packer 12-19 PACKER 10796 8325.56 4-1/2"AVA PPH Hydraulic Set Perr 12-19 PACKER 11620 8912.46 5-1/2"Otis Packer • TREE= OW • S NOTES: H2S READINGS AVERAGE 125 WB LFEAD= FMC ppm I I ON MI.WELL REQUIRES A SSSV _.. _. U 2— 19 WHEN ON ML •**O ROME JEWELRY SURFACE ACTUATOR= BAKER C INmAL KB.6 E1/= 77' TO 10776'&CHROME WO PIOR ASSY�11620'"* BF.mil!_ ___.__. I I KOP 2800 Angle= 51 7200' I 2106' H5-1R"FEB X h110(9-CR),D=4.562" Datum MD= 1146T Datum ND= 8800'SS 13-318°CSG,72#,L-80 BIM,D=12.347* H 2430' 10653' H5-1/2"I�5 X NP(9-Cif,D=4.562" I 1 _ Minimum ID =.50"@ 10907' �� L10685 H9-5/8"X5-1/2"BKR S-3 PIS D=4.750" I 4-1/2" XN LOCK CHOKE II 10749' H5-1/2" - X NP(9-CR),D=4.562" I 5-1/2"1BG,17#,L-80 TCI,.0232 bpf,D=4.892" —1 10760' 10776' H8.210"X 5-1/2"UNIQUE OVERSHOT(9 CR) I 5-1/2"-TBG STUB(11/20/08) —I 10769' 10793' H5-1/2"X 4-1/2'XO,D=3.958" It �� PM 10796' 9-5/8"X 4-1/2"AVA HYDRA PKR,D=4.75 I 10814' Hr 7' 1 LOt1T EXTENSION,D=6.3r I 10820' Hr X 4-1/2*XO,D=3.958" 1 TOP OF r LNR --1 10887' 10887' H9-5/8"X 7" BKR HGR w/TRACK SLV I 1 10907*__I-14-1/2"SCR SWN NP,D=3.725" I 4-1/2"TBG,12.6#,F'C L-80 BTC-M —1 10914' I 10907' 1-14-1/2"XN LOCK,DH CHOKE ASSEMBLY, .0152 bpf,D=3.958' I J 13=.50"(04/23/13) 19-5/8"CSG,47#,L-80 BTRS,D -=8.681' I 11191' 1 10914' 4-1/2"WLEG,D=3.958" I I 10904' H EL MD TT LOGGED 04/19/92 I 11289' H7"MARKER JOINT I 1 c/'1y'1.4'1'1' 11459' HTOP OF CEMENT(0726/06) I ♦1 ♦ 11528' --I TOP OF SAND(0726/06) I lit11620' Hr x 5-1/2.OTIS WD PKR,D=4.00" I 3-12"TBG,92#,13CR-FOX, —I 11634' 0087 bpf,o=2.992' 11625' -15-12"X 3-1/2'XO,D=2.992" I ' I 11632' H3-1/7'RCR SWN NP,D=2.75" 1 PERFORATION SUMMARY 1 11634' H3-12"WLEG,D=2.992° I REF LOG:BHCS ON 12/07/82 ANGLE AT TOP FBRF:43"It 11328' Note:Refer to Production DB for historical perf data 1 I 11632' H/3.K)TT LOGGED ON 02/11/93 I SIZE I SPF I INTERVAL I Opn/Sgz I SHOT I SQZ SEE PAGE 2 FOR PERFORATION DATA I 1 I I 1 PBTD 116777' I •••••••••••••••1 17"LNR,29#,L-80 BTC,.0371 bpf,o=6.184" H 11920' I ∎'�'�•�'�•�'�•1' ••■••••• TO —I 11930' AAA tAtt A DATE REV BY CQMNBJIS DATE REV BY OOMI.BNT'S PRI.TDHOE BAY UNIT 12/25/82 ROWAN 21 ORIGINAL COMPLETION 01/11/12 TMWJMD ADDED Ii2SSAFETY NOTE WELL: 12-19 12/15/91 N3S IRWO 05/03/13 DLW/JMD SET DH CHOKE(0423/13) PBituTT No: 1821980 11/20/08 D16 RYVO AR No: 50-029-20870-00 07/26/06 RWL/PAG(Mn/SAND TOP SEC 18,TON,R15E,573'FSL&935'FEL 11/08/06 BGGRLH PERF OORIRUCTTONS 02/09/11 MB/JAM ADDED SSSV SAFETY NOTE BP Exploration(Alaska) 12-19 PERFS 1 1 1 1 R B 1 1 J PERFORATION S& MARY REF LOG:81-CS ON 12/07/82 1.111 ANGLE AT TOP PEW 43°@ 11328' / (Note:Refer to Production DB for historical pert data SIZE SPF NTERVAL Opn/Sqz SNOT SQZ 3-118' 11326-11346 S 09/25/83 05/12/88 3-1/8' 4 11350-11430 S 09/25/83 05/12/88 3-3/8" 6 11391-11411 S r 12/91 12/91 3-3/8" 4 11392-11452 0 04/19/92 4.0.4.O.'V 3-3/8' 6 11411-11451 S 05/12/88 3-3/8' 4 11465-11505 C 04/19/92 3-1/8' 11564-11584 S 05/12/88 ovr 3-3/8' 4 11589-11597 C 02/11/93 3-3/8' 4 11601-11619 C 02/11/93 2-1/8" 6 11638-11648 C 02/11/93 2-10 8 11649- 11689 C 08/07/92 3-3/8' 6 11683-11687 S 05/12/88 1 I LATE REV BY COM E NTS DATE REV BY CONVENTS PRUDHOE BAY (UT 12/25/82 IOWAN 2t ORIGINAL COMPLETION 01/11/12 TMWJMO AWED H2S SAFETY NOTE WELL 12-19 12/15/91 N3S RWO 05/03/13 CLW/.IMO SET OH CHOKE(04/23113) PERMT No: 1821980 11/20/08 D16 RtNVO MI No: 50-029-20870-00 07/26/06 RWUPAG CMT/SAND TOP SEC 18,TDN,R15E,573'FSL&935'EEL 11/08/06 BGG/TLH FEW CORRECTIONS 02/09/11 P€/JMO ADD®SSSV SAFETY NOTE BP Exploration(Alaska) • Page 1 of 2 \~2-. I`ll Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, December 11, 2009 11:18 AM ~ ,Z' ~~ ~~1 To: Regg, James B (DOA); NSU, ADW Well Integrity Engineer ~~ Cc: .Maunder, Thomas E (DOA) Subject: RE`. Missing MITs Attachments: PBU 12-19 (AIO 04C.013) AA Cancellation.pdf; MIT MPU E-07 05-25-09.x1s '~ Jim, MPU E-07 (PTD 1910490) was pressure tested on 05/25/09, however, our records do not show who the inspector was on location. I have attached the MITIA form for your review. The well is currently on water injection. PBU 04-10 (PTD 1760420) was reclassified as Not Operable on 11/07/09 due to a failing MITIA. A tubi q~patch ~ was set on 12/07/09 to mitigate the TxIA communication. On 12/08/09, the well was placed on water infection for a state witnessed MITIA. ,_ PBU 12-19 (PTD 1821980) Our records show that AIO 4C.013 was cancelled on 09/14/07. I have attached the r canceled AA for your reference. The well was worked over on 11/20/08 and placed on a 4 year MITIA schedule. It is currently on water injection. -- (~~~ ct~~ c.;! ~~ rti~~ Cr,~~~(,;;` MPU E-03 (PTD 1890170) is scheduled for a witnessed by John Crisp today. I will provide you a copy of the ,,, MITIA form at the end of the month. It is currently on gas injection. PBU S-216 (PTD 2001970) was P&A'd on 12/11/07 and hasn't been injected in since 07!20/09. There are no plans to inject in this well in the near future. I hope this helps and please let me know if you need anymore information. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~ ~ 4, QC~ 1a?'~+ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Friday, December 11, 2009 9:51 AM To: NSU, ADW Well Integrity Engineer Cc: Maunder, Thomas E (DOA) Subject: Missing MITs Following MITs are missing or late: MPU E-07 (PTD 1910490) due 10/16/2009 PBU 04-10 (PTD 1760420) due 11/19/2009 PBU 12-19 (PTD 1821980) due 12/6/2009 (AIO 4C.013) Followng MITs are due: MPU E-03 (PTD 1890170) due 12/12/2009 PBU S-216 (PTD 2001970) due 12/13/2009 12/11/2009 Page 2 of 2 These wells are shown in our database as currently injection as of October 31; unfortunately our production/injection data lags a month so some or all of these may currently be SI. Please provide current status and, if MITs have been performed that satisfy the Commission's regulatory requirements, forward the test results. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 12/11/2009 i ~ \N~~ STATE OF ALASKA AL/~A OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPE~TIONS 1. Operations Performed: ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 182-198 - 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 , 50-029-20870-00-00 - 7. KB Elevation (ft): 7T 9. Well Name and Number: , PBU 12-19 8. Property Designation: 10. Field /Pool(s): ADL 028330 - Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11930' ~ feet true vertical 9218' - feet Plugs (measured) None Effective depth: measured 11459' feet Junk (measured) None true vertical 8871' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 79' 79' 1490 470 Surface 2429' 13-3/8" 2429' 2429' 4930 2670 Intermediate 11191' 9-5/8" 11191' 8677' 6870 4760 Production Liner 1033' 7" 10887' - 11920' 8465' - 9210' 8160 7020 ~~L~~~~ ~~~~ ~~' ~ ~~~ Perforation Depth MD (ft): 11392' - 11689' Perforation Depth TVD (ft): 8822' - 9040' 5-1/2", 17# x 4-1/2", 12.6# L-80 10914' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" Baker S-3 Packer 10685' ~ 9-5/8" x 4-1/2" AVA PPH Perm Packer 10796' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 20 24 Subsequent to operation: 0 0 4221 140 184 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ^ Development ®Service ® Daily Report of Well Operations 16. Well Status after work: ® WeIlSchematicDiagram ^ Oil ^ Gas ®WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 308-343 Printed Name Sondra Stewman Title Drilling Technologist Sign ure ~/ Prepared By Name/Number: Phone 564-5743 Date ~ r~ ° ~~~b Sondra Stewman, 564-4750 Form 10-404 Revised 04/2006 Submit Original Only err ~... ~ C i ~, ~ ~'~ ~ ~ .~ _ ~ .. ~._~rt ~~~~~: 20D~ , TREE = FMC GEN 3 WELLHEAD = CALICO FMGMCEVOY ACTUATOR = AXELSON KB. ELEV = _ 7T BF. ELEV = KOP = 2800' Max Angle = 51 @ 7200' Datum MD = 11467 Datum TV D = 8800' SS ~ 12 -19 ~ ~T~~:~*3-1 /2" C~R®M~TB~*~~77~ L F 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2430' Minimum ID = 2.75" @ 11632' 3-112" Parker SWN Nipple 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 10. TOP OF 7" LNR I--I 1 2106" ~-~ 5-112" X NIPPLE; ID = 4.562" '10653' - -~5-112" X NIPPLE, ID =4.562„ 10685" 9-5,'8" X 5-112" BAKER S-3 PKR, 10749' S-1I2" X NIPPLE, ID = 4.562°' 10760" 5-1,`2" X 8.210" UNIQUE OV ERSHOT 10793' 10796' 5-1/2" X 4-1/2" XO, ID = 4.892" 9-5/8" X 4-1/2" AVA PPH HYDRAULIC SET PERM PKR 10907' -~ 4-1/2" PKR SWN PROFILE NIP, ID = 3.725" 4-1/2" TBG-IPC, 12.6#, L-80, 10914' .0152 bpf, ID = 3.958" 10914' 4-1/2" TUBING TAIL, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 11191' 10904' ELMD TT LOGGED 04/19/92 11459' TOP OF CEMENT (07/26/06) 11528' TOP OF SAND (07/26/06) 11620' 7" X 5-1 /2" OTIS B W D PKR 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" ~-~ 11624' 3-1/2" TBG, 9.2#, 13-C R, .0087 bpf, ID = 2.992" ~-~ 11633' PERFORATION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP PERF: 43 @ 11328' Note: Refer to Production DB for historical pert data j SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATION DATA PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" TD 1~ 1877' u 11920' 11624' -15-1 /2" X 3-1 /2" XO, ID = 2.992" 11632' -{3-1/2" PKR SWN NIP, ID = 2.75" 11633' 3-1/2" TUBING TAIL, ID = 2.992" 11632' ELMD TT LOGGED ON 02/11/93 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/82 ORIGINAL COMPLETION 12/14/91 RWO 11/20/08 D16 RWO 11/21/08 PJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNff WELL: 12-19 PERMIT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) ~ 12-19 ~ PERFORATION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP PERF: 43 @ 11328' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 11326 - 11346 S 05/12/88 3-1/8" 4 11350- 11430 S 05/12/88 3-3/8" 6 11391 - 11411 S 12/91 3-3/8" 4 11392 - 11452 C 04/19/92 3-3/8" 6 11411 - 11451 S 05!12/88 3-3/8" 4 11465 - 11505 C 04/19/92 3-1/8" 11564 - 11584 S 05/12/88 3-3/8" 4 11589- 11597 C 02/11/93 3-3/8" 4 11601 - 11619 C 02/11/93 2-1/8" 6 11638 - 11648 C 02/11/93 2-1/8" 8 11649 - 11689 C 08/07/92 3-3/8" 6 11683 - 11687 S 05/12/88 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/82 ORIGINAL COMPLETION 12/14/91 RWO 11/20/08 D16 RWO 11/21/08 PJC DRLGDRAFTCORRECTIONS PRUDHOE BAY UNff WELL: 12-19 PERMfT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) Page 1 flf 2 • • Well: 12-19 Well History Well Date Summary 12-19 9/18/2008 ***WELL S/I ON ARRIVAL*** PULLED PRONG FROM 10,909' SLM PULLED 4 1/2 PXN PLUG BODY FROM XN-NIP @ 10,907' MD, ***CONTINUED ON WSR 09/19/08*** 12-19 9/19/2008 ***CONTINUED FROM WSR 09/18/08*** SET 4 1/2 HES FASDRIL PLUG (3.66" OD, 28.92" OAL) @ 10,843' MD TAGGED 4 1/2" XO C~ 10,796' SLM W/ 4.500" GAUGE RING DRIFT W/ 4.50" CENT TO 4 1/2" XO C~ 10796' SLM ***WELL LEFT S/I, DSO NOTIFIED*** 12-19 9/20/2008 T/I/O = 30NAC/0+. Temp = SI. T & IA FLs (FB). T FL ~ 348' (9 bbl). IA FL @ 45' (2 bbl). SV, WV, MI inj. shut. SSV, MV open. IA & OA otg. 12-19 9/21/2008 T/I/0=0/0/40 Temp =SI CMIT-TxIA PASSED to 4000 psi (RWO Prep) Pumped a total of 42 bbls dissel down Tbg and 7.5 bbls own o ring o es pressure. n r test T/IA lost 0/0 psi in 30 mins. Bled T/IAP's. FWHP's=40/20/80 Tags hung and wellhead valves checked for position upon departure. 12-19 10/9/2008 ***WELL SI UPON ARRIVAL*** (E-LINE JETCUT TUBING). INITIAL T/IA/OA: 0/0/0. RIH WITH 4.15" MAX OD JET CUTTER, AND 4.75" GEMCO CENTRALIZERS. ATTEMPTED TO FIRE CUTTER, BUT HAD A MISSRUN, POOH TO INVESTIGATE THE PROBLEM. ****JOB CONTINUED ON 14-OCT- 2008**** 12-19 10/9/2008 ***WELL SI UPON ARRIVAL*** (E-LINE JETCUT TUBING). INITIAL T/IA/OA: 0/0/0. RIH WITH 4.15" MAX OD JET CUTTER, AND 4.75" GEMCO CENTRALIZERS. ATTEMPTED TO FIRE CUTTER, BUT HAD A MISSRUN, POOH TO INVESTIGATE THE PROBLEM. ****JOB CONTINUED ON 14-OCT- 2008**** 12-19 10/13/2008 ***PRE RWO E-LINE JET CUT*** WELL SI UPON ARRIVAL. INITIAL T/IA/OA: 0/0/0. RIH WITH 4.15" MAX OD JET CUTTER, AND 4.75" GEMCO CENTRALIZERS. ATTEMPTED TO FIRE CUTTER, BUT HAD A MISSRUN, POOH TO INVESTIGATE THE PROBLEM. ***JOB CONTINUED ON 14-OCT-2008*** 12-19 10/14/2008 ***JOB CONTINUED FROM 13-OCT-2008*** T/IA/OA: 0/0/0. RIH AGAIN WITH 4.15" JET CUTTER AND 4.75" GEMCO CENTRALIZERS. UT 5-1/2" T FINAL T/IA/OA: 0/0/0. DSO NOTIFIED OF VALVE POSITIONS ON DEPARTURE. WELL LEFT SHUT-IN ***JOB COMPLETE*** 12-19 10/16/2008 T/I/0=80/0/0 temp=s/i Circ. Out/CMIT TxIA to 1000 psi (RWO Prep) Pumped 10 bbls neat meth spear & 1115 bbls 1 % KCL down TBG, up IA & down hardline jumped #18 F/L. Pumped 152 bbls DSL down TBG & U-tubed to IA for Freeze Protect. Pumped 5 bbl neat meth spear, 130 bbls crude & 8 bbls DSL to F/P well #18 F/L & hardline jumper from well #19 to #18. ****Continued on 10-17-08 WSR**** 12-19 10/17/2008 *"*Continued from 10-16-08 WSR**** Circ Out/CMIT-TxIA PASSED to 1000 psi (RWO Pry Pumped 3.3 bbls DSL down IA to bring to test pressure. On 3rd test, T/IA lost 20T20 psi~0 psi.~ass. Bled WHP. FWHP's=0/0/0 ***Tags hung. Casing valves open to gauges**** 12-19 10/21/2008 T/I/0=0/0/0. Set 5" FMC IS-A BPV. Pre Rig. 12-19 11/14/2008 T/I/0=0/0/0. Pull 5" FMC IS-A BPV. Doyon 16 on well. 12-19 11/14/2008 T/I/0=0/0/0. Pull 5" FMC IS-A BPV thru BOPE after rig testi. 12-19 11/14/2008 T/IA/OA= BPV/0/0 Temp=hot Free (4) stuck LDS Arrived location, Rig was finishing circulation well. FMC set 4" ISA. RU 1 HP BT onto THA 0 psi in void, (4) LDS were marked with flagging tape from past pre rig, rig rep reported kroil was sprayed onto gland nuts through out night. All LDS were cycled and left in the out position, tightened all G/N we had cycled. 12-19 11/20/2008 T/I/0=0/0/0. Pull 6" CIW J TWC thru BOPE.(would not hold). Set 6" CIW J TWC with T-Bar. Tested good. 12-19 11/22/2008 T/I/0=0/0/0. Pull 6" CIW J TWC thru tree. Post Doyon 16. 12-19 11/23/2008 ***WELL S/I ON ARRIVAL*** (post rwo) R/U SLICKLINE UNIT 4516 (SHIPPING CAP ON SSV) STBY ON VALVE CREW TO PLUMB IN TO SSV ***CONTINUE WSR ON 11-24-08*** 12-19 11/24/2008 ***CONTINUED WSR FROM 11-24-08*** (post RWO) PULL B&R FROM RHC-M PUG BODY ~ 10.741' SLM PULL 5-1/2" RHC-M PLUG BODY FROM X-NIP C~ 10 744' SLM &T W 3.50" CENT, TEL, S.BAILER, LOC TT @ 10,906' SLM (- 2' CORK= 10,904' ELMD) TAG STICKY BTM @ 11,450' SLM (- 2' CORK = 11,448' ELMD) Page 2 of 2 '"'WELL S/I ON D~iTURE, DSO NOTIFIED OF ALL CONDITIONS' 12-19 12-19 12-19 11/26/2008 T/I/0=0/0/0. SI. IA FL (pre AOGCC MIT-IA). IA FL near surface. No IA integral flange. SV,WV=closed. SSV,MV=open. IA & OA OTG. 12/3/2008 T/I/O = 10/40/VAC. Temp = SI. Monitor WHPs, check for IA Integral. No integral on IA. SV, WV =Closed. SSV, MV =Open. IA & OA = OTG. NOVP. 12/5/2008 T/I/O = 250/0/0 Temp =Hot MIT IA PASSED to 4000 psi (Pre AOGCC) Pumped 10.1 bbls meth to pressure up. IA lost 40 psi 1 sf 15 mins and 20 psi 2nd 15 mins for a total loss of 60 psi in 30 mins Bled to zero. FWHP's = 250/0/0 Swab =shut, Master =open, SSV =open, Wing =open, IA =open and tagged, OA =open. 12-19 12/6/2008 T/I/0= 450/40NAC. Temp= Hot. (PASSED) AOGCC MIT-IA w/ FB to 4000 psi. Pressured IAP to 4000 psi. Total loss of 0 psi. LRS in control of the valves. 12-19 12/6/2008 T/I/0=450/40/vac Temp=Hot/aOGCC MIT IA PASSED to 4000 psi (AOGCC Witnessed by J.Crisp) Pressured up IA with 5 bbls~ met~fAlost ~i in s mins awn 'd psi m ~T5 mins or o a pressure loss of 20 psi in 30 mins. Bled IA (-5 bbls). Final WHP's=450/100/0. Verify casing valves open & tagged. Valve positions are as follows: Swab-open, wing-open, master-open, SSV-open, IA/OA-open to gauges. Print Date: 12/16/2008 Page 1 of 1 • • BP EXPLORATION Operations Summary Report Page 1 of 6 ~ Legal Well Name: 12-19 Common Well Name: 12-19 Spud Date: 11/30/1982 Event Name: WORKOVER Start: 11/11/2008 End: 11/20/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/20/2008 Rig Name: DOYON 16 Rig Number: Date From - To li Hours Task I Code NPT Phase ~'~, Description of Operations _ I 11/9/2008 16:00 - 17:30 1.50 MOB P 17:30 - 00:00 6.50 MOB P 111/10/2008 100:00 - 12:00 I 12.001 MOB I P 12:00 - 00:00 I 12.001 MOB I P 111/11/2008 (00:00 - 12:00 I 12.001 MOB f P 12:00 - 00:00 I 12.001 MOB I P 11/12/2008 100:00 - 01:30 1.50 ~ MOB P 01:30 - 02:00 I 0.501 MOB I P 02:00 - 12:00 10.00 MOB P 12:00 - 00:00 12.00 MOB P 11/13/2008 ~ 00:00 - 12:00 12.00 ~ MOB I P 12:00 - 21:00 I 9.00 I MOB I P PRE PJSM. Back Rig off of 12-21. Remove BOP stack from cellar and place on transport cradle. PRE Spot Rig in center of pad to wait on 7ES move and Pad Prep to be completed on 12-19. Perform general maintenance and housekeeping around Rig. Prep mezzanine for painting. Clean up all equipment, rig mats and herculite from around 12-21. PRE Wait on 7ES to move and Pad Prep. Perform general housekeeping, maintenance and painting throughout Rig. Finish prepping Mezzanine for painting and begin painting same. PRE Wait on 7ES to move and Pad Prep. Finish painting Mezzanine and continue painting throughout Rig. General maintenance and housekeeping throughout Rig. Install hydraulic lines for new booster wheels in wheel room. PRE Wait on 7ES move & Pad Prep. General housekeeping, maintenance and painting throughout Rig. Welder making repairs in pits. PRE Wait on 7ES move & Pad Prep. General housekeeping, maintenance and painting throughout Rig. 7ES moves off location at 1800-hrs. CH2MHill crew begins removing wellhouse and lines at 1900-hrs. PRE Wait on Pad Prep. RD all equipment for laying the derrick over. Prepare to move rig to west side of DS 12. CH2MHill crew is rigging down all lines and scaffolding on the tree. PRE PJSM on moving the rig. Jack rig up and move around DS to west side. Stage rig just north of well 12-19. PRE Wait on Pad Prep. General maintenance, housekeeping and painting throughout rig. At 0230-hrs, dirt hauling begins. CH2MHill crew continues rigging down scaffolding on the tree. At 0400-hrs, move mud pump and generator modules from DS 4 to DS 12. Replace oil line and compression sleeve on Cat engine #3. Weld riser leak between Pits 3 and 4. Install worm gear drive in Pit module. PRE Wait on pad build-up. Roads and Pads still hauling material from DS12-25 to DS12-19i as of 1600-hours. The grading crew arrived at 2000-hrs and began by moving large pile of gravel staged in front of the well before beginning to grade the pad. Continue painting projects around the rig. Set BOP stack on cellar pedestal. Change all filters in hydraulic system. PRE Wait on Pad Prep. At 0030-hrs, Grading crew is finished leveling the gravel that was staged on the pad near the well and begins hauling gravel from 12-19 to bring gravel to final grade. At 0400-hrs, Tool Service makes first survey shot of location and find grade is low on East side. Build East edge of gravel up to match grade at well. General housekeeping, painting and maintenance throughout rig. PRE Continue to Wait on Pad Prep. Continue general housekeeping, maintenance and painting throughout rig, Begin soaking "stuck" LDSs hourly in preparation for backing them out. Work on new pit module. At 1800-hrs, Lay Herculite and set rig mats on 12-19. Roads and Pads finish building ramp onto 12-19 pad, removing gravel pad left from 7ES to clear right-of-way for the rig to move and widening south side of Printed: 12/8/2008 12:20:06 PM i • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: 12-19 Common Well Name: 12-19 Event Name: WORKOVER Contractor Name: DOYON DRILLING INC. Rig Name: DOYON 16 Date From - To ~ Hours Task Code I Start: 11 /11 /2008 Rig Release: 11/20/2008 Rig Number: Spud Date: 11 /30/1982 End: 11 /20/2008 11/13/2008 12:00 - 21:00 9.00 MOB P 21:00 - 23:00 2.00 MOB P 23:00 - 23:30 0.50 MOB P 23:30 - 00:00 0.50 MOB P 11/14/2008 00:00 - 01:30 1.50 MOB P 01:30 - 02:30 I 1.001 DHB I P 02:30 - 03:00 0.50 CLEAN P 03:00 - 07:30 4.50 CLEAN P 07:30 - 08:30 1.00 CLEAN P 08:30 - 09:30 1.00 WHSUR P 09:30 - 10:30 1.00 WHSUR P 10:30 - 11:00 0.50 WHSUR P 11:00 - 14:00 3.00 BOPSU P 14:00 - 19:00 5.00 BOPSU P 19:00 - 19:30 0.50 BOPSU P 19:30 - 21:00 1.50 DHB P 21:00 - 23:00 2.00 PULL P 23:00 - 00:00 1.001 PULL P NPT i Phase Description of Operations PRE 12-19 to allow room for Mud Pump #2 module. PRE PJSM on moving Rig. Jack up, move and spot Rig on 12-19. PRE Build small pad for slop tank and spot slop tank on ODS. PRE Begin RU to circulate on mainfold in cellar. PRE RU double annulus valves, all circulating lines and cellar manifold. Spot Mud Pump and 3516 motor modules. DECOMP PU DSM lebricator and mess ~r t ct to 500-nci -Good t2ct. Pull ISA BPV. No pressure underneath plug. LD DSM lubricator and BPV. DECOMP PJSM with Rig Crew and CH2MHill truck drivers on displacing diesel freeze protection and wellbore fluid. Assign positions to hands and discuss hazards of moving fluids. DECOMP Pressure test all lines to 3500-psi -Good test. Pump 20-bbl Hi Vis sweep and chase out of hole at 7-BPM with 880-psi. Slow down circulation while swapping out trucks of seawater. Dirty returns at calculated bottoms up and a good slug of diesel just ahead of sweep indicating that we are circulating through the jet cut. Circulated a 2nd full wellbore volume across the shakers and saw no gas or oil in the returns. Stop circulating and monitor well for 30-minutes. Well is dead. DECOMP R/D circulating lines. P/U BPV and FMC dry rod into hanger. Test BPV to 1000- si from below for strai ht lin . DECOMP FMC and Cameron personnel use wrenches to break loose the 4 stuck LDSs. The Gland Nuts on the LDSs had seized, but the repeated application of Aero-Kroll to the LDSs and Gland Nuts as well as the heated spool served to help break the LDSs and Gland Nuts free. Function the LDSs in and out with the impact wrench. DECOMP N/D tree and adaptor flange. Called AOGCC at 0930 to give update re the upcoming BOPE test. Jeff Jones returned call at 0940-hours and waived State's right to witness the BOPE test. DECOMP Clean top of tubing head. lanstall blanking plug in hanger for 10 right-hand turns. Verify blankin lu ullin threads at 8-1 left-hand turns DECOMP N/U BOP stack and equipment. Fill BOP stack and function test BOPE. DECOMP Test ROPE 250- si low and 4000- si hi h. Test 3-1/2" x 6" VBRs with 4" and 5-1/2" test joints. Test annular preventer to 250-psi low and 3500-psi high with 4" test joint only. Hold and Chart all tests for 5-minutes. BP WSL and Doyon Toolpusher witness all tests. DECOMP RD BOP test equipment and blow down all lines. Pull Blanking plug. DECOMP RU Dutch Riser system. PU DSM Lubricator and pressure test to 500-psi -Good test. Bleed pressure off of IA from testing; Pull BPV. LD Lubricator, BPV, and Dutch Riser system. DECOMP Safety Stand-down with both Rig Crews, both BP WSLs, both Doyon Toolpushers, and WSLf to discuss recent incidents on other rigs. Discussed hand injuries within ADW and also across the slope. Also discussed "How we forget what we are doing" and "How do we get back in focus" with participation from every individual in the meeting. DECOMP MU XO for tubing hanger to jt of 4" DP. RIH and screw into Printed: 12/8/2008 12:20:06 PM • • BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 12-19 Common Well Name: 12-19 Spud Date: 11/30/1982 Event Name: WORKOVER Start: 11/11/2008 End: 11/20/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/20/2008 Rig Name: DOYON 16 Rig Number: Date From - To ~~, Hours Task Code NPT .Phase Description of Operations _ __ 11/14/2008 23:00 - 00:00 1.00 PULL P DECOMP _ _ _ hanger with 10 right hand turns. FMC tech attempt to BOLDS. Suck out stack. 11/15/2008 00:00 - 05:00 5.00 WHSUR P DECOMP FMC tech unable to back out 2-LDSs. In both cases, the Gland nuts were fused to LDS and entire assembly had to be removed. Both LDS /Gland nut assemblies were replaced. One hole required tapping prior to installing new assembly. RU to LD 5-1/2" 17# L-80 while working on LDSs in cellar. Change out seal on 5-3/4" RH Acme tubing hanger XO after replacing LDS. Continue to BOLDS. 05:00 - 05:30 0.50 PULL P DECOMP Pull Tubing hanger to Rig Floor. Hanger came free at 175,000-Ibs. String weight was 200,000-Ibs. 05:30 - 07:00 1.50 PULL P DECOMP CBU at 8-BPM with 210-psi. See nothing but clean seawater over the Shakers during the circulation. 07:00 - 08:00 1.00 PULL P DECOMP PJSM to R/U to pull and UD tubing and spool control lines. B/O and UD hanger, crossovers, and landing joint. R/U control fine spooler. M/U XO to floor safety valve. 08:00 - 10:00 2.00 PULL P DECOMP POOH and UD 5-1/2" LTC 8-rd tubin .Control line hanging up periodically, but a slow slack-off releases the line each time to enable continuing POOH with the tubing. 10:00 - 13:00 3.00 PULL P DECOMP Safety Stand-down. See details in "Remarks" tab. 13:00 - 21:00 8.00 PULL P DECOMP Resume POH and UD 5-1/2" LTC 8Rd tubing. The tubing will not be salvaged according to Stores. 51 of 56 SS control line bands were recovered while spooling control lines. 90-joints out at 1540-hours. 132-joints at 1700-hours. Recovered 246-jts of 5-1/2" 17# L-80 Tubing, 1-SSSV assembly, and 1-cut jt of 5-1/2" Tubing. Cut jt was 21.81' in length and cut was flared to 6.5". 21:00 - 21:30 0.50 PULL P DECOMP Clean and clear rig floor. RD all 5-1/2" Tubing handling equipment. Drain BOP stack and function rams looking for SS bands not recovered while spooling control lines. No more SS bands recovered. Install wear ring. 21:30 - 22:00 0.50 PULL P DECOMP Bring all Dress-off BHA components to rig floor and steam same. 22:00 - 23:30 1.50 CLEAN P DECOMP MU Dress-off BHA. BHA consists of: Dress-off shoe, Wash Pipe Extension, Internal Dress-off Mill, Boot Basket, Double Pin Sub, 9-5/8" Casing Scraper, Bit Sub, Bumper Sub, Oil Jar, XO and 6(ea) 4-3/4" DCs. Total BHA length = 235.99'. 23:30 - 00:00 0.50 CLEAN P DECOMP RIH with Dress-off BHA on 4" DP from 235' to 710'. PU 4" DP from pipe shed. 11/16/2008 00:00 - 07:30 7.50 CLEAN P DECOMP PU 4" DP from Pipe Shed &RIH with Dress-off BHA. 135-jts run at 0230-hrs. 230-jts RIH at 0500-hrs. 280-jts ~ 0600-hours. Tag stub at 10,760', 26' in on DP joint #333. 07:30 - 08:30 1.00 CLEAN P DECOMP PJSM. Get parameters: 202K-Ibs Up wt, 135K-Ibs Down wt, start rotating at 40-RPM with free torque at 9K-Ib-ft, 7-BPM at 1090-psi. Slowly lower over stub and maintain -2K-Ibs WOB, torque at 10-11 K-Ib-ft. Control mill-off and extension slides down over stub until inner mill contacts stub. Mill off -6" and stop rotating to P/U and lower back down over the stub. P/U to pump sweep all the way around. 08:30 - 10:00 1.50 CLEAN P DECOMP Pump 20-Bbl Hi-Vis sweep, 8.5-BPM, 1460-psi for 740-Bbls. See small bits of scale, sand, and metal across Shakers. Also see a -2-gallon "glob of black stuff" come across the Shakers, probably schmoo. Sweep came back exactly when calculated, Printed: 12/8/2008 12:20:06 PM • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 12-19 Common Well Name: 12-19 Spud Date: 11/30/1982 Event Name: WORKOVER Start: 11/11/2008 End: 11/20/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/20/2008 Rig Name: DOYON 16 Rig Number: Date 'From - To Hours ~ Task ~ Code NPT Phase Description of Operations 11/16/2008 08:30 - 10:00 1.50 CLEAN P DECOMP followed by clean seawater. There were no losses to the wellbore. 10:00 - 14:00 4.00 CLEAN P DECOMP POH and S/B DP in Derrick. B/O and UD 4-3/4" DCs. Loading Pipe Shed with 5-1/2" TCII tubing for thread cleaning and inspection. 30-stands POH at 1140-hours. 70-stands at 1245-hours. 14:00 - 15:00 1.00 CLEAN P DECOMP B/O and UD DCs. B/O and UD BHA. Empty Boot Basket and get 1/2 of a SS band and 1-1/2-Ibs of debris. Clear and clean Rig Floor. 15:00 - 17:00 2.00 CLEAN P DECOMP PJSM. M/U FasDrill Plug Drill-out BHA: Cut-lip guide, Wash Pipe Extension, Triple Connection Bushing, 3-bladed Junk Mill and RIH on 6-joints of 2-7/8" PAC DP. 17:00 - 20:00 3.00 CLEAN P DECOMP RIH with FasDrill Plug Drill-out BHA from 197' to 10,537' on 4" DP from derrick. 20:00 - 21:00 1.00 WHSUR P DECOMP PU Storm Packer and MU to DP. Obtain parameters: PU wt = 197K-Ibs, SO wt = 132K-Ibs. RIH and set Storm Packer 101' below rotary table. Test Storm Packer to 1500-psi for 10-charted minut .Good test. 21:00 - 23:00 2.00 WHSUR P DECOMP Vac out BOP stack. Pull Wear ring. MU FMC pack-off pulling tool to 1-jt of 4" DP. BOLDS on casing spool. Pull 9-5/ " Pack-off through BOP stack. Pack-off came free at 50K-Ibs. Install new pack-off per FMC tech. RILDS. Blow down Kill and Choke lines and prepare to ND BOP stack while RILDS. 23:00 - 23:30 0.50 WHSUR P DECOMP ND BOP stack. Remove one of the annulus valves on new tubing spool. Install VR plug and tapped blind flange in place of valve. Mechanical Barriers for ND are 1) Tested Storm Packer and 2) Tested FasDrill plug at 10,843'. 23:30 - 00:00 0.50 WHSUR P DECOMP Place BOP stack on cellar pedestal. ND tubing spool and remove from cellar. 11/17/2008 00:00 - 02:30 2.50 WHSUR P DECOMP Clean off top of casing spool and in ring gasket groove. Install ring gasket and upper seals on 9-5/8" Pack-off. NU new tubing s ool. Continue to clean and inspect 5-1/2" TC-II tubing connections with Unique Machine thread specialist. 02:30 - 03:00 0.50 WHSUR P DECOMP FMC rep test new 9-5/8" Pack-off to 5000-psi for 30-minutes. Good Test. 03:00 - 08:00 5.00 BOPSU P DECOMP NU BOP stack. Set test plug. RU and test BOP break to 250-psi low pressure and 4000-psi high pressure. Hold and chart each test for 5-minutes. Good, solid tests. 08:00 - 08:30 0.50 CLEAN P DECOMP P/U RTTS/Storm Valve Run/Pull tool and RIH to release RTTS/Storm Valve and POH and UD. 08:30 - 10:00 1.50 CLEAN P DECOMP Slip and Cut 92' of drilling line. 10:00 - 19:00 9.00 CLEAN P DECOMP Clean and inspect all threads on 5-1/2" 17# L80 TC-II Tubing. Unique Machine thread specialist inspects all threads. Tally tubing. 19:00 - 20:30 1.50 CLEAN P DECOMP Obtain milling parameters: PU wt = 200K-Ibs, SO wt = 132K-Ibs, Rot wt = 152K-Ibs. Rotate at 40-rpm with 6K-Ibs/ft of free torque. Pumping at 6-BPM with 1050-psi. RIH and locate 5-1/2" tubin stub at 10 760'. Set down 15K-Ibs and observe shear of shear pin guide assembly. Continue RIH and tag top of fill at 10,813'. Torque increases to 8K-Ibs/ft while cleaning out fill. Clean out fill down to top of FasDrill pluo at 10.844' (31' of fill . Control mill FasDrill plug per Baker fisherman with 3K-Ibs weight on bit and 45 to 60-RPM with 10K-Ibs/ft of Printed: 12/8/2008 12:20:06 PM • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 12-19 Common Well Name: 12-19 Spud Date: 11/30/1982 Event Name: WORKOVER Start: 11/11/2008 End: 11/20/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/20/2008 Rig Name: DOYON 16 Rig Number: D t T T NPT Ph F H d e ~ D i f O k C i i a e rom - o ~ ours as o e escr pt on o perat ons as 11/17/2008 19:00 - 20:30 1.50 CLEAN P DECOMP torque. _Begin observing losses of 124-BPH at 2020-hrs. Mill through plug at 2030-hrs.. 20:30 - 21:00 0.50 CLEAN P DECOMP Continue to RIH with same milling parameters and push plug out of bottom of tailpipe assembly at 10,914'. Final de th reached b mill is 10 94 ' Static loss rate = 156-BPH. 21:00 - 00:00 3.00 CLEAN P DECOMP Pull Mill back into tubing tail. Turn pumps on at 7-BPM with 1700-psi. Circulate 1-1/2 times calculated bottoms up to account for~rnamic loss rate of 176-BPH. See fingernail sized Schmoo wads while circulating. Finish cleaning, inspecting and strapping 5-1/2" 17# L80 TC-II tubing with Unique Machine thread specialist. 11/18/2008 00:00 - 08:30 8.50 CLEAN P DECOMP Monitor well - On a vac. Obtain static loss rate of 120-BPH. POH w/milling BHA from 10,910'. LD DP to pipe shed. Monitor well after pulling out of 5-1/2" tubing stub -still on a vac. Keep well full by filling_ through the kill line using the_ char a um at 120-BPH. 30-jts out at 0100-hrs. 200-jts out at 0500-hrs. 300-jts C~ 0720-hrs. 08:30 - 10:00 1.50 CLEAN P DECOMP B/O and L/D 2-7/8 PAC DP and Mill. 10:00 - 11:30 1.50 BUNCO RUNCMP Clear and clean rig floor. 11:30 - 12:30 1.00 BUNCO RUNCMP R/U 5-1/2" tubing handling equipment. R/U Doyon Casing torque turn equipment and check computer connections. 12:30 - 13:00 0.50 BUNCO RUNCMP PJSM---discuss the Hazard Hunt Lists with respect to the completion running operation. Hold PJSM for the operation. 13:00 - 18:00 5.00 BUNCO RUNCMP RIH with 5-1/2", 17#, L-80, TCII tubing. Torque all connections to 4350-Ib-ft, using Jet Lube Seal Guard pipe dope. RIH with Unique Machine Overshot, X-nipple, one full joint, the Baker packer, X-nipple and 12 full joints using dog collar at 1415-hours with no threading problems. 30 full-joints RIH at 1500-hours. Water loss using constant hole-fill is 100-BPH. 18:00 - 00:00 6.00 BUNCO RUNCMP -3,200 -ft RIH. Continue running 5 1/2" TCII completion. Fluid loss now at 90 bbls/hr. Have -7400-ft RIH at midnight. 11/19/2008 00:00 - 04:30 4.50 BUNCO RUNCMP Continue to picking up 5 1/2" Completion from -7,400 -ft. 04:30 - 07:00 2.50 BUNCO RUNCMP Pick-up weight = 202K. SOW = 145K. Pick up Joint #261 and 262 to tag top of 5 1/2" tubing sump at 10,760'dpm. Did not see Mule Shoe sli over stum Saw first set of shear pins with 30' in, saw second set of shear pins with 38' in, saw no-go with a total of 40' in. Stacked out on No-Go with 15k down. Pick-up 8' and re-tag No-Go at same spot. Lay down Jt # 262, 261, and 260. Pick-up 8,5' Pup Joint and Joint 260. Make up Tubing Hanger Assembly. (When tubing is landed, tubing will be spaced out 3' off of No-Go). 07:00 - 07:30 0.50 BUNCO RUNCMP Land Tubing Hanger and RILDS. 07:30 - 13:30 6.00 BUNCO RUNCMP PJSM with CH2MHill truck drivers, Lil Red crew, rig crew, Baker Completions Tech, Toolpusher and WSL to discuss Packer fluid and diesel freeze protect circulation. Also covered pinch points and Spill Prevention methods. PT lines to 3500-psi for seawater circulation. Reverse circulate 290-Bbls of 120E seawater, then 580-Bbls 120E seawater mixed with EC1124A Corrosion Inhibitor at 3-BPM and 300-psi. 13:30 - 15:30 2.00 BUNCO RUNCMP Pressure test Lil Red lines to 4000-psi. Reverse circulate 100-Bbls of diesel freeze protect fluid at 1.9-BPM at 450-psi. 15:30 - 16:00 0.50 BUNCO RUNCMP R/U to circulate 55-Bbls down the tubing for freeze protecting the tubing at 1.4-BPM and 450-psi. Printed: 12/8/2008 12:20:06 PM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: 12-19 Common Well Name: 12-19 Spud Date: 11/30/1982 Event Name: WORKOVER Start: 11/11/2008 End: 11/20/2008 Contractor Name: DOYON DRILLING INC. Rig Release: 11/20/2008 Rig Name: DOYON 16 Rig Number: I Date I From - To Hours Task Code NPT Phase Description of Operations 11/19/2008 16:00 - 17:15 1.25 BUNCO RUNCMP Break off circulating line, drop ball and rod, reconnect circulating line and have Lil Red build pressure to set packer and test tubing. Build pressure to 3200-psi and a seal bleeds out on a swing in the cellar spraying -2-gallons of diesel on the rig mats. S/D Lil Red and use Absorb to clean up diesel. Call SRT and ADW RWO Superintendent. SRT returned call and said this is anon-recordable event. Bleed all diesel out of lines back to Lil Red. 17:15 - 18:00 0.75 BUNCO RUNCMP Resume setting packer and pressure testing tubing to 4000-psi with rig pump. Bring pressure up to 4100- si and it slowly bleeds to 3900-psi in 10-minutes. Find a bleedin Halliburton valve on the cementing manifold and S/D to change it out. 18:00 - 20:00 2.00 BUNCO RUNCMP Resume test. Pressure test Tubing at 4,000 psi x 30 minutes. Gopd test. Bleed tubing pressures down to 1,500 psi. Fill Annulus with 10 bbls and ressure u to 4 000 si. Pressure test Casing and Packer at 4,000 psi x 30 minutes. Good test. Bleed Casing down to 0 psi. ee own u mg to 0 psi. Lay down landing joint. Blow down lines. 20:00 - 00:00 4.00 WHSUR P RUNCMP Install TWCV. Made several attempts to get TWC to hold ressure. Call out DSM to ull lu Ri u Dutch S stem. Plck-up Lubricator and test. Pull TWCV. 11/20/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP Install second TWCV. Test TWCV at 3,500 psi. x 10 minutes. Good test. Blow down lines. Suck out stack. 01:30 - 04:30 3.00 BOPSU P RUNCMP Nipple down Dutch System. Nipple down BOP Stack and set back on stump. 04:30 - 08:30 4.00 WHSUR P RUNCMP Nipple up Adaptor Flange and Tree. 08:30 - 09:30 1.00 WHSUR P RUNCMP R/U to pressure test tree to 5000-psi. PT tree to 5000-psi and record for 30-minutes for straight-line test to 5000-psi. 09:30 - 10:30 1.00 WHSUR P RUNCMP Conduct Safety meeting in Dog-House with ADW RWO Superintendent to discuss the three DAFWC incidents of the last four days. The Rig Crew, two DSM crew, a Cameron Tech, the Tool Pusher and the WSL were in attendance. 10:30 - 12:00 1.50 WHSUR P RUNCMP R/D test equipment, disconnect Mud Pump #2 module and External Generator module. Pull cuttings tank away from rig. R/D and secure equipment inside rig for short move off well. Release rig at 1200-hours, 11/20-2008. Printed: 12/8/2008 72:20:06 PM MElVI®RANDUM Toy Jim Regg P.I. Su ervisor ' ^ ~' FROM: John Crisp Petroleum Inspector State ®f Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, December 15, 2008 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-19 PRUDHOE BAY UNIT 12-19 LJ • Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv ~~aj,C.' ~- Comm Well Name: PRUDHOE BAY UNIT 12-19 Insp Num: mitJCr081211055209 Rel Insp Num: API Well Number: 50-029-20870-00-00 Permit Number: 182-198-o Inspector Name: John Crisp Inspection Date: 12/6/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 12-19Type Inj. ~ w ~ TVD ~ 8328 ~ IA I 40 ~ 4020 ~ 3980 I 3980 ~ ~ P.T. 1821980 ':TypeTest SPT Test si ! i ~ p zoaz I OA ! o o o I o I Interval ~TAL ~ P/F P / Tubing ~ aso I aso j aso ! aso j j NOteS' 8.5 bbl's pumped for test due to high test pressure. No problems witnessed. Mor,d~ay, December 15, 2008 Page 1 of 1 • SARAH PALIN, GOVERNOR ~t Lf~LCli-7~ Oiil ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~SERQATIOI~T C011TA'IISSIOIIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration Alaska Inc. P4 Box 196612 ~tis~~~~~ S ~ ~ ~ ~ 2008 ~~ Anchorage, AK 99519-6612 ~~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 12-19 Sundry Number: 308-343 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this ZS day of September, 2008 Encl. STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSI N APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 08 p ,mil '~~~ 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Welt ^ Change Approved Program ®Pull Tubing ~ ^ Pertorate New Pool ^ Waiver ^ Other 2. Operator Name: BP Ex location (Alaska) Inc. 4. Current Well Class: ^ Development ^ Exploratory 5. Permit To Drill Number 182-198 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 ®Service , ^ Stratigraphic 6. API Number: 50-029-20870-00-00 " 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? ^ Yes ®No 8. Well Name and Number: PBU 12-19 - 9. Property Designation: ADL 028330 10. KB Elevation (ft): ~' ~ 11. Field /Pool(s): , Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): 11930' Total Depth TV_D_(ft : 1~a?/~ ~ Lam. Effective Depth MD (ft): 11459' Effective Depth TVD (ft): Plugs (measured): 10907 Junk (measured): None Perforation Depth MD (ft): Below Pluq: 11392' -11689' Perforation Depth TVD (ft): 8822' - 9040' Tubing Size: 5-1/2", 17# x 4-1/2", 12.6# Tubing Grade: L-80 Tubing MD (ft): 10914' Packers and SSSV Type: 9-5/8" x 41/2" AVA PPH Perm Packer Packers and SSSV MD (ft): 10796' 13. Attachments: ® Description Summary of Proposal ^ BOP Sketch ^ Detailed Operations Pro ram 14. Well Class after proposed work: ' ^ Exploratory ^ Development ®Service 15. Estimated Date for Commencin O rations: October 15, 2008 16. Well Status after proposed work: ^ Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: Commission Re resentative: ®WAG~ ^ GINJ ^ WINJ ^ WDSPL 18. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact Mackie Dentck. 564-5891 Printed Na avid Re Title Engineering Team Leader Prepared ay Marnelw,mber Signature ~~ Phone 564-5743 Date 9 Z3 og Terrie Hubble, 564at628 Commission tie Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness +~.~ ^ Plug Integrity '~OP Test ~Allechanical Integrity Test ^ Location Clearance ~~ SirC.~.. ~r l ~~ Other: `~©~~~'~~i ~d~ -'~y~ ` Subsequent Form Required: ~(~~ APPROVED BY ~ ~ZS! A roved B COMMISSIONER THE COMMISSION Date Form 10-403 Re~eddt56f006 Submit In Duplicate cA lV t t by GP,~y, 12-19i Rig Workover • Scope of Work: Expense RWO: Pull 5-'/z" completion, change out 9-5/8" casing packoff, run 5-'/z" L-80 tubing with Baker S-3 packer set at 10800' MD. MASP: 2395 psi Well Type: Ivishak Water Alternating Gas Injector Estimated Start Date: October 15th, 2008 Production Engineer: Bob Gerik Intervention Engineer: Mackie Derrick Pre-ri re work• S 1 Pull 4-1/2" PXN plug, set 4.5" composite bridge-plug at 10840', CMIT TxIA to 4000 psi, drift for 5.5" ~et cutter. E 2 Jet cut 5-'/z" L-80 tubing in middle of 1S full joint above packer. Cut depth = 10766'md reference 12/12/91 tubin tall F 3 Circ well to seawater with 2000' diesel freeze-protect. CMIT TxIA to 1000 psi to verify mechanical barrier. W 4 Check the tubing hanger and IC casing hanger lock down screws for free movement. Completely back out and check each lock down screw for breakage (check one at a time). PPPOT-T & IC.PPPOT-IC FAILED & PPPOT-T PASSED 08/18/08 O 5 Set a BPV in the tubin han er. O 6 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU workover rig. ND tree. NU and test BOPE pipe rams to 4000 psi. Test annular preventer to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Retrieve 5-'/2" tubing string down to the packer. 3. Changeout and test 9-5/8" packoffs 4. Run 5-'/z" L-80 tubing with Baker S-3 packer set at 10800' MD. 5. Displace the IA to packer fluid and set the packer. 6. Test tubing and IA to 4000 psi. Freeze protect to 2200' MD. 7. Set BPV. ND BOPE. NU and test tree. RDMO. TREE = FMC GEN 3 WELLHEAD = CALICO FMGMCEVOY ACTUATOR = AXELSON K . ELEV = 77' BF. ELEV = _ KOP = _____-_ 2800' Max Angle = 51 @ 7200' Datum MD = 11467' Datum TV D = 8800' SS 12 -19 S NOTES:**3-1 /2" CHROMETBG'* :. ~-:- ~ 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" i--i 2430' i--J ~ Minimum ID = 2.75" @ 11632' 3-1/2" Parker SWN Nipple 10793' 5-1/2" X 4-1l2" XO, ID = 4.892" 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 10793' 10796' 9-5/8" X 4-1l2" AVA PPH HYDRAULIC SET PERM PKR TOP OF 7" LNR 10887' 10907' 4-1/2" PXN PLUG (06/03/08) 10907' 4-1 /2" PKR SWN PROFILE NIP, ID = 3.725" 4-1/2" TBG-IPC, 12.6#, L-80, 10914' 10914' 4-1/2" TUBING TAIL,. ID = 3.958" .0152 bpf, ID = 3.958" 10904' ELMD TT LOGGED 04/19/92 9-5/8" CSG, 47#, L-80, ID = 8.681" 11191' 11459' TOP OF CEMENT (07/26/06) 11528' TOP OF SAND (07/26/06) 11620' 7" X 5-1/2" OTIS BWD PKR 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 11624' 11624' 5-1/2" X 3-1/2" XO, ID = 2.992" 11632' 3-1/2" PKR SWN NIP, ID = 2.75" 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" 11633' 11633' 3-1/2" TUBING TAIL, ID = 2.992" 11632' ELMD TT LOGGED ON 02/11/93 REF LOG: BHCS ON 12/07/82 ANGLE AT TOP PERF: 43 @ 11328' Note: Refer to Production DB for historical perf data SIZE ~ SPF ~ INTERVAL ~ Opn/Sqz ~ DATE ~ SEE PAGE 2 FOR PERFORATION DATA PBTD -~ 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" -C TD -fi 11 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/82 ORIGINAL COMPLETION 06/28/06 JGMIPAG PULLED PXN TTP / SFTY NOTE 12/14/91 LAST WORKOVfB2 07/26/06 RWUPAG TOPS OF CMT & SAND 01/03/02 RNITP CORRECTIONS 11/08/06 BGG/TLH PERF CORRECTIONS 09/26/05 JYJ/TLH ELM TT LOGGED (02/11/93) 08/20/07 RDW/PJC WANER SFTY NOTE DELETm 11/06/05 MOR/TLH PXN TTP SET (10/30/05) 06/23/08 KJB/SV SET PXN (06103/08) 01 /26/06 RPH/TLH WA N ER SAFETY NOTE PRUDHOE BAY UNff WELL: 12-19 PERMIT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) TREE = FMC; C1ETI WELLHEAD = CALICO FMGMCEVOY ACTUATOR = AXELSON KE3. ELEV = 77' BF. ELEV = KOP = 2800' Max Angle = 51 @ 7200' Datum MD = 11467' Datum TV D = 8800' SS ~ 12-19 Proposed RWO 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 243 Minimum ID = 2.75" @ 11632' 3-1 /2" Parker SWN Nipple 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" --r 1 TOP OF 7" LNR S NOTES:**3-1/2" CHROME TBG** 2100' )~ 5-1 /2" X NIPPLE, ID = 4.562" 10780' ~ 5-1/2" X NIPPLE, ID = 4.562" 10800' 9-5/8" X 5-1/2" BAKERS-3 PKR, 10860' 5-1/2" X NIPPLE, ID = 4.562" 10875' 5-1/2" X 9-5/8" UNIQUEOVERSHOT 10793' 10796' S-1/2" X 4-1 /2" XO, ID = 4.892" 9-5/8" X 4-1/2" AVA PPH HYDRAULIC SET PERM PKR 10907' ~4-1/2" PKR SWN PROFILE NIP, ID = 3.725" 4-1/2" TBG-IPC, 12.6#, L-80, 10914' .0152 bpf, ID = 3.958" 10914' 4-1/2" TUBING TAIL, ID = 3.958" 9-5/8" CSG, 47#, L-80, ID = 8.681" 11191' 10904' ELMD TT LOGGED 04/19/92 11459' --jTOPOFCEMEM(o7/26/06) 11528' TOP OF SAND (07/26/06) 11620' 7" X 5-1/2" OTIS BWD PKR 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" 11624' 11624' 5-1/2" X 3-1/2" XO, ID = 2.992" 11632' 3-1/2" PKR SWN NIP, ID = 2.75" 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" 11633' 11633' 3-1/2" TUBING TAIL, ID = 2.992" 11632' ELMD TT LOGGED ON 02/11 /93 PERFORATION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP PERF: 43 @ 11328' Note: Refer to Reduction DB for historical pert data SEE PAGE 2 FOR PERFORATION DATA PBTD 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" TD DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/82 ORIGINAL COMPLETION 06/28/06 JGM/PAG PULLED PXN TTP/ SFTY NOTE 12/14/91 LAST WORKOVFR 07/26/06 RWL/PAG TOPS OF CMT & SAND 01/03/02 RNITP CORRECTIONS 11/08/06 BGG/TLH PERF CORRECTIONS 09/26/05 JYJ/TLH ELM TT LOGGED (02/11/93) 08/20/07 RDW/PJC WAIVER SFTY NOTE DELETED 11/06/05 MOR/TLH PXN TTP SET (10/30/05) 06/23/08 KJB/SV SET PXN (06/03/08) 01/26/06 RPIi;TLH ~NANER SAFEfI' NOTE PRUDHOE BAY UNff WELL: 12-19 PERMIT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) . . Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Friday, September 14, 2007 10:04 AM To: Regg, James B (DOA) Cc: NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech Subject: RE: PBU Sundry/AA Cancellations \~'d:'\q~ Jim, Per our conversation, these wells are not being cancelled due to recent failure to pass an MITIA. We submitted the cancellation requests based on past diagnostics performed in the past that indicate these wells will not pass an MITIA. Our internal requirements mandate that we have tubing integrity to inject these wells, thus, the wells have been shut in and the AA/Sundry for the respective wells are being cancelled. Please call if you have any further questions or concerns. Thank you, Paul Austin for Anna Dube Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 SCANNED SEP 2 12007 .....:.1:...~_~. From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, September 13, 2007 5:32 PM To: NSU, ADW Well Integrity Engineer Subject: PBU SundryjM Cancellations I am working on cancellation requests for PBU wells 12-19, 12-21, W-42 and do not find the following in our files: PBU 12-21: MIT-IA (fail) performed 3/8/2007 PBU 12-19: MIT-A (fail) date unknown I'd appreciate receiving copies of these MITs so our records are complete. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 9/14/2007 • _- _ _ SARAH PAL/P/, GOVERNOR ~v ~~TT~+ ~~11 ~~°~q ® ~~ ~~ 333 W. 7th AVENUE, SUITE 100 0.~®l~-7a<i~~~gll®d~ ~®1KM7L'+~''~®~ ANCHORAGE, ALASKA 99501-3539 s7 ~Y l~~i~ai~7 PHONE (907) 279-1433 FAX (907) 275-7542 CANCELLATION ADMINISTRATIVE APPROVAL w0. AIO 40.013 ~'Ir. Steve Rossberg, Wells Manager ~ ~~~ Attention: V~'ell Integrity Engineer, PRB-24 `~, BP Exploration (Alaska) Inc. ~~ P.O. Box 196612 ~k~~~ ,lAN ~ ~ 2~G~ Anchorage, AK 99~ 19-6612 RE: Cancellation of Administrative Approval AIO 040.013 (Well PBU 12-19) Dear ~~1r. Rossberg: Pursuant to BP Exploration (Alaska) Inc. ("BPXA"}'s request dated August 28, 2007 Alaska Oil and Gas Conservation Commission (-`Commission") hereby cancels Administrative Approval AIO 040.413, which allows continued water injection. This well exhibited tubing by inner annulus pressure communication, and BPXA did not at the time propose repairing the well to eliminate the problem. The Commission determined that water injection could safely continue in the well, but subject to a number of restrictive conditions set out in the administrative approval. Since then, BPXA has shut in the well following a failed mechanical integrity test. BPXA states it does not intend to operate Well 12-19 without passing a mechanical integrity test of the inner annulus. Consequently, Administrative Approval AIO 040.013 no longer appties to operation of this well. Instead, injection in well PBU 12-19 will be governed by provisions of the underlying AIO No. 4E which supersedes and replaces AIO 4C. DONE at Anchorage, Alaska and dated September 14, 2007. Cv ~ ~~ ~, ... + ; The Alaska Oil and Gas Conservation Commission I~ % ~ r ~~~ Daniel T. S amount, Jr. Commissioner ~~-~~ ~~~ Y Cathy P Foerster Commissioner • t=RAMK H. A9URKOWSKI, GOVERNOR 333 W. 7`" AVENUE, SU17E 700 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 AI)vIINISTRATIV~ APPR®VAL AI® -tC'.013 tilr. Steve Rossberg, Weils Manager BP Exploration (Alaska) Inc. 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBtr 12-19 (PTD 182-198) Request for Administrative Approval Dear i~1r. Rossberg: Per Rule 9 of Area [njection Order 004C.000, the Alaska OiI and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska} Inc. (~'BPXA"}'s November 12, 200 request for administrative approval to inject water in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 12-19. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures, PBL; 12-19 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to inject water in PBU 12-19 is conditioned upon the foilowin~: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPX.A shall perform an annual ~IIT - OA to 1.2 times the maximum anticipated well pressure; 4. BPXA shall perform an annual CMIT - T x [A to 1.2 times the maximum antici- pated well pressure; ~- BPXA shall limit the well's OA pressure to 1000 psi; Mr. Steve Rossberg December 13, ?00~ Page ? of 2 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 P~1 on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. at o e, Alaska and dated December 13, 200. ~'~ ~' ~~/ hn ~ 'or an, aniel T.'~eamount, Jr. Cathy P Foerster, Commissioner Commissioner Chairm _ ->~,~ , ,, ,~ _~- ~. ~ ;.. _ ~,~- ,= <,~~!' .. ~ k. s .,~ 12-19 (PTD #1821980) Internal w..cancellation - Reclassified as Not OPele Regg, James B (DOA) Page 1 of 1 From: NSU, ADWWelllntegrity Engineer [NSUADWWelllntegrityEngineer@BP.com] Sent: Friday, August 17, 2007 8:08 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr East (FS1/2/COTU/Seawater); GPB, FS1 OTL; GPB, FS1 DS Ops Lead; GPB, Wells Opt Eng; GPB, Optimization Engr Cc: Gerik, Bob G; NSU, ADWWelllntegrity Engineer; NSU, ADWWI Tech Subject: 12-19 (PTD #1821980) Internal Waiver Cancellation - Reclassified as Not Operable l2é'11 CO/z-tJ Do? All, /' An internal waiver was issued for TxlA communication on well 12-19 (PTD #1821980) on 01/24/06. The well does not pass an MITIA and is not considered Operable. Paperwork will also be sent to the AOGCC canceling the corresponding Administrative Approval. Plans are to restore this well with a rig workover. The well is reclassified as Not Operable. Please remove all waivered well signs and the laminated copy of the waiver from the well house. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 5'CANNI;D AUG 2 3 Z007 8/2112007 q 1 1.007 sGANNED JUN· /.I Schlumberger NO. 4306 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth UTe... IOd--1C]J) Company: State of Alaska Alaska Oil & Gas Cons Gomm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay D CI CD BL Well Job# Loa Description ate o or L3-12 11695062 PRODUCTION PROFILE 06/06/07 1 GNI-03 11637128 PRESS/TEMP SURVEY 06/06/07 1 Y -11 C 11661151 MEMORY INJECTION PROFILE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFILE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29L 1 11686753 LDL OS/28/07 1 Y-OSA 11628778 MEMORY INJECTION PROFILE OS/28/07 1 L5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-3SA 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07 A 11626098 PRODUCTION PROFILE OS/28/07 1 13-29L 1 11686753 LDL OS/28/07 1 04·24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDL 06/03/07 1 14-05A 11813055 PPROF W/RST BORAX 06/11/07 1 K·12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z-13A 11649962 MEMORY PROD PROFILE 04/21/07 1 W-17A 40012333 OH EDIT MWD/LWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: "H iJ\~ 51 ,0 ,lOin Received by: aLl t.j' 06/18/07 . . . . MEMORANDUlVI State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor DATE: Monday, May 21, 200i SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 12-19 PRCDHOE BAY UNIT 12-19 \ ~ÎY \~'Ó FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 12-19 API Well Number: 50-029-208iO-00-00 Inspector Name: John Crisp Insp N urn: mitJCrOi05181 10026 Permit Number: 182-198-0 Inspection Date: 5/13/2007 ReI Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --'---:-~.~.._- ----,--- I , I I I ,----, i Well i 12-19 ¡Type Inj. iN ¡TVD 8403 I IA I 160 I 2490 I 2470 : 24iO I I ~---+---~~'- [ SPT i Test psi --~-~-~ ~-"~--~r- ·¡--··-----·-~-------;-----i-~------ P.T.D! 1821980 [TypeTest I 2100.75 OA ' 160 I 450 450 ¡ 450 ! L___ I ---------- ~-.._--_. ~-----_._--- ---------. - _._---~ ~_._._..__._-- -_.----------_._--~.._..~_..- Tubing I 160 2390 i 2370 I 2370 I i Interval REQVAR P/F P I -1_____ i I Notes: CMIT TxlA for variance. 12.6 bbls pumped for test. b¡~c 46 .013- ÛI\I\..i.(?&,ellST - 'T¿\..:r:.;\ 1 ¡\.,t:Vr~ .-. I See.. C¡J¿SD J.rtsp :t\ ,1liiJ c r ò 705 I 'b( 05"4 2.( SCANNED JUN 0 6 Z007 Monday, May 21, 2007 Page I of 1 . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE; Monday, May 21. 2007 SUBJECT: "vlechanical Integnty Tests BP EXPLORATION (ALASKA) f"iC 12-19 PRUDHOE BAY uN1T 12-19 Jim Regg P,I. Supervisor ~ ¡<'FY1 Co(S{D? FROM: John Crisp Petroleum Inspector Src; Inspector NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 12-19 Insp Num: mitJCr070518105421 Rei Insp N urn: API Well Number: 50-029-20870-00-00 Permit Number: 182-198-0 Inspector Name: John Crisp Inspection Date: 5/13/2007 Packer Pretest Initial Well I 12-19 ¡Type Inj. iN! TVD IA - ~-¡-8;- I I _ ,I ___......I.- P.T.Di 1821980 !TypeTest : SPT : Test psi OA I 80 ----~-_.~--_..._--'--_,.______'______L....___ ~_______.._._. _.,__._ Interval REQVAR PIF __~__ ¡.// Tubi"-~__150 ~~o~~, Notes: MIT OA for variance. 2.2 bbls pumped for test. Depth 8403 I 2100.75 I \ lbå--" \ q~ Reviewed By; :J' 72 2...- P.I. Suprv '7 Comm 190 15 Min. 30 Min. 45 Min. 60 Min. i~;~: 190! : --'---."- 2500 2380 150 À:J:<J 4f .0/"3>- C(."\oI\.U<tt jL-L:vïc;.A,. 1- C,/"LÞ¡- T,><;.J:A S?ë. c-JÎý) .J..\S.þ:d.- ,!v\.lt~cr 07CS/£llC024 tiGANNED JUN {I 6 2007 Monday, May 21, 2007 -- 2350 ! ¡ ISO Page 1 of I . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenslein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay I PBU I OS 12 05113107 Jack Winslow John Crisp \ t6 3-~ 19 'ã Packer Depth Pretest Initial 15 Min. 30 Min. Well 112-19 I Type Ini. I N TVD I 8,403" Tubing 150 150 150 150 Int_1I V P.T.D.11821980 I Type test I P Test psil 2500 Casing 180 190 190 190 P/FI P Notes: AOGCC State witnessed MIT -OA for variance OA 80 2500 2380 2350 compliance. We1l112-19 I Type Inj. I N I TVD I 8,403" Tubing 150 2390 2370 2370 Interval! V P.T.D.\1821980 I Type test I P I Test psi I 2500 Casing 180 2490 2470 2470 P/FI P Notes: AOGCC State witnessed CMlT - TxIA for variance OA 80 450 450 450 compliance. Weill \ Type Inj.\ I TVD I Tubing Int_I! P.T.D.I I Type test \ I Test psi I Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I Tubing Interval! P.T.D.I I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj. I TVD I Tubing Int_1I PTD.I I Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal RadioactNe Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) S~liNE.D JUN 12 2007 MIT PBU 12-19 05-1 ~7.xls t( t: V 1::1 V 1-"'" tf:P1 STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS~ 0 8 Z007 REPORT OF SUNDRY WELL OPERATIONS C .. 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 S~ ~ & Gûs Con~theo/P$IS:~?~echanical plug _ Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D AR~Q!Mftsion D Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 182-1980 3. Address: P.O. Box 196612 Stratigraphic Service < P 6. API Number: Anchorage, AK 99519-6612 50-029-20870-00-00 / 7. KB Elevation (ft): 9. Well Name and Number: 77 KB 8. Property Designation: PBU 12-19 ADLO-028330 11. Present Well Condition Summary: 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool Total Depth measured true vertical 11 930 . 9218 ' feet feet Plugs (measured) Junk (measured) None None Effective Depth measured 11877 ' feet true vertical 9179 feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 33 - 112 33 - 112 1490 470 Su rface 2398 13-3/8" 72# L-80 32 - 2430 32 - 2429.6 4930 2670 Production 11160 9-5/8" 47# L-80 31 . 11191 31 - 8677.34 6870 4760 Liner 1033 7" 29# L -80 10887 . 11920 8464.52 - 9210.39 8160 7020 Perforation depth: &CANNED MAY 1 12007 Measured depth: 11328 - 11689 True Vertical depth: 8775.77 - 9040 . Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 4-1/2" 12.6# L-80 5-1/2" 17# L-80 3-1/2" 9.2# L-80 9-5/8"x4-1/2" AVA PPH Perm Pkr 7" X 5-1/2" OTIS BWD Packer o o Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 29 - 10793 10793 - 10914 11620 - 11624 11624 - 11633 10796 11 620 o o Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 4776 0 o Shut-in 0 15. Well Class after Droposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG 13. Oil-Bbl o o x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble R8DMS 8FL MA V 0 9 2007 Title Data Management Engineer Signature Phone 564-4944 d 04/2006 n n I ~ I f\ I ^ I Tubing pressure 240 o Service p GINJ W INJ P' W OS P L Sundry Number or N/A if C.O. Exempt: Date 5/7/2007 Xt5l \( Submit Original Only \~/ 12-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 5/1/2007 ***WELL S/I ON ARRIVAL*** (PRE STUD BOLT REPAIR) DRIFT WI 3.805 CENT, S-BAILER TO 10894'SLM SET 4.5 PXN PLUG BODY@10891'SLM (4,1/4" PORTS) SET PRONG @ 10,891' SLM (96" OAL, 1.80" O.D. & 1 3/4 FN) ***NOTIFIED DSO WELL LEFT S/I ON DEPARTURE & PLUG LEFT IN HOLE, TAGGED MASTER VAL VE*** "~"""'Å'''' .n ""'~"~".'Å'"'' .··..··'··N·'·.V^.^w_VN.N~.'·.. . .-""W"ÅW^",,_"'.'N.V.,,-"."_","_"_"_"_'_'_","_',"',WN"'" .h."···..··.. 5/2/200TT/I/O= O+IO+NAC. Temp= SI. TBG, lA, & OA FLs (pre-CMIT, MITOA). TBG FL @ 690'. (16 bbls). IA FL @ 210'. (10 bbls). OA FL @ 30'. (1 bbl). ,_···....N".'·h..·.·.....·.W"'.W.·.·.·.·.·.·.·.·..,·.WN.W.·~.·.wu.·,.·.·.·.·"'"·.·.·.·.·.·.·.·.W.·N.·.·^~^~..w.",··~ FLUIDS PUMPED BBLS 1 DI ESEL 1 TOTAL STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATlq~ 1. Operations Performed: Abandon 0 Alter CasingO Change Approved ProgramO 2. Operator Name: 3. Address: Repair WellO Plu: PerforationsO Pull TubingD Perforate New PoolO Operation ShutdownD Perforate 0 4. Current Well Class: Development 0 . BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 77.00 8. Property Designation: ADL-028330 11. Present Well Condition Summary: Total Depth measured 11930 feet true vertical 9218.0 feet Effective Depth measured 11877 feet true vertical 9179.0 feet Casing Length Size CONDUCTOR 79 20" 91.5# H-40 SURFACE 2704 13-3/8" 72# L-80 PRODUCTION 11160 9-5/8" 47# L-80 LINER 1033 7" 29# L·80 Perforation depth: RECEIVED S'¡::-D . L I 2 7 2006 Stimulate 0 WaiverO n ExploratoryO 5. Permit to Drill Number: 1 . 6. API Number 50-029-20870-00-00 StratigraphicO 9. Well Name and Number: 12-19 Service ŒI 10. Field/Pool(s): Prudhoe Bay Field I Prudhoe Oil Pool Plugs (measured) Junk (measured) Secured Well--- CMT Cap @ 11459' (07/26/2006) MD TVD Burst Collapse 33 112 33.0 112.0 1490 470 32 . 2430 32.0 - 2430.0 4930 2670 31 - 11191 31.0 - 8677.0 6870 4760 10887 - 11920 8465.0 9210.0 8160 7020 Measured depth: 11392-11452,11465-11505,11589-11597, 11601-11619, 11638-11648, 11649-11689 True vertical depth: 8822-8866,8875-8905,8967-8972,8975-8989, 9003-9010, 9011-9040 Tubing ( size, grade, and measured depth): 5-1/2" 17# L-80 4-1/2" 12.6# L-80 5·1/2" 17# L-80 3-1/2" 9.2# 13CrSO Packers & SSSV (type & measured depth): " 'k"!" .^*""", ""~f;\. ~"~ì\-...:~,;.~¡:-t'-j. \-.....:~' ~;\,'.-.........",:--. i/- @ 29 @ 10793 @ 11620 @ 11624 10793 10914 11624 11633 @ 10796 @ 11620 @ 2199 9-5/8" AVA PPH Hydrulic Set Perm PKR 7" Otis BWD Packer 5-1/2" Cameo Bal-O SSSV Nipple 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ Form 10-404 Revised 4/2004 ..r OCT I} 3 2006 Representative Dailv Averaae Production or Iniection Data Gas-Mef Water-Bbl Casin 51 51 Pressure 20 20 Tubin Pressure 10 33 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD DevelopmentD ServiceŒ WAG 0 GINJD WINJŒ WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A Title Petroleum Engineer Phone 564-5174 9/22/06 Date . . 12-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/28/2006 T/I/O = 50/0/0 - Injectivity test. (Sand plug) Pumped 83 bbls 60/40 meth water down tubing. Established injectivty of 4 bpm @ 1250 psi. FWHP's = 50/0/0 08/02/2006 *** WELL SI ON ARRIVAL *** (post sandbacklcmt plug) DRIFTED W/2.875 CENT, TEL & SAMPLE BAILER, LOC EOT @ 10,895' + 9' CORR= 10,904' ELMD, TAG SOFT CEMENT TOP @ 11,464' CORR ELMD. SAMPLE BAILER EMPTY **** NOTE: RAN 2.70 CENT BELOW ROPE SOCKET DUE POSSIBLY DAMAGED TT**** *****LEFT WELL SHUT IN***** 07/26/2006 CTU #f3, Sand Plug, Cement Cap; Confirmed top of sand multiple times at 11528' elmd (corrected to gr/ccl 04-Jul-06 and IPROF 27-Jun-94) after waiting 3 hours and pressuring up backside. POOH replacing voidage. MU and RIH with 2.66" OD "Pig Shear" nozzle. Tag top of sand and correct depth to 11528' elmd. Mix and pump 2.6 bbls - 15.8 ppg Class 'G' cement - est TOC 11459' - Shear Pig Noz - POH keeping hole full with diesel. Perform weekly BOP test. RD CTU #6. *** Job Complete **-, 07/25/2006 CTU 6, Sand Plug / Cement Cap; MIRU. MU and R.lH with 2.25" BDN. Tag bottom at 11616' ctmd. Correct depth to 11613' elmd (corrected to gr/ccl 04-Jul-06 and IPROF 27-Jun- 94) PUH load well with 1%KCL 07/05/2006 FINISH LOGGING W/ PDS MEMORY SPINNER TIL ***WELL LEFT S/I, NOTIFIED DSO OF WELL ST A TUS*** 07/04/2006 T/I/O = 100/0/0 - Assist slickline - (Re-set CMIT clock) - Pumped 95 bbls diesel down tubing for log. FWP's = 200/0/0 07/04/2006 MADE RUNS W/2 1/4 BAILER,@ 11,630 SLM. RAN 2.8 SWAGE,3 1/2 BRUSH,S.B. SAT DOWN @ 11,629 SLM. RAN 3 1/2 X-LlNE,W/3 1/2 XXN,SAT DOWN@ 11,627 SLM.NO SET. RAN PDS CCL TO 11628' SLM, LOG UP 40 FPM TO 10600' SLM RAN PDS MEMORY SPINNER, LOG BETWEEN 11300' SLM TO 11624' SLM. 07/03/2006 BAIL FILL W/10' X 21/4" DD BAILER FROM 11627' SLM TO 11629' SLM 07/02/2006 MADE SEVERAL RUNS W/2 1/4 BAILER,BAIL DN TO 11618' SLM RAN 41/2 XN LOCATOR,SAT DOWN @10,910 SLM. 3' CORRECTION. MADE MULTIPLE RUNS W/2 1/4" BAILER. BAIL DOWN TO 11624' 07/01/2006 MADE THREE 21/4" X 5' DD BAILER RUNS, MADE IT TO 11600' SLM, THEN BROKE THRU TO 11611' SLM RAN 2.8 SWAGE,31/2 BRUSH,1.1 SWAGE, BRUSHED NIPPLE @ 11,611 SLM. RUN 2.80" CENTRALIZER, 3' STEM, 2.85" LIB, GOT IMPRESSION OF POLISHED BORE. RUN 3.5" XXN PLUG, SET @ 11611' SLM Page 1 . . 12-19 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 2 Diesel to PT Surface Equipment 83 60/40 Methanol Water 486 Diesel 405 1 % KCL Water 12 Clean Gel 33 16/20 Carbolite --- 8 ppg 35 Fresh Water 2.6 15.8 PPQ Class "G" Cement 50 Contaminate 1108.6 TOTAL Page 2 TREE = FMC GEN 3 WELLHEAD = CALICO FMClMCEVOY ~CTUATOR= KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lV D = AXELSON 77' 2800' 51 @ 7200' 11467' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I Minimum ID = 2.75" @ 11632' 3-1/2" Parker SWN Nipple I 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" TOPOF 4-1/2" TBG-IPC I TOPOF7" LNR I 14-1/2" TBG-IPC, 12.6#, L-80, .0152 bpf, ID = 3.958" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I I TOP OF 5-112" TBG-IPC I 12-19 S NOTES: *** 3-112" CHROME TBG; 8' *** ***Tx A COMM. OPERATING LIMITS: MAX lAP = 2000 PSI, MAX OAP = 1000 PSI (01/06/06 WAlVER)*** . 2199' -15-1/2" CAM BAL-O SSSV NIP, ID = 4.562" I 10793' -15-112" X 4-1/2" XO I 10796' 9-5/8" X 4-1/2" AVA PPH HYDRAULIC SET PERM PKR -14-1/2" PARKER SWN PROFILE NIP, ID = 3.725" -14-1/2" TUBING TAIL I H ELMD TT LOGGED 04/19/92 -1 TOP OF C8v1ENT (07/26/06) -1 TOP OF SAND (07/26/06) -17" X 5-1/2" OTIS BWD PKR -15-1/2" X 3-1/2" XO I 15-1/2" TBG-IPC, 17#, L-80, .0232 bpf, ID = 4.892" I TOP OF 3-1/2" TBG I I 3-1/2" TBG, 9.2#, 13-CR, .0087 bpf, ID = 2.992" I 11624' 11624' 11633' -13-1/2" PARKER SWN NIP, ID = 2.75" --3-1/2"TUBINGTAIL I H ELMD TT LOGGED ON 02/11/93 I ÆRFORA TION SUMMA.RY REF LOG: BHCS ON 12/07/82 A NGLE AT TOP PERF: 43 @ 11328' Note: Refer to Production DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz DA TE SEE PAGE 2 FOR PERFORA TION DATA IpsTD I I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I DATE 12125/82 12114/91 01/03/02 09/26/05 11/06/05 01/26/06 ~ REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER RNITP CORRECTIONS JY JITLH ELM TT LOGGED (02/11/93) MORlTLH PXN TIP SET (10/30/05) RPH/TLH WArvER SAFETY NOTE 11871' 11920' 11930' DA TE REV BY COMMENTS 06/28/06 JGMlPAG PULLED PXN TIP I SFTY NOTE 07/26/06 RWLlPAG TOPs OF GMT & SAND PRUDHOE BA Y UNIT WELL: 12-19 PERMIT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) DATE 12/25/82 12/14/91 01/03/02 09/26/05 11/06/05 01/26/06 ÆRFORA TION SUMMARY REF LOG: BHeS ON 12/07/82 ANGLEAT TOP ÆRF: 43 @ 11328' Note: Refer to Produetion DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-1/8" 11326-11346 S 05/12/88 3-1/8" 4 11350-11430 S 05/12/88 3-3/8" 6 11391 -11411 S 12/91 3-3/8" 4 11392-11452 C 04/19/92 3-3/8" 6 11411 - 11451 S 05/12/88 3-3/8" 4 11465 - 11505 C 04/19/92 3-1/8" 11564 - 11584 S 05/12/88 3-3/8" 4 11589 - 11597 C 02/11/93 3-3/8" 4 11601 -11619 C 02/11/93 2-1/8" 6 11638 - 11648 C 02/11/93 2-1/8" 8 11649 - 11689 C 08/07/92 3-3/8" 6 11683 - 11687 S 05/12/88 RBI BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER RNlTP CORRECTIONS JY JITLH ELM TT LOGGED (02/11/93) MORlTLH PXN TTP SET (10/30/05) RPl-VTLH WM/ER SAFETY NOTE 12-19 . DATE RBI BY COMMENTS 06/28/06 JGMlPAG PULLED PXN TTP / SFTY NOTE 07/26/06 RWLlPAG TOPs OF GMT & SAND PRUDHOE BA Y UNIT WELL: 12-19 PERMIT No: 1821980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) 12-19 (PTD 1821980) Possible Tubing Leak e e ~Ke(f\X~ \'tt aÇ Subject: 12-19 (PTD 182198Ò) Possible Tubing Leak Fròm: "Anders,}()e L" <anders22@BP.com> Date: Mon, 24 Qþt 2005 10:03:44 -0800 .' IT···· .......;. '" ..... To: jÌfÎ1:c..regg@adn1.in.ak.us, wint~#_au.. admin.st .' ;ak;us .:.: ~~:N~~';;rii:.tntY ·;'l=;~;~~:~~1~ ~~ <G . JDSOpsLeàþ@BP.com>, "GJ¡>B, F'.lISIP/STP Areª1Mgr" . .' ':I~~~t~~~ ,'.~~r::~~ . pft~~j" 4 . . . .. ...... . . . .... . .. ... . ........ . . .. ..... ..... ...... ....... ntëgrity E~~.f" <.V~ Hello all. Well 12-19 (PTD #1821980) appears to have slow TxlA communication. The IA was bled from 340 psi to 20 psi and repressured to 340 psi in 30 minutes. Recent events: > 10/20/02: MITIA passed to 2300 psi (AOGCC witnessed) > 10/23/05: TIO = 200/340/0, bled lAP to 20 psi, repressured to 340 in 30 min. Current plan is to conduct an MITIA. Attached is a wellbore schematic, please call with any questions. «12-19.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com \~'fl ,. JI\¡¡"~kÀ!ç-: <2¡'~nu\:r Æ_,~' Content-Description: 12-19.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 12/22/20054:12 PM COMMENTS ORIGINAL COM PLErION LAST WORKOVER CORRECTIONS M TT LOGGED (02/11/93) SEC 8, BP Exploration (Alaska) PRUOHOE UNIT WELL: ÆRMIT No: API No: 50-02: TION, R15E 4696.01 1821980 ! )-20870-00 FEL 4953.08 FNL BY 7" LNR, 29#, L-80, .0371 bpf 10=6.184" OATE 11930' 11877' 11920' REV BY COMMENTS SEE PAGE 2 FOR ÆRFORA TION OA TA ÆRFORA TION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP ÆRF: 43 @ 11328' Note: Refer to Production OB for historical perf data SIZE I SPF INTERVAL Opn/Sqz DATE 3-1/2" TBG, 9.2#. 13-CR, .0087 bpf 17#, L-80, .0232 bpf, TOP OF 3-1/2" TBG 5-112" TBG-IPC, 10 = 4.892" 4-1/2" TBG-IPC, 9-5/8" 12.6#, L-80, .0152 bpf, 10 = 3.958" TOP OF 7" LNR TOP OF 4-1/2" TBG-IPC 10 = 2.992" 11633' 11624' 11624' ELMO TT LOGGED ON 02/11/93 3-1/2" TUBING TAIL 11632' 3-1/2" PARKER SWN NIP, ID = 2.75" 11624' 5-1/2" X 3-1/2" XO TOP OF 5-1/2" CSG. 47#, L-80, 10 = 8.681 TBG-IPC 11620' 10907' 10914' 7" X 5-1/2" OTIS BWO PKR ELMD TT LOGGED 04/19/92 4-1/2" TUBING TAIL 4-1/2" PARKER SWN PROFILE NIP, ID = 3.813" 9-5/8" X 4-1/2" AVA PPH HYDRAULIC SET ÆRM PKR I 10793' I I 10796' I 5-1/2" X 4-1/2" XO 5-1/2" TBG-IPC, Minimum ID = 2.75" @ 11632' 3-1/2" Parker SWN Nipple 7#, L-80, .0232 bpf 10 = 4.892" 13-3/8" ngle '::: MO= TVD= CSG, 72#, L-80. ID= 12.347" 8800' SS 2199' 5-1/2" CAM BAL-O SSSV NIP, 10 = 4.562" .{ TREE = -iEA D = , /!"TOR= .EV = FMC GEN 3 CALICO FMC/MCEVOY AXELSON e 12-19 e SAFETY NOTES: ***CHROME TBG*** TREE = FMC GEN 3 WELLHEAD'" CALICO FMC/MCEVOY ACTUA TOR'" AXELSON KB. ELEV = 77' SF. ELEV = KOP= Max Angle = Datum MD '" Datum TVD = 2800' 51 @ 7200' 11467' 8800' SS e ÆRFORA TION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP ÆRF: 43 @ 11328' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 11326 - 11346 S 05/12/88 3-1/8" 4 11350-11430 S 05/12/88 3-3/8" 6 11391 -11411 S 12/91 3-3/8" 4 11392 - 11452 0 04/19/92 3-3/8" 6 11411 -11451 S 05/12/88 3-3/8" 4 11465 - 11505 0 04/19/92 3-1/8" 11564 - 11584 S 05/12/88 3-3/8" 4 11589 - 11597 0 02/11/93 3-3/8" 4 11601 - 11619 0 02/11/93 2-1/8" 6 11638 - 11648 0 02/11/93 2-1/8" 8 11649-11689 0 08/07/92 3-3/8" 6 11683 - 11687 S 05/12/88 12-19 . DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/82 L COMPLETION 12/14/91 LAST WORKOVER 01/03/02 RNJTP CORRECTIONS 09/26/05 JY J/TLH ELM TT LOGGED (02/11/93) e PRUDHOE BAY UNIT WELL: 12-19 ÆRMIT No: 182-1980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission . _~O~ ~~~~~:~~~OL ~~j~~blo5=_ DATE: Wednesday, November 16,2005 FROM: John Crisp Petroleum Inspector ~U_IJJEC!~~~han~a~ Inte~rity !<:s.!S _ _____ BPEXPLORATION(ALASKA)INC 12-19 PRUDHOE BAY UNIT 12-19 Src: Inspector -- -ct-- .I \q \ 4:J~ NON-CONFIDENTIAL Reviewed By: P.I. Suprv :IF3ø-- Comm Well Name: PRUDHOE BAY UNIT 12-19 API Well Number 50-029 -20870-00-00 Inspector Name: John Crisp Insp Num: mitJCr051111082932 Permit Number: 182-198-0 Inspection Date: 1111012005 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 12-19 ¡Type Inj. i N I TVD I 8384 I IA I 860 2470 I 2440 I 2430 I I P.T. ! 1821980 ITypeTest I SPT i Test psi I 2096 ! OA I 320 ¡ 520 ! 530 I 540 ! I I I Interval REQVAR P/F P Tubing! 920 I 2500 I 2500 i 2500 ! ¡ Notes CMIT - TxIA for new waiver. 5 BBL's pumped for PI. 'U J~\"-~~~t.D ~." ~(r\}~¥ L '(. Wednesday, November 16,2005 Page 1 of 1 12-19 (PTD# 1821980) Failed MITIA ) ') \1r1 \ O'j .---;) \ b \ 't-J> ~ \, .:::........." .. .......:". . .... ... ... ....,.. ".".... .. ".": :".: ". . .. . "." .. ,".. '.", .. '." : .".' . .. . .' S~~je~t:il~~19(PTP#1821980)Fai~e4¥ITIi\< .'. . ............... .... . ......... ......i .>' ....'............'.....< .. . ........ ..... ..... '. .....,..'.........'....... ...... F. .. ~9.Jn.:'.'N...·. '. S..., U. ....<,A.Ð...., ,'.WW~llIntegrityErigirie~r'~<:NSUADWWellIî1tegrityEngineer@IlP. ~C. qm... > . . ."'.....: .".. ".:" ":.'"' :".". ......".. .:.:"' .:. ...... ...... ".. "".. ................... . ....... :.....:. .. .: ..... .." "", ." . . . .... .. Da.·te: Wed> 26. Odt200520:22:16..080Q ............ . .' ,....... . ,.. ., .' ....., ',' . ......'.. '. .... ". .'.. ,. ..' . ....,. < ... '..... .... . .,.. '. . . Hello Jim & Winton, We performed an MITIA to 2500 psi on well 12-19 (PTD# 1821980) on 10/25/05 that failed with an llR of 0.3 bpm @ 2500 psi. The current plan forward is to secure the well and identify if the well has a tubing leak or a PC leak. Plan forward: 1. FB: MITIA to 2500 psi - FAilED, llR == 0.3 bpm @ 2500 psi 2. Sl: Brush & flush, set TTP 3. FB: MIT-T to 2500 psi, MITOA to 2500 psi 4. WIE: If MIT-T & MITOA pass, Write TxlA waiver & AA for PWI only Attached is a wellbore schematic & the MIT form, please call with any questions. «12-19.pdf» «MIT PBU 12-19 10-25-05.xls» Thanks, Donald Reeves - Filling in for Anna Oube Well Integrity Engineer 907 ~659-51 02 907~659-51 00 #1154 pgr $CANNEfJ NOV 1 ~¡ 2005 From: Anders, Joe L Sent: Monday, October 24, 2005 10:04 AM To: Jim_Regg (jim_regg@admin.state.ak.us); AOGCC - Winton Aubert (winton_aubert@admin.state.ak.us) Cc: NSU, ADW Well Operations Supervisor; NSU, ADW Well Integrity Engineer; GPB, FS1 DS Ops Lead; GPB, FS1/SIP/STP Area Mgr; Gerik, Bob G; Rossberg, R Steven; Engel, Harry R; Don Reeves (reevesdf@alaska.net reevesdf@bp.com); Hughes, Andrea (VECO); Luckett, Ely Z. (VECO) Su bject: 12-19 (PTD 1821980) Possible Tubing Leak Hello all. Well 12-19 (PTO #1821980) appears to have slow TxlA communication. The IA was bled from 340 psi to 20 psi and repressured to 340 psi in 30 minutes. Recent events: > 10/20/02: MITIA passed to 2300 psi (AOGCC witnessed) lof2 10/27/2005 8:39 AM 12-19 (PTD# 1821980) Failed MITIA ) ) > 10/23/05: TIO == 200/340/0, bled lAP to 20 psi, repressured to 340 in 30 min. Current plan is to conduct an MITIA. Attached is a wellbore schematic, please call with any questions. « File: 12-19.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom Content-Description: 12-19.pdf 12-19.pdf Content-Type: application/octet-stream Content-Encoding: base64 PBU 12-19 Content-Description: MIT PBU 12-19 10-25-05.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 20f2 10/27/2005 8:39 AM ) ) STATE OF ALASKA / ALASKA OIL AND GAS CONSERVATION COMMISSION t~ \l:P Mechanical Integrity Test .A12C . \ IJ\~ ~f.JY OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS12 10/25/05 Donald Reeves Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us \%~ e:'Õ Packer Depth Pretest we1l112-19 I Type Inj. I TVD I Tubing 180 P.T.D. 1821980 Type test P T est psi 2500 Casing 350 Notes: MITIA Failed, established LLR of 0.3 bpm @ 2500# OA 0 0 weill I Type Inj. I I TVD I Tubing P.T.D. Type test T est psi Casing Notes: OA weill Type Inj'l I TVD I Tubing P.T.D. Type test T est psi Casing OA Notes: weill Type Inj'l I TVD I Tubing P.T.D. Type test T est psi Casing OA Notes: weill Type Inj'l I T:~PSil Tubing P.T.D. Type test Casing OA I Notes: TYPE INJ Codes D = Drilling Waist G = Gas I = Industrial Waistewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT Report Form BFL 911105 2005-1025_MIT_PBU_12-19,xls Initial 160 2,500 o 15 Min. 30 Min. 160 N/A 1,000 N/A N/A Interval 0 P/F F Interval P/F Interval I P/F Interval P/F Interval P/F INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) Tr~EE:: FMC GEN 3 WELLHEAD == CALICO FMC/MCEVOY ACTÜATÓR'; .. ...... .... . . . .. AxELsÖN KB. ELEV ::: 77' "·'w,,,............ ,v"',',"," BF. ELEV ::: KOP::: MaxÄrïgie;; ... DatÙmMO;;;" ... ................."........,."......,......."..... Datum TV 0 ::: ) 12-19 ) SAFETY NOTES: ***CHROME TBG*>\':k 2800' ... ..... .... ·······!51@72Öbï . ......,.................,.."...."....." 11467' 8800' SS 2199' 1-1 5M1/2" CAM BALMO SSSV NIP, 10::: 4,5ß2" (I» 113-3/8" CSG, 72#, L-80, ID::: 12.347" 1-1 2430' r---4I 16 Minimum ID = 2.75" @ 11632' 3-1/2" Parker SWN Nipple [5-1/2" TBGMIPC, 17#, L-80, .0232 bpf, 10::: 4.892" 1-1. 10793' 1 ~ [TOP OF 4-1/2" TBG-IPC 1-( 10793' ~ :;g: I 10793' 1-1 5-1/2" X 4-1/2" XO I ~-I 10796' 1- 9-5/8" X 4-1/2" AVA PPH HYDRAULIC SET ÆRM PKR I TOP OF 7" LNR l-i 10887'.1 I I I 10907' 1-14-1/2" PARKER SWN PROFILE NIP, 10::: 3.813" [4-1/2" TBG-IPG, 12.6#, L-~O .0152 bpf, 10::: 3.958" l-i. 10914' I 10914' 1-14-1/2" TUBING TAIL I ~ 10904' 1-1 ELMO TT LOGGED 04/19/92 1 [ 9-5/8" CSG, 47#, LM80, 10::: 8.681" l-f 11191' µ I TOP OF 5-1/2" TBGM IPC 1--1 11620' 1 ð' ~ 11620' l-f 7" x 5-1/2" OTIS BWD PKF~ 5-1/2" TBG-IPC, 17#, L-80, .0232 bpf, 10::: 4.892" l-f 11624' I \ I 1-15-1/2" X 3-1~2" XO 1 I TOP OF 3-1/2" TBG l-f 11624' f ' 11624' I I 11632' 1-I3M1/2" PARKER SWN NIP, 10::: 2.75" I 3-1/2" TBG, 9.2#, 13·CR, .0087 bpf, ID::: 2.992" l-f 11633' 1-13-1/2" TUBING TAIL 1 11633' 11632' ]-1 ELMO TT LOGGED ON 02/11/93 1 SEE PAGE 2 FOR ÆRFORA TION OA TA ÆRFORA TION SUMMARY REF LOG: BHCS ON 12/07/82 ANGLE AT TOP ÆRF: 43 @ 11328' Note: Refer to Production DB for historical perf data ~ SIZE 1 SPF I INTERV AL I Opn/Sqz I OA TE I PSTO 1-1 11877' I 7" LNR, 29#, L-80, .0371 bpf, 10::: 6.184" 1-1 11920' ~-t 11930' . DATE 12/25/82 12/14/91 01/03/02 09/26/05 REV BY COMMENTS ORIGINAL COM PLEfION LAST WORKOVER RNlTP CORRECTIONS JY JITLH ELM TT LOGGED (02/11/93) DATE REV BY COMMENTS PRUDHOE SAY UNrr WELL: 12-19 ÆRMrr No: 1821980 API No: 50-029-20870-00 SEC 18, TION, RiSE 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) ') TREE::: FMC GEN 3 WElLHEAD:::: CALICO FMC/MCEVOY AC1;ûÄTÓR;' . AXEL.SÓN kriäèi; ... SF. ELEV == KOP== Max Angle ::: . DatÙmMÖ;;· ...............,,,......,..... ....""....... Datum TVD =: DATE 12/25/82 12/14/91 01/03/02 09/26/05 2800' 51 @ 7200' ..,. ....... ................ ............."""....".".. 11467' 8800' 5S PERFORA TION SUMMA RY REF LOG: BHCS ON 12/07/82 A NGLE AT TOP PERF: 43 @ 11328' . Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 11326 - 11346 S 05/12/88 3-1/8" 4 11350 - 11430 S 05/12/88 3-3/8" 6 113H1 - 11411 S ,. 12/91 3-3/8" 4 113~12 - 11452 0 04/19/92 3-3/8" 6 11411-11451 S 05/12/88 3-:3/8" 4 11465 - 11505 0 04/19/92 3-1/8" 11564 - 11584 S 05/12/88 3-3/8" 4 11589 - 11597 0 02/11/93 3-3/8" 4 11601-11619 0 02/11/93 2-1/8" ß 11638 - 11648 0 02/11/93 2-1/8" 8 11649 - 11689 0 08/07/92 3-3/8" 6 11683 - 11687 S 05/12/88 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOV ER RNlTP CORRECTIONS JY JffLH ELM TT LOGGED (02/11/93) DATE REV BY 12-19 -. ~ \ I :8: Z II I I .. 1-. 8 Z ~I < . COMMENTS ~ ) PRUDHOE BA Y UNIT WElL: 12-19 PERMrfNo: 182-1980 API No: 50-029-20870-00 SEC 18, TION, R15E 4696.01 FEL 4953.08 FNL BP Exploration (Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor y~--~ DATE: October 20, 2002 Chairman ~~.g~ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder f BPX P.I. Supervisor DS~ 12 PBU FROM: Chuck Scheve Prudhoe Bay Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. "WellJ 12-19 J Typelnj. J S I T.V.D. J 8403 J Tubingl 1850 J 1850 I 1850 I 1850 ]lntervalJ 4 P.T.D.I 182-198 IType'testl P ITestpsil 2101 I Casingl 250 I 2300 I 23001 23001 PIE I,P Notes: WellI 12-33 I Typelnj. J S J T.V:D. 18458 J Tubingl ~00 I ~'~00 I~00 I~00 I lntervall 4 P.T.D.I 189-010 TypetestI P ITestpsil 2115 I CasingI 100 I 2250 I 2250:1 22501 p/FI P Notes: WellJ P.T.D.I Notes: " WellI P.T.D.I Notes: ' WellI P.T.D.I Notes: JType Inj. Type test Type Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER IN J. G = GAS INJ. $ = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance . W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 12 and witnessed the 4-year MIT on wells 12-19 and 12-33. The. pretest tubing and casing' pressures were observed and found to be stable. The casings were then preSsured up and observed for 30 minutes with all both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Attachments: Number of Failures: 0 -- Total Time during tests: 2 hours cc-' M IT report form 5/12/00 L.G. MIT PBU DS 12 10-20-02 CS.xls 10/25/2002 ARCO Alaska, Inc. Date- Subject: From/Location' Telephone: To/Location: July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Transmittal #: 94054 ~ ~' ,;UL ! 7' '199 .4las~ Oil & Gas Cons. Commission A'~ct~ora.ce .. , Well i Log Date i Tool Type Number i (M-D-Y) 1-05ST ! 6-21-94 i Prod Pro, 1-17 ! 6-20-94 i/ ProdProf 2-20 ! 6-18-94 /IBP Setting Rec 2-28 ~ 6-28-94j/ Leak Detection 3-2 ! 6-22-94 k Leak Detection 4-2 ! 6-17-94 ~ Patch Set Rec 4-30ST! 6-25-94 I / Per, Rec 4-40 i 6-25-94 t / Per, Rec 4-43 ! 6-23-94 i ~- Comp Rec 4-44 i 6-20-94'i / Per[ Bec · /" Per[ Rec 5-03A ! 4-45 i 6-25-94 5-03A i 6-9-94 6-9-94 5-03A ! 6-9-94 5-13 i 6-17-94 5-33 i 6-29-94 6-8 i 6-15-94 Lo~ ! 6-12A i 6-24-94 '" Slim I GR ~ CDR · ,- Leak Detection Per[ Record / TDTP Per[ Rec 7-6 i 6-28-94 ~ Per[Rec 7-26 ! 6-19-94 i.. Per[ Bec 9-05A ! 6-21-94 .--' Per[Bec 9'05A ~ 6'22'94 ', Per[Rec 9-30ST ! 6-29-94 ,~'Duai Burst 11-6 i 6-22-94 /'Prod Prof 11-29i 6-27-94 / Per[ Rec 12-02 ~ 6-28-94 ~ IniPmf Run, Scale , 5II 1~ 5II 1, 2" & 5" 1 5" 1 5" I 5" I 5" 1,2" &5" 1,2" & 5" 1,1" & 5" ,1 511 1 511 , 5II ,511 1, 5" , 5II , 5II ! 5II Contractor i } SCH SCH SCH SCH SCH · SCH SCH SCH SCH SCH SCH ~ SCH ! SCH 12-7A l 6-27-94 12-19 i 6-27-94 12-23 i 6-28-94 12-28I 6-27-94 13-08 ! 6-30-94 14-24 i 6-15-94 14-39 i 6-19-94 14-39 i 6-19-94 16-28 l 6-20-94 -"Leak Detection ~ Ini Pmf Ini Pmf Prod Prof Per[ Pro, -/ CNL "Leak Detection Leak Detection Per[ Rec SCH SCH SCH SCH ; SCH ~ SCH i SCH ~ SCH SCH SCH 1, l"& 5" SCH 1, 5" SCH , 5II , 5II 1~5II 1,5" , 5II , 5II ! 51l 1, 1" &5" , 2II 1 511 SCH SCH SCH SCH SCH SCH SCH SCH i SCH i SOH * DS# 04-02 The APl# is 50-029-20088-00 Number of Records: 35 ARCO Alasi(a, Inc. Is a Su~sid~ary of AtlantlcRIchfleldCompeny ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska ~510 DATE: REFERENCE: ARCO CASED HOLE FINALS -11 1-24-93 -11 2-7-93 1-13 2-7-93 /~~1-24a 2-20-93 ~--Z-~~l-30 1-24-93 · -l~'~"~t'i~ -- 2-14 7-27-91 ~ ~-- 3-9 12-19-92 ~ ~._~_~i~-24 1-25-93 ~t~ '3-32 4-25-92 ~3-32 4-25-92 q~_1~-32 2-19-93 ~3-34A 2-19-93 ~l~ ~ .4-35 8-16-92 -15 10-27-92 q ~.~.~.~_-,~ 2-22-93 3-2-93 -~' ~"-~'~9-27 ~. 3-1-92 '"'"--- %9-27 3-1-92 - 1 2-8-93 1-1 4-21-92 1-13A 3-8-93 1-18 4-14-92 1-18 4-14-92 12-28-92 4-37 4-13-92 6-21 7-23-92 6-21 7-23-92 6-27 8-23-92 __16-30 2-12-93 RECEIVED -~~7-21 12-20-92 Perf Record Please sign and return t~e art.ached co. py as receipt of data. Sonya Wallace AT0-1529 'A/aska 0il &a.~_.h_Gas Cons. ~"~nlaalon Perf Record ~~' H~ Pe~ Record R~ 1, ~ H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ T~ R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Peri Record R~ 1, ~' H~ PGST Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ 'T~ R~ 1. ~' H~ DSN R~ 1, ~' H~ T~ Boron ~Jection R~ 1, ~' H~ Peri Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ ~GT 5 ~/~ R~ 1, ~' H~ ~ 10 ~/~ R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Resets R~ 1. ~' H~ PSGT R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ PSGT Computed Rea~s H~ 1. ~' H~ PSGT R~ 1, ~' H~ Pe~ Record R~ 1, ~' H~ Pe~ Reco~ R~ 1, ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ 1. ~' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1. ~' H~ ~GT Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ PSGT Computed Resets R~ 1, ~' H~ PSGT R~ 1, ~' H~ Pe~ Record R~ 1. ~' H~ Pe~ Record R~ l. ~' H~ R~ 1, ~' H~ # CENTRAL FILES # CHEVRON # LUCHA~ JOHNSTON # EXXON PHILLIPS MOBIL BPX STATE OF ALASKA * The correct apl# for 3-32 is 504)29-21141-00. ,.- -.; -----.. STATE OF ALASKA .--.. ALASKA _AND GAS CONSERVATION CC,. AISSION ~ ' · .... -' REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operal:ion shul:down stimulate Plugging ,erfora1:e X · /./. Pull tubing Alter casing Repair well Other 6. Datum of elevation(DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 323' FSL, 4716' FEL, Sec. 07, T10N, R15E, UM Development: Exploratory Stratigraphic Service X 5. Type of Well RECEIVED 77 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-19 9. Permit number/approval number 82-198, 93-009 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Oil Pool MAR 5-0 199; .Alaska Oil & Gas Cons. Cornmiss[o~ Anchorage 12. Present well condition summary Total depth: measured true vertical 11930' MD feet feet Plugs(measured) None Effective depth: measured 11877 MD feet true vertical 9179' TVD feet Junk(measured) Casing Length Size Cemented Conductor 79' 20" 1850sx Sudace 2429' 13-3/8" 1800 sx & 400 sx None Measured depth True vertical depth 79' MD 79' TVD 2429' MD 2429' TVD Intermediate 11191' 9-5/8" 505 sx & 300 sx 11191' M D' 8677' TVD' Liner 1033' 7" 350 sx 10887-11549' 8464'-9210' Perforation depth: measured 11392'-11452', 11465-11505', 11590-598',11602-620', 11639-689'. true vertical 8822-8866',8878-8905', 8970-976',8979-992',9006-9042'. Tubing (size, grade, and measured depth) 5.5", 17#L-80, tbg w/tail @ 10914'. 3.5" 9.2#,L-80 lower assbly @11620'-633' Packers and SSSV (type and measured depth) AVA pkr @ 10796', BWD pkr @ 11620', BaI-O SSSV @ 2199' 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiloBbl Gas-Md Water-Bbl Casing Pressure 13600 13700 Tubing Pressure 2228 2187 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas __ Suspended Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ 0 ~ Title Senior Operations Engineer Form 10-404 Rev 06/15/88 ~ Date 3/23/93 SUBMIT IN DUPLICATE~,,,~ Summary of Adperf Operations DS 12-19i 2/11/93. Depressed fluid level with AL gas. Backflowed to achieve drawdown and perforated: 11590-11598'@ 11602-11620' @ 11639-11649' @ 4 spf, 3-3/8" gun. 4 spf, 3-3/8" gun 6 spf, 2-1/8" gun Resumed water injection. KML 3/23/93 RECEiVeD MAR ~ 0 !-99~ .Alaska Oil & Gao Cor~s. Cornmir~sion Anchorage, 1. Type of Request: 2. Name of Operator ARCO Alaska, Inc. .~---. STATE OF ALASKA ALASKA. .,_ AND GAS CONSERVATION ;C. /ii.iON AP___PLICATIO_ _N FOR e RY Abandon Suspend , 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 Alter casing Repair well Plugging Change approved program Pull tubing Vadance 5. Type of Well Development Exploratory Stratigraphic Service X 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, T10N, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, T10N, R15E At effective depth At total depth 323' FSI, 4716' FEL, SEC. 07, T10N, R15E RECEIVED JAN 1 9 1993 Alaska 0il & Gas Cons. (~umrdssi01' Anchorage measured 11930' feet Plugs(measured) true vertical feet 12. Present well condition summary Total depth: Effective depth: measured 11849' feet true vertical 9158' feet Re-enter Je~l well Time extension ~x~m~ate ~eer Pedorate, /~ Length Size Junk(measured) Cemented 6. Datum of elevation~F or KB) KBE = 77' 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 12-19 9. Permit number 82-198 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Fled/Oil Pool 79' 20" 1850 SX 2429' 13-3/8" 1800 SX & 400 SX Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: feet Measured depth True vertical depth BKB 79' 79' 2429' 2429' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10833' & 4-1/2" L-80 @ 10914', 3.5" 9.3&L-80 11620-11633 Packers and SSSV (type and measured depth) Ava 9-5/8" PPH Packer @ 10796' MD, SSSV @ 2199' MD; Otis 7" 'BWD' Packer at 11620 MD, 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation January 30, 1993 16. If proposal was verbally approved Oil Name of al)prover Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~"~f- ,~ Title 15. Status of well classification as: Gas Suspended WAG Injector Senior Engineer Date I,) 1.~/~ FOR COMMISSION LIEF_ ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Mechanical Integrity Test Approved by order of the Commissioner Form 10-403 Rev 06/15/88 Location clearance Subsequent form required 10- ,4/_0,.{ Origin?' ?:.2ned By Dav~~'~ ~:,:... J.~hnoton IApproval No. CommiSSioner Date SUBMIT IN TRIPLICATE 11191' 9-5/8" 505 sx & 300 sx 11191' 8677' 1033' 7" 350 sx 10887'-11920' 8464'-9210' measured 11328'-11689' true vertical 8776'-9042' Proposed Ad/Reperf Operations DS 12-19i In order to improve tertiary recovery by increasing vertical sweep efficiency of MI, the following ad/reperfs are proposed: · MIRU Electric line Unit. · Test BOP Equipment. · Perforate 11540'- 11550' @ LSD 11570-11588' @ LSD 11590-11596' @ FSD 11602-11620' @ FSD 11639-11649' @ FSD KML RECEI'¢I9 Aiaska 0ii & Bas gong. Co~-n~-f~iss~o~ Anchorag~ 6 5 4 2 COILED TUB],Ni3 UNIT BOP EGU ! PI, lENT 1. ~000 PSi ?" W£LLHEAD CONNE~CTOR FLANGE 2. 5000 PSI 4 1/16" PIPE: RAMS 3. ~d:)O0PSI 4 1/6" HYD~LK~ SLIPS 4. ~)O00 PSI 4 1/6" SH£AR RAMS ~).5000 PSI 4 '1/6" BLIND RAIDS 6. ~)000 PSI 4 '1/'16" STUIrF'ING BOX 4 2 RECEIVED dA N !. 9 Ir39,5 iska Oil & Gas Cons. ~jommissil ' Anchorage HI ,REL,INE BOP EOUIPHENI' 1. ~000 Peal?" WELLH[.AD CONNECIOR FLANG[ 2. 5000 PSI WIR[LIN[ RAUS (VARIABL[ 3. ~000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ~_. STATE OF ALASKA ALASKA~ 'AND GAS CONSERVATION CC '-"IlSSIO~ ~ I C~ ! ~ A--~ REPORT OF SUNDRY WELL oPr-HATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska~ Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Strafigraphic 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, T10N, R15E At top of productive interval 55'FNL, 4552' FEL. SEC. 18, T10N, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC, 07, T10N, R15E REC"EIVED N OV - lgg ~_las~.Oil.& Gas Cons. Commission 'Ar ,lzor;ge 12. Present well condition summary Total depth: measured true vertical 11930 feet Plugs(measured) feet 6. Datum of elevation(DF or KB) KBE=77 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-19 g. Permit number/approval number 82 - 198 10. APl number 50 - 029 - 20870 11. Field/Pool Prudhoe Bay Oil Pool feet Effective depth: measured true vertical 11877 feet 9179 feet Junk(measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented 1850 sx 1800 sx & 400 sx 79' 20" 2429' 13-3/8" 11191' 9-5/8" 505 sx & 300 sx 1033' 7" 350 sx measured 11392'-11452'; 11465-11505; 11649-11689' Measured depth True vertical depth KB 79' 79' 2429' 2429' 11911' 8677' 10887'-11920 8464'-9210' true vertical 8822-8866'; 8878-8905'; 9013-9042' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10833' & 4-1/2" 12.6# L-80 @ 10914' & 3-1/2" 9.2# 13CR @ 11633' Packers and SSSV (type and measured depth) Otis 7" 'BWD' packer at 11620' MD, Ava PPHH Set Perm Packer at 10796' MD, SSSV at 2199' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Reoresentative Daily Average Production or In!ectjon Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8000 200psi 700psi Subsequent to operation 5321~ 200 psi 500 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas.__ Suspended__. Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 Title Senior Engineer cc: S. Wallace/DS Er~jr/J. W. Peirce Date /0//~ ~,/,';~ ~_ SUBMIT IN DUPLICATE Daily Report of Operations DS12-19; 8/07/92 MIRU HIS. PT. RIHw/GUN #1. Shoot 11668-11688' IVID. POOH. LD GUN # 1. All shots fired. PT. RIH w/GUN #2. Shoot 11648-11668' MD. POOH. LD GUN #2. Ail shots fired. Release well. Resume SWI injection. RECEIVED NOV - 2 199~_ Alaska Oil & Gas Cons. Commission' Anchorage ARCO Alaska, Inc. P.O.Box 100360 Anchorage, ,~lnskn 99510 DATE: 10-2-92 REFERENCE: ARCO CASED HOT.~- FINALS ****** 16-31 ~2..~.t-. 8-25-92 Per/ Run L 5" ~rr-S Per/ Run 1, 5" HLS Per/ l~m 1, 5" HL~ Per/ l~m 1, 5" HLS Collar l~m 1, 5" HLS Per/ Run 1, 5" HLS Per/ Run 1, 5" HIS Per/ Rrm 1, 5" HL~ Per/ Run L 5" Perf Run 1, 5" l~-q Per/ Run 1, 5" l~-S Per/ Rrm 1, 5" ~=rLS Per/ Rrm 1, 5" HIS Collar l~m 1, 5" HLS Per/ Run 1, 5" HLS Collar Run 1, 5" HLS Perf Run 1, 5" HLS Per/ Run 1, 5" HI~ Per/ Run 1, 5" HI~ Per/ ~m 1, 5" KLS Please sign and retura ~at~Cz~e~ copy u receipt of dat~ RECEIVED~ /2./ Sonya Wallace OCT 0 5 1992 APPROVED_~~__ _ ATO-1529 Tr~ns# 9221~~'~-~--- Alaska Oil & Gas Cons. # CENTRAL ~o~g~ # CHEVRON # EXTENSION EXPLORATION # EXXON # MOBIL # PHK, LIPS PB WELL ~ # BPX # STATE OF ALASKA Th~ ~ well nam~ is 1-L5. The cra-feet APl # fee l-lB is 50-029-21007-01. The cmrect well -nme is 6-14~%- The correct API # for 7-4A is 50~29-20292-01. The correct APl # for 14-1 is 50-029-~317~. The correct AP1 # flit 14-5A is 504)29-20327-01. The ~ API# for 16-31 is 504Y29-22280-00. /7 ARCO .a.l. slm, Inc. P.O.Box 100360 Anchorage, Alaska 995 10 DATE: 6-19-92 REFERENCE: 3-35 4-37 7.9 Z,~" 11-5 ,~/~ ARCO CASED HOLE FINALS 5-12.92 Jewelry Run 1, ~' C~_mco 5-21.92 GR-Collar lh_m I, ~Y' Camco 5-15.92 Prod Profile l~m 1, [~' C_~mco 5-12-92 Prod Profile l~n 1, 5" Camco 5-12-92 Jewelry lh~m 1, [Y' Camco 5-17-92 Prod Profile Run 1, 2'8d~' Camco 5-11-92 Prod Profile Run 1, ~' Camco 5-16-92 PITS lh_m 1, 5" Cameo 5-15-92 PITS/Flowmeter Run 1, ~' Camco 5-24-92 Prod Profile Run 1, 5" Camco 5-16-92 Prod Profile Run 1, ~' Camco 5-15-92 Prod Profile Run 1, ~' Camco 5-14-92 Prod Profile Run I, [~' Cs__mco 5-14-92 Prod Profile Run 1, ~' Camco 5-18-92 Gas Lift Run 1, :~'&t~' Camco 5-25-92 InJ Profile Run I, ~' Camco 5-14-92 InJ Profile Run 1, ~' Camco 5-14-92 lnJ Profile Run 1, ~' C~mco 5-19-92 CCL/GR/Junk Basket Run 3, ~' Camco Please sign and return the attached copy as receipt of data. RECEIVED BY ~ Have A Nice Day! Sonya Wallace ATO- 1529 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ALASKA TEXACO RECEIVED * The correct APl# for 9-30ST is 50°029-2 14 11-00. AUG 1 0 1992. Alaska Oil & Gms Cons. Commission Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION CC--",,IlSSK I REPORT SUNDRY WELL OPF_.,-1ATI FI 1. Operations performed: Operation shutdown -- Stimulate __ Plugging Perforate ~ Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, T10N, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, T10N, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC. 07, T10N, R15E 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) KBE=77 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-19 9. Permit number/approval number 82-198/92-078 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Field/Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11930 feet Plugs(measured) feet Effective depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: 11877 feet 9179 feet Junk(measured) Length Size Cemented 79' 20" 1850 sx 2429' 13-3/8" 1800 sx & 400 sx 11191' 9-5/8" 505 sx & 300 sx 1033' 7" 350 sx measured 11392-11452'; 11465-11505'; 11649-11689' Measured depth True vertical depth KB 79' 79' 2429' 2429' true vertical 8822-8866'; 8878-8905'; 9013-9042' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10795' & 4-1/2" L-80 @ 11634' 11191' 8677' 10887'-11549' 8464'-9210' Packers and SSSV (type and measured depth)PackerBaker SAB Packer @ 10821' MD, SSSV @ 2211' MD; Otis 7" ~W¢~pf~,~.~ 11620' MD,at 10796' MD, SSSV at 2199' MD D ~ ~ 13. Stimulation or cement squeeze summary "'~ '- ~'' '- '" -- - Intervals treated(measured) Treatment description including volumes used and final pressure AY 1 5 1992 Alaska 0il & Gas Cons. O0m~'tssi0t~ /~n~.hora_oe 14. Prior to well operation Subsequent to operation Representative Daily Averaoe Production or In!ection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 3057 200 psi 6265 200 psi Tubing Pressure 621 psi 749 psi 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil__ Gas__ Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~/~-- ~. ~-~-~-'------- Title Senior Engineer Date Form 10-404 Rev 06/15/88 cc: S. Wallace/DS Enor/J. W. Peirce SUBMIT IN DUPLICATE 4/19/92 Daily Report of Operations DS 12-19 MIRU AWS. PT. RIH w/GUN # 1. Shoot 11484-11504' MD. POOH. LD GUN # 1. 36 of 80 shots didn't fire. PT. RIHw/GUN #2. Shoot 11464-11484' MD. POOH. LD GUN #2. All shots frred. PT. RIHw/GUN #3. Shoot 11431-11451'MD. POOH. LD GUN #3. All shots frred. PT. RIH w/GUN #4. Shoot 11411-11431' MD. POOH. LD GUN #4. All shots fired. PT. RIHw/GUN #5. Shoot 11391-11411' MD. POOH. All but 2 shots fired. PT. RIH w/GUN #6. Shoot 11484-11504. POOH. All shots fired. RD. Release well. Resume SWI injection. RECEIVED MAY 1 5 1992 Al~s.ka .Oil .& Gas Cons. Commission t~cherage STATE OF ALASKA ALASKA'~--''. AND GAS CONSERVATION REPORT SUNDRY WELL OPLrlATIONS 1~. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, T10N, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, T10N, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC. 07, T10N, R15E 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) KBE=77 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-19 9. Permit number/approval number 82-198/91-287 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth' measured true vertical 11930 feet Plugs(measured) feet Effective depth: measured true vertical Casing Structural Conductor Sudace Intermediate Production Liner Perforation depth: 11877 feet 9179 feet Junk(measured) Length Size Cemented Measured depth True vertical depth KB 79' 20" 1850 sx 79' 79' 2429' 13-3/8" 1800 sx & 400 sx 2429' 2429' 11191' 9-5/8" 505 sx & 300 sx 11191' 8677' 1033' 7" 350 sx 10887'-11549' 8464'-9210' measured 11649-11689' true vertical 9013-9042' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10795' & 4-1/2" L-80 @ 11634' Packers and SSSV (type and measured depth) Baker SAB Packer @ 10821' MD, SSSV @ 2211' MD; Otis 7" 'BWD' packer at 11620' MD, Packer at 10796' MD, SSSVat 2199' MD r~ ~' ~ ~' ! % i F" r~ I 13. Stimulation or cement squeeze summary K I' I,. I: I'V E IJ I 14. Intervals treated(measured) ~'~A¥ 1 5 1992 Treatment description including volumes used and final pressure Alaska 0il & Gas Cons. C0[~sSt~t~ Representative Daily Average Production or Injection Data j~Cll01'ag~ Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure SI for RWO 10072 3100# 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~,~ ~, (~~'~'"~r~-----"~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Daily Report of Operations DS 12-19 12/31/91 Commenced MI injection following RWO to replace tubing. WAG conversion complete. RECEIVED MAY 1 5 199~ Alaska Oil & Gas Cons. Commission An~florag~ ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-27-92 REFERENCE: ARCO CASED HOLE FINALS 3-15 ?~- f~2-92 Spinner/Temp/Press * 3-34 ~/z-~2 4-3-92 Vertflog 4-30 2~'-~ 4-12-92 Tu--in~ Cutter 7-7A ~-~-~ 4-10-92 pert'~~ 9-3 4-18-92 Co!!ar/Perf ** 0-30ST 3-30-92 PFC/GR ~o._gy 12-9 3-28-92 Ped ~,ecoc£ ~z../io~ ( 12-19 4-19-92 12-19 4-19-92 ?g~r/ 14-2 4-9-92 R~_m 1, 5" R"'~ 1, 5" R,m 1, 5" Run 1, 5" Run 1, 5" Run 1, 5" Collar tie-in to Jewelry Run 1, 5" Collar/Peri Run 1, 5" Perf (Post°Squeeze) Run 1, 5" Please sign ~-d return the attached copy as receipt of data. RECEIVED BY~.~_~ Have A Nice Day~. R [,,, C ~ I Vic3 c~ ?-~ D ~ ~n~ W~, ~y 11 APPROVED__ ATO-1529 ~S~ ~~5 ~ Alaska 0~l ~ ~a9 Cons. Commissio~ Anchorage ~ ~~ON ~ ~ON ~~~ON ~ ~0~ Sch Atlas Atlas Sch At. ks Atlas Sch Atlas Sch PBW~~ R&D # BPX # STATE OF ALASKA TF.,XAC, O * The correct well name is 3-34. ** The correct APl# for 9-30ST is 50-029-21411. ----.. STATE OF ALASKA ~ ALASKA ' AND GAS CONSERVATION CC~-~'JlISSION 0 ~ I 6 I. APPLICA, ION FOR SUNDRY APr'ROVALS 1. Type of Request: Abandon Suspend Alter casing Repair well Change approved program 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 == 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, T10N, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, T10N, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC. 07, T10N, R15E Operation shutdown Plugging , Pull tubing Variance 5. Type of Well Development Exploratory Stratigraphic Service X RECEIVED APR - 2 t992 Alaska 0ii & Gas Cons, c0mm'~ss~0t~ -Anchorage Re-enter suspended well Time extension Stimulate Perforate X Other 6. Datum of elevation(DF or KB) KBE = 77' feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 12-19 9. Permit number 82-198 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Field/Oil Pool 12. Present well condition summary Total depth: measured true vertical 11930' feet Plugs(measured) 9218' feet Effective depth: measured 11877' feet true vertical 9179' feet Casing Length Size Structural Conductor 79' 20" Sudace 2429' 13-3/8" Intermediate Production 11191' 9-5/8" Liner 1033' 7" Perforation depth: measured 11649'-11689' Junk(measured) Cemented 1850 SX 1800 SX & 400 SX Measured depth 79' 2429' true vertical 9013'-9042' True vertical depth BKB 79' 2429' 505 sx & 300 sx 11191' 8677' 350 sx 10887'-11549' 8464'-9210' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 10795' & 4-1/2" L-80 @ 11634' Packers and SSSV (type and measured depth) Baker SAB Packer @ 10821' MD, SSSV @ 2211' MD; Otis 7" 'BWD' packer at 11620' MD, Packer at 10796' MD, SSSV at 2199' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch 14. Estimated date for commencing operation Apdl 9, 1992 16. If proposal was verbally approved Oil Name of approver Date approved Service Signed17. I hereby~certify that th,~fore(.,,/. ~is true and correct to theTitlebeSt of my knowledge. · /-/ Noti([.~/Commissior 15. Status of well classification as: Gas Suspended Injector Senior Engineer FOR COMMISRI{3N URE ONLY Date ,~//~.A ~ Conditions of approval: 1 so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY LONNIE C_ S~;~ITH Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 RW/.IWP/DR Fnnr_ SUBMIT IN TRIPLICATE DS 12-19 Description of Proposed Work AP1 #50-029-20870 Permit #82-198 Below are the intervals we are proposing to perforate within the Sadlerochit formation. · 11392'-11452' MD (60' at 4 SPF) °11465'-11505' MD (40' at 4 SPF) (Depths reference 12/17/82 BHCS) Alaska Oil & Gas Gons. Oornm~ss~°~" Anchorage 4 2 4. SO00 I~ 4 1/t- ri. ow TUll: P~CX-~ff' RECEIVED APR - 2 199[~ Alask~ Oil & Gas Cons. Anchorage STATE OF ALASKA ALA~,,,A OIL AND GAS CONSERVATION COMMISSI,.,,,~ ~ ! ~ ,'~.' ~'~~ REPORT OF SUNDRY WELL OPERATI0 i 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing. Repair well Perforate Other X WORKOVER 2. Name of Operator ARCO Alaska, inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 572' FSL, 934' FEL, SEC. 18, TION, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, TION, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC. 07, TION, R15E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 79' Surface 2429' Intermediate Production 11191' Liner 1033' 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE = 77'feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number DS 12-19 9. Permit number/approval number 82-198 / 91-355 10. APl number 50- 029-20870 11. Field/Pool Prudhoe Bay Field~Oil Pool 11930' feet Plugs (measured) 9218' feet BKB 11848' feet Junk (measured) 9158' feet BKB Size Cemented 20" 1850 SX 13-3/8" 1800 SX & 400 SX 9-5/8" 505 sx & 300 sx 7" 350 sx Measured depth 79' 2429' 11191' 10887'-11549' True vertical depth BKB 79' 2429' 8677' 8464'-9210' Perforation depth: measured 11649'- 11669' true vertical 9011'-9026' Tubing (size, grade, and measured depth) 5-1/2"L-80 @ 10795'& 4-1/2"L-80 @ 11634' Packers and SSSV (type and measured depth) RECEIVED JAN 2 ? 3992 Alaska 011 & Gas Cons. u0mmlss~'°~ Anchorage A VA "PPH" Packer @ 10796' & Otis "WD" Packer @ 11620'; Camco "BaI-O" SSS V @ 2199' 13. Stimulation or cement squeeze summary See Attached Activity Summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Water In. iector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-.._ ~3. ~ Title WorkovorSuporintondent Form 10-404 Rev 06/15/88 Date I SUBMIT IN DUPLICATE ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 12-19I NABORS 3S KILL: 7.5 NDNU: 3.5 OTHR: 13.0 11/21/91 ( 2) MOVING RIG MW: 8.5 Seawater TD:11930 MOVING RIG TO DS12-19. PULL BPV, RU CIRC LINES. PUMP S/WATER PB:11877 DWN TBG. KILL KILL WELL. INSTL BPV, ND TREE, REMOVE TREE SUPV:LP F/CELLAR, Nil BOPE. DAILY:S16,247 CUM:$16,247 ETD:SO EFC:$1,204,247 NDNU: 1.5 PTBG: 17.0 OTHR: 5.5 11/22/91 ( 3) LAY DOWN TBG MW: 8.5 Seawater TD:l1930 NU BOPE RU TO TEST BOPE, BLIND RAMS. FILL HOLE, INTSL LNDG PB:11877 JT. LD LNDG JT, RU PWR TONGS & STBG BOARD, PU JT OF DP. SUPV:LP SPEAR TNG HGR, PULL FREE, RELEASE & LD SPEAR & TBG HGR. CO ELEVATORS, RD STBG BOARD, LD TBG, SSSV. DAILY:S34,008 CUM:$50,255 ETD:S34,008 EFC:$1,204,247 PTBG: 3.0 PPBR: 6.5 OTHR: 14.5 11/23/91 ( 4) P/U DP MW: 8.5 Seawater TD:l1930 POOH LD TBG. R/U, REPAIRD OR CHG OUT HCR VALVE, 2 PRESS PB:11877 TRANSMTR, TRNSMT HOSE. THAWED FROZEN CHOKE LINE. INSTL WEAR SUPV:LP RING. RIH W/BHA PU DP. DAILY:S20,387 CUM:$70,642 ETD:S54,395 EFC:$1,204,247 PPBR: 20.5 OTHR: 3.5 11/24/91 ( 5) POOH W/PBR MW: 8.5 Seawater TD:l1930 RIH W/SPEAR PU DP. PI KELLY TEST BOP. POOH W/FISH, RECOVERED PB:11877 SEAL ASSY. B/O & LD FISH, MU PBR RET TOOL, SERVICE RIG. RIH SUPV:LP W/BHA, CUT DRILL LINE. POOH. DAILY:S20,387 CUM:$91,029 ETD:S74,782 EFC:$1,204,247 PPKR: 24.0 11/25/91 ( 6) TD:l1930 PB:11877 SUPV:LP POOH W/PKR MW: 8.5 Seawater POOH W/PBR & K-ANCHOR. LD FISH, RU STRAP & BHA & ROTATE SHOE. SERV RIG. PU KELLY, TAG PKR @ 10801' MILL. CBU, SOME GAS. MONITOR, BLOW DN & SB KELLY. POOH W/FISH. DAILY:S29,822 CUM:$120,851 ETD:S104,604 EFC:$1,204,247 PPKR: 5.5 COUT: 16.5 OTHR: 2.0 11/26/91 ( 7) POOH W/MILL MW: 8.5 Seawater TD:l1930 POOH W/PKR, PULL WEAR RING W/PKR. BD & LD SPEAR, PKR, & PB:11877 ASSY. MU RUN TOOL & INSTL RING. RUN DCS IN HOL, POOH LDDC. SUPV:LP RIH TO 10886'. PU KELLY, WASH & CLN OUT TO 11641'. CIRC TO CLN HOLE. POOH WET W/PLUGGED MILL. DAILY:S42,024 CUM:$162,875 ETD:S146,628 EFC:$1,204,247 COUT: 24.0 11/27/91 ( 8) TD:l1930 PB:11877 SUPV:LP POH W/6" MILL MW: 8.5 Seawater POH LAST 5 JTS DRL CLRS PLUGGED W/ ASPH SCALE. CLEAN OUT PLUGGED PIPE, RIH W/BHA TO 11,609. WASH TO 11796'. CIRC HOLE CLEAN. POH. DAILY:S21,913 CUM:$184,788 ETD:S168,541 EFC:$1,204,247 RECEIVED JAN 2 T 992 Alaska Oil & Gas Cons. Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 12-19I NABORS 3S COUT: 20.0 TCSG: 4.0 11/28/91 ( 9) RIH W/TEST PACKER MW: 8.5 Seawater TD:l1930 SLIP AND CUT DRILLING LINE. RIH W/7" SCRAPERS TO 11796 & PB:11877 9-5/8" SCRAPER TO LINER TOP @10887'. SUPV:CB DAILY:S34,817 CUM:$219,605 ETD:S203,358 EFC:$1,204,247 TCSG: 10.0 LPRF: 4.5 11/29/91 (10) TD:l1930 PB:11877 SUPV:CB OTHR: 9.5 R/D ATLAS LOGGING UNIT MW: 8.5 Seawater SET 7" TEST PACKER TO 11309'. TEST ANNULUS TO 3500 PSI, PUMP DOWN DP EST INJECTION RATE TO FORMATION @ 3 BPM, 800 PSI. RELEASE PACKER, POH. RIH WITH 7" VERTILOG, LOG UP FROM TOP OF PERFS @11300'- TO TOL @ 10887'. POH. RIH W/9-5/8" VERTILOG. LOG FROM SURFACE TO TOL. R/D ATLAS. DAILY:S20,387 CUM:$239,992 ETD:S223,745 EFC:$1,204,247 SQZ : 24.0 11/30/91 (11) TD:l1930 PB:11877 SUPV:CB RIH W/6" BIT MW: 8.5 Seawater ATTEMPTED CEMENT SQUEEZE. SQUEEZE UNSUCCESSFUL. POH, L/D 2-7/8" TBG. RIH W/3-1/2" DRILL PIPE. DAILY:S69,170 CUM:$309,162 ETD:S292,915 EFC:$1,204,247 SQZ : 3.0 OTHR: 21.0 12/01/91 (12) RIH FOR RESQUEEZE MW: 8.5 Seawater TD:l1930 RIH W/6" BIT. DRILL OUT CEMENT STRINGERS TO 11355' FIRM TO PB:11877 11370'. DISPLACE WELL TO BRINE. POH AND L/D DRILL COLLARS. SUPV:CB RIH W/2-7/8" TBG FOR RESQUEEZE DAILY:S62,744 CUM:$371,906 ETD:S355,659 EFC:$1,204,247 SQZ : 15.5 OTHR: 8.5 12/02/91 (13) DRILL OUT SQUZ CEMENT MW: 8.5 Seawater TD:l1930 RESQUEEZE PERFORATIONS. POH, L/D 2-7/8" TBG. RIH W/8-1/2" PB:11877 BIT & BHA. TAG CEMENT STRINGERS @10453'. WASH OUT SUPV:CB STRINGERS, TAG SOLID CEMENT @10648' IN 9-5/8" CASING, DRILLING OUT. DAILY:S56,421 CUM:$428,327 ETD:S412,080 EFC:$1,204,247 COUT: 24.0 12/03/91 ( 14) TD:l1930 PB:11877 SUPV:CB DRILLING OUT SQZ CMT MW: 8.5 Seawater DRILL OUT CMT TO 10759'. CIRC OUT CUTTINGS. POH, RIH W/NEW 8.5" BIT. DRILL OUT CMT IN 9-5/8" CSG TO 10887'. NOTE: EFC RAISED DUE TO RE-SQUEEZE. DAILY:S22,312 CUM:$450,639 ETD:S216,639 EFC:$1,422,000 RECEIVED JAN ~ ? '~992 Oil & Gas Cons. Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 12-19I NABORS 3S SQZ : 24.0 12/04/91 ( 15) TD:11930 PB:11877 SUPV:CB DRILLING OUT CMT MW: 8.5 Seawater CIRC TOL TO CLEAN, PUMPED SWEEPS. POH, LD DRILL CLRS. RIH W/BHA TO 10887'. DRILLED HARD DMT TO 11160'. DAILY:S25,337 CUM:$475,976 ETD:S241,976 EFC:$1,422,000 SQZ : 21.0 PROB: 3.0 PROB CODE: EFC 12/05/91 (16) RIH MW: 8.5 Seawater TD:11930 DRLD CMT TO 11710'. TEST PERFS. PUMPED SWEEP @ TOL. POH, PB:11877 WORKED ON PUMP. RIH. NOTE: EFC RAISED BECAUSE OF THIRD SUPV:CB RE-SQUEEZE. DAILY:S22,887 CUM:$498,863 ETD:S36,863 EFC:$1,650,000 SQZ : 24.0 12/06/91 (17) TD:l1930 PB:11877 SUPV:CB PERF SQZ #3 MW: 8.5 Seawater CIRC HOLE CLEAN. TEST PERFS, POH. RIH W/MULE SHOE. RIH W/BHA TO 11710. DAILY:S58,153 CUM:$557,016 ETD:S95,016 EFC:$1,650,000 SQZ : 24.0 12/07/91 (18) TD:l1930 PB:11877 SUPV:CB RIH W/BHA #14 MW: 8.5 Seawater SQZ #3. RIH TO 11710' & SET BALANCE PLUG. BLED PRESS OFF. STUCK WHILE POH. CIRC. POH. PULLED & SERVICE WEAR RINGS. INSTLD TEST PLUG. RIH W/BHA #14. DAILY:S76,740 CUM:$633,756 ETD:S152,734 EFC:$1,669,022 SQZ : 23.0 PROB: 1.0 PROB CODE: EFC 12/08/91 (19) POOH W/BHA #14 MW: 8.5 Seawater TD:l1930 CONT RIH W/BHA #14, TAGGED CMT @ 9358'. DRLD CMT TO 10887'. PB:11877 CIRC TOL TO RID OF LEAKING NITROGEN. FIXED LEAK ON SKATE. SUPV:CB CONT TO POH TO DRILL COLLARS. DAILY:S43,009 CUM:$676,765 ETD:S195,743 EFC:$1,669,022 SQZ : 24.0 12/09/91 ( 20) TD:l1930 PB:11877 SUPV:CB DRILLING CMT MW: 8.5 Seawater CONT LD BHA #14. PU 6" BIT, PU BHA #15. RIH TAGGED CMT @ 10948'. DRILLED CMT 11459'. TESTED PERFS. DRLD CMT 11730'. DAILY:S24,094 CUM:$700,859 ETD:S288,859 EFC:$1,600,000 SQZ : 15.5 RPKR: 8.5 12/10/91 (21) DISPL HOLE W/CLEAN SW MW: 8.5 Seawater TD:l1930 DRLD, CLEAND OUT FILL TO 11848'. TESTED PERFS. CBU TO CLEAN PB:11877 HOLE. POH. RIH W/BHA #16, SERVICED BLOKS/CROWN. CONT TO RIH SUPV:CB TO 11817'. WASH DOWN TO 11848', DISPL FLUID TO CLEAN SW. DAILY:S23,247 CUM:$724,106 ETD:S312,106 EFC:$1,600,000 RECEIVED JAN ~ ? ~9~ Alaska Oil & Gas Cons. CommtSSt{m Anchorage ACTIVITY SUMMARY BP/AAI SHARED SERVICE NORTH SLOPE AK PRUDHOE BAY DS 12-19I NABORS 3S RPKR: 17.0 LPRF: 6.0 OTHR: 1.0 12/11/91 (22) TIE IN WIRELINE PERF GUN MW: 8.5 Seawater TD:l1930 CONT DISPL HOLE TO FILTERED SW. CIRC HOLE UNTIL CLEAN. POH PB:11877 W/SCRAPERS & BHA RU WIRELINE. PULL FLOW NIPPLE. ND/NU SUPV:CB SHOOTING FLANGE & LUB. RIH W/4" 20 FT PERF GUN. TIE INTO CBL REF BHCS. DAILY:S28,394 CUM:$752,500 ETD:S340,500 EFC:$1,600,000 RPKR: 18.5 LPRF: 4.5 OTHR: 1.0 12/12/91 (23) CIRC WELL TO INHIBTD SW MW: 8.5 Seawater TD:l1930 FIRE 20' PER GUN, POH. MU & RIH W/GUN #2. TIE IN & PERF TO PB:11877 11669', POH. RIH TO 11244' TAG UP, POH. ND SHOOTING FLANGE. SUPV:CB SERV RIG. RU & RIH TO 11620'. DROP BALL & SET TOP OF PKR. SHRT TO TOL, REV CIRC INHIBITED BRINE. DAILY:S84,229 CUM:$836,729 ETD:S424,729 EFC:$1,600,000 RPKR: 11.0 RCMP: 13.0 12/13/91 (24) RIH W/5-1/2" COMPLETION MW: 8.5 Seawater TD:11930 CONT REV CIRC WELL TO INHIBITED SW. POH LDDP & RUNNING TOOL. PB:11877 RIH 5-1/2" TBG. SUPV:CB DAILY:S45,910 CUM:$882,639 ETD:S470,639 EFC:$1,600,000 NDNU: 4.5 RCMP: 17.0 PROB: 2.5 PROB CODE: EFS 12/14/91 (25) SET PKR. MW: 8.5 Seawater TD:l1930 RIH W/ COMP. M/U TBG HGR. LAND TBG. TEST HGR. N/D BOPE. PB:11877 N/U TREE. TEST TREE. DISP W/ 154 BBLS DIESEL. R/U TO SET SUPV:CB PKR. DAILY:S357,689 CUM:$1,240,328 ETD:S828,328 EFC:$1,600,000 NDNU: 2.0 12/15/91 ( 26) TD:l1930 PB:11877 SUPV:CB RIG RELEASE @ 08:00 HRS. MW: 8.5 Seawater SET PKR. TEST TBG, ANNULUS. BLEED PRESSURE. CLOSE TREE VALVES. SECURE WELL. RIG RELEASED @ 08:00 HRS, 12/14/91. DAILY:S17,859 CUM:$1,258,187 ETD:S1,188,000 EFC:$1,258,187 RECEIVED JAN 2 T 992 Alaska 0ii & Gas Cons. Anchorage ARCO ALA3.'KA.. INC. -F'. O. BOX ANUHORAGE, ALA~'KA 99Si 0. DATE- ~ 2-3t -94 REFERENCE- ARCO CAs'E~OLE FINAL~ ~ f4-46, t2-8-9t ¢/ COMPLETION RECORD ~ ~2-s-?~ ~ C~T ~2-8-9~ ~ U~IT ~~6-8 ~2-7-9~~ PDK-~ ~/GR/CCL -, '-/~'~¢7-9 t2-i 3-9' ~ COLLA~-~'bh;h -~t2-t9 i2-i¢-9t J COLLAR-PERF ¢~__~ tS-2SA t2-i4 9t ¢ COLLAR-PERF ~ i 4-et ¢ COLLAR-FERF PLEASE SZCW AW~ RETU~ THE ATTACHED RECEIVED BY HAVE A NICE DAY! £ONYA WALLACE AT0-t529 (COLOR) (COLOR) (COLOR) RUN t, ..,.~'" I;:UN t, 5:' RUN i., 5' RUN i , 5 · RUN 1, 2." RUN 1, .5" RUN i , 5" RUN i, 5' RUN t , 5" COPY AS RECE£F'T OF DATA, $CI--I SCH £'CF! AYLA~ Ai'LA$ A'i'LA~ A TLA.S' A [LA~' A';'LA~' DISTRIBUTION ~ CENTRAL FILES ~ CHEVRON D & M -,- EY. TEN$ION EXPLORATION -,,-'" EXXON NARATHON · ~ MOBIL PHILLIPS PB WELL FILES R & D BPX ~'rATE OF ALASKA TEXACO RECEIVED JAN ~ 0 1992 ,",;as~:a Oil & Gas Cons. Commission Anchorage ARCO ALASKA, INC. F'.O. BOX ANCHORAGE, ALASKA 995i0 DATE' i2-iS-gi KEFERENCE' ARCO CASED HOLE FINALS ~ C," ~_~t'-Si 7-i 8-9i DSN q I~, ~~-Z8 i 0-2Z-9i PERF RFCORD q~'l~.=-Z9 t t-tg-gt .ULTRASONIC IM~qGER (COLOR) ~~~ i~-i9-9t COLLAR FOR TUBING CUTTER ~~i9 tt-28-9t DIFFEREN[IAL I'EMF'ERAYURE ~~t9 i i-28-9i VER. TILOG (7') tt-29-9i VERTILOG (9 5/8') ~ i ~-2i-9i PERF .LOG RUN 1, 5 4. RUN i , 5' ' RUN 2, 5' RUN ~, 5' RUN i ,. 5' RUN i, 5' RUN i, 5" RUN t , 5' RUN i', '5: HLS HLS HL~' SCH HLS AFLAS ATLAS A'¥LAS HLS P. LEASE SIGN AND RETURN THE ATTACHED coF'Y.AS RECEIF'T OF DATA~ SON';'A WALLACE . . - /~~~F:OVED ~Y./~i~/I"~ ATO-t 529 '' ' . ~o~a~m ~ CEN i'RAL FILES ~ PHILLIPS = CHEVRON PB WELL FILES D & M .. EXTENSION EXPLORATION ~ BF'X ~ EXXON NARAI'HON TEXACO ~ MOBIL ARCO ALASKA, INC, -~-~. F'.O. BOX t08S68 ANCHORAGE, ALASKA 995t~ DATE' ~ 2-~ S-9~ REFERENCE' ARCO CASED HOLE FINALS t~-8-9~ PERF' RECORD RUN ~, 5' ~2-S-9~ COLLAR-PERF RUN ~, 5' '~9 ~-~7-9~ TUBING COLLAR/JET CUTTER RUN ~, 5' ~~~--t~ t ti-t2-9i COLLAR (AVA TUBIN6 PATCH) RUN t, 5' t2-6-9t PFC RUN t, 5' PLEASE SIGN AND RETURN THE AT I'ACHED COPY A~ RECEIF'T OF DATA, I.'11...~; A"I'LA3' FILS' HI..,? H/..~' ATLA£' HL~' RECEIVED BY'- HAVE A NICE DAY! ~ONYA WALL. ACE AT0-~529 RECEIVED AF'F:'F;,'OVE~D ~ i 't' R A N;NI~$~ ~ ~'s Cons. Commiss on Anchorage DIS'TRIBUTION CENTRAL FILES CHEVRON D&M EXTENSION EXPL. ORATION EXXON MARATHON MOBIL · ~ F'HILLIF'$ F'B WELL F:'IL.E:S' R & D -,- BF'X .S'TAi'E OF' ALA:~'KA TEXACO STATE OF ALASKA ¢----,, o,. ^ND OONSE.VAT,ON OOMM,SS,O .ri R I fi I APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend __ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well Plugging __ Time extension ~ Stimulate ~ Change approved program Pull tubing X Variance Perforate x Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development__ Exploratory __ Su'afigraphic__ Service x 6. Datum elevation (DF or KB) KBE = 77' feet 7. Unit or Property name Prudhoe Bay Unit 4. Location of well at surface 8. 572' FSL, 934' FEL, SEC. 18, TION, R15E At top of productive interval 55' FNL, 4552' FEL, SEC. 18, TION, R15E At effective depth At total depth 323' FSL, 4716' FEL, SEC. 07, TION, R15E 12. Present well condition summary Total depth: Well number DS 12-19 9. Permit number 82-198 10. APl number 50- 029-20870 11. Field/Pool Prudhoe Bay Field/Oil Pool measured true vertical 11930' feet Plugs (measured) 9218' feet BKB Effective depth: measured true vertical 11877' feet Junk (measured) 9179' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth BKB 79' 20" 1850 SX 79' 79' 2429' 13-3/8" 1800 SX & 400 SX 2429' 2429' Tubing (size, grade, and measured depth) 5-1/2" 17# L-80 @ 110918'MD Packers and SSSV (type and measured depth) Baker SAB Packer @10821' MD, SSSV @ 2211'MD 11191' 9-5/8" 505 sx & 300 sx 11191' 8677' 1033' 7" 350 sx 10887'- 11549' 8464'-9210' measured 11328'-11347', 11352'-11432', 11431'-11451', 11464'-11499', 11509'-11549', 11559'-11584' true vertical 8776;8963' RECEiV1FL'D N OV 0 1991 Alaska Oil & Gas Cons. Com~'ts~ Anchorage 13. Attachments Description summary of proposal x Detailed operations program BOP sketch x 14. Estimated date for commencing operation November 17, 1991 16. If proposal was verbally approved Oil__ Gas ~ Name of approve~ie ~lmith 11-15-91 Date approved Service Water Injector 17. I her, ffby c~~ ~/fore<~oing is true and/(~orrecyto the best,of my ~owledcj~e. ~ Signed ~. ~-~, ~'~..z~/', /f/~' Titl~[~o~r"Supo~lf~n, - ' FOR COMMISSION USE ONLY 15. Status of well classification as: Suspended Conditions of approval: Notify Commission so representative may witness I Approval Plug integrity__ BOP Test Location clearance /~pprowci (_~:c.,f_~y Mechanical Integrity TestT~,' Su--'~bsequent form required 10- ~/"/'H~.:~.-.,--'-':~'~"i';-'-~'d,~. ORIGINAL SIGNED BY II- ~, ti' Approved by order of the Commission LONNIE C. SMITH Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DS 12-19 WORKOVER OPERATIONS SUMMARY Well D~ 12-19 Attachment #1 OBJECTIVES: Removal of the existing 5-1/2" completion assembly, milling/retrieval of the BROWN 9-5/8" x 5-1/2" SAB packer, cleanout to PBTD, testing casing, running a VERTILOG, squeezing perforations, cleaning out, repedorating, setting packers on E-line, and recompleting the well with a 5-1/2", L-80, IPC completion string. RIG O 1. 2. 3. 4. 5. 6. 7. 8. 10. 11. 12. 15. 16. 13. 14. 17. 18. 19. 20. 21. 22. PERATIQNS MIRU. PULL BPV KILL WELL ND/NU/TEST BOPE PULL TUBING RETRIEVE SEAL ASSEMBLY (PU DP) RETRIEVE PBR MILL/RETRIEVE PACKER SCRAPER RUN/CLEANOUT (PU COLLARS) RUN VERTILOGS SQUEEZE PERFORATIONS CLEANOUT/TEST DISPLACE WE/! RORE POOH LDDP GR/CCL/PERFORATE SET PACKERS ON E-LINE RUN 5-1/2" COMPLETION ASS'Y LAND TUBING/SPACEOUT FREEZE PROTECT/RELAND TUBING ND/NU. TEST TREE TEST TUBING/CASING. SECURE WELL. RELEASE RIG RECEIVED NOV 2 0 199~ AJaska OJJ & Gas Cons. Cornmissio~'~ Anchora.qe BOP STACK CONFIGURATION ATTACHMENT II 13 5/8", 5000 PSI WP TRI PLE RAM STACK WORKO VER I RISER ANNULAR PREVENTER I I I 2" KILL LINE MANUAL HYDRAULIC GATE GATE ! I PI PE RAMS I DRILLING SPOOL I BLIND RAMS I 4" CHOKE LINE HYDRAULIC MANUAL GATE RECEIV[ D NOV 2 0 199' Alaska 0ii & f~as Cons. C~ nmissioi~ Anchora.q~ M(.,E ALASI< A '.'f;" ", ANCHOR ^ ' , ,0 DATE' t t-8---9 t REFERENCE: ARCO CASED HOLE FINALS 0-i6'-9t INJ PROFILE ()-t 7-9i INJ F'ROI--II_E 0,-i6-9i PROD F'ROFIL_EE ;3-t7-9t PROD F'ROFII._E ~}-9-9i ]'EbiF'ERATURE '~-9-9i GR-CCL ¢, -- 6 - 9 i F' F"' C HAVE A i'-~,~ DAY! ,'-.) -.5. - 9 i C i"] L L A R---F:'E F: F- ¢,-ii-gi LEAK DETECT ~-ii-gt INJ PROFILE (-)-ii-gl INJ PROFILE (:.').-i 3-9t (;AS LiFT (~'-5- 9 i COLLAR-PERF ~-t~-?t LEAK DETEC'F ~N9 RETURN THE ATTACHEI) $[)NYA WAL_L. ACE ATO-i 529 RUN t, 5' CAMCO RUN t, ~ l (] A i-~ C (_') RUN t, 5' CAHCO F;UN i, 5' CAi'iCi] RUN t, 5' CAMCO RUN i, 5' CAM(]O RUN i, 5' ATLAS RUN ~, 5' Al'LAS RUN i, 2'&5' CAMCO RUN t, 5' CAMCO RUN i, 5' CAMCO RUN i, 5' CAMCO RUN i , 5' Al'LAS RUN i, 5'&iO' CAMCO COF'Y A3; RIEC:EII::'T OF: DATA, A F' F' R 0 V El D~.. ~/~ x~''''' ~ 'I'RAN S ~- 9/S59 DI£TRIBUTION ~ CENTI;:AL FILES ~- F'HILLIF'S ~--~ CHEVRFiN_ F'B WELL FILES D & iq R & D :'~ EXTENSION EXF'L[iRAT I rlN ~: BPX · $ EXXON .$ 'STATE OF. ALASKA HARAI'HON TEXACO ' MOBIL 'Ii' * ]"HE CORRECI' I)S STATE OF ALASKA ' ALASKA' 'L AND GAS CONSERVATION CC. .vllSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: - Abandon Suspend ~ Operal~on shutdown Alter casing Repair well Plugging Change approved program Pull tubing Re-enter suspended well , Time extension Sl~mulate Variance Perforate 2. Name of Operator 5. Type of Well ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM Development Exploratory Stratigraphic Service X At top of productive interval At effective depth At total depth ~i~k~. OJJ & Gas Co~,s. CorfttT~ss~o~ 323' FSL, 4716' FWL, Sec. 7, TION, R15E, Annhnrn_~' 12. Present well condition summary Total depth: measured 11930 feet Plugs(measured) true vertical 9218 feet Other X 6. Datum of elevation(DF or KB) 77' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 12-19i 9. Permit number 82-198 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 11877 feet true vertical 9179 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 79' 20" 1850 # Ploeset cmt 79' 79' Surface 2352' 13-3/8" 1800 sx Fondu & 400 sx PF "C" 2429' 2429' Production 11114' 9-5/8" 505 sx CI 'G',300 sx PF "C" 11191' 8677' Liner 1033' 7" 350 sx CI 'G' 11920' 9210' Perforation depth: measured 11328'-11347';11352'-11452';11465'-11500';11510'-11550';11560'-11585' true vertical 8776'-8790';8794'-8866';8876'-8901';8908'-8938';8945'-8964' Tubing (size, grade, and measured depth) 5-1/2",17 #,L-80,PCT @ 10833'md; 4-1/2",12.6 #,L-80, PCT w/tail @ 10917'md Packers and SSSV (type and measured depth) Be-'.ker "SAB" pkr @ 10821'md, Camco BaI-O SSSV @ 2210'md 13. Attachments 14. Estimated date for commencing operation September 1991 16. If proposal was verbally approved Name of approver Description summary of proposal X Detailed operations program I 15. Status of well classification as: Oil Gas Suspended Date approved Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~', ~ ~ Title Sr. Area Operations Engineer FOR COMMISSION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY ~!S,q,F. LL A, DOUGLAS"~ BOP sketch Date Approval No. d.~//....,~,~..? I SUBMIT IN TRIPLICATE c: SW DS 12-19i Summary of Proposed operations API 50_029-20870-00 Permit # 82o198 er Produced Water Injection to Water- from Seawa. t / iection Service Conversion Alternating-Gas 1} Locate source of tubing/casing communication- Patch tubing as necessary. 21 Conduct Mechanical Integrity Test of tubing/casing annulus. 3) Test surface flowline and valves. 4) Commence Miscible Gas, Alternating with Water on or about October 15, 1991 ff M.I.T. passed Note: This well is part of the planned expansion of the Prudhoe Bay Miscible Gas Project (PBMGP). R Alaska Oil a (:;as Cons. Cummissio' Ancho~'a[~a _ - STATE OF ALASKA ALASKA ¢ AND GAS CONSERVATION COt '.SSION APPLICA'I ,ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon , Suspend Operation shutdown Alter casing Repair well Plugging Change approved program , Pull tubing Re-enter suspended well Time extension Stimulate Variance Perforate 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphio Service 4. Location of well at surface 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM At effective depth At total depth 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM Other X 6. Datum of elevation(DF or KB) 77' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 12-19 9. Permit number 82-198 10. APl number 50 - 029-20870 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 11930' feet 9218' feet Effective depth: = measured 11877' feet true vertical 9179' feet Length Size Plugs(measured) None RE(~EIV~P JUl_ '1 ?_. ~;.-,¢.,~, Junk(measured) NOn~la. ska Oil & Gas Cons. Corem~,ssi°~ Cemented Measu~til~[i~ll~ True vertical depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 79' 20" 1850 # Poleset cmt 79' 79' 2352' 13-3/8" 1800 sx Fondu & 400 sx PFC 2429' 2429' 11114' 9-5/8" 505 sx Class G & 300 sx PFC 11191' 8677' 1033' 7" 350 sx Class G 10887 - 11920' 8476' - 9210' measured 11328' - 11347', 11352' - 11452', 11465' - 11500', 11510' - 11550', 11560' - 11585' true vertical 8776' - 8790', 8794' - 8866', 8876' - 8901', 8908' - 8938', 8945' - 8964' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PeT @ 10833' MD; 4-1/2", 12.6#, L-80, PCT w/tail @ 10917' MD Packers and SSSV (type and measured depth) Baker "SAB" pkr @ 10821' MD, Camco BAL-O SSSV@ 2210' MD 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation Continue on H20 injection till July 20, 1991 Detailed operations program 15. Status of well classification as: BOP sketch 16. If proposal was verbally approved Blaire Wondzell 7/3/91 Name of approver Date approved Service 7. I~y that the f, pr~fiing~ true and correct to the best ~ ,/ (L/ //~. Signe ..~~~ Title FOR COMMISSION LI~E ONLY ~ C~s of ~proval: Notify Commission ~ representative may witne~ Plug integrity . BOP Test Lo~tion clearance Mechanical Integrity Test Subsequent form required 10- ~' Oil Gas ,= Suspended Water Injector of my knowledge, Operations Superintendent Date IApproval No. ~/-- ,~./~ /, Approved by order of the Commissioner ._,,~c~ ~5'~ Form 10-403 Rev 06/15/88 t3~t~l~' '" e~ W. J. Q Brien PRB-24 659-5102 Commissioner SUBMIT/IN T~PLICATE Approved Copy ~Retu.~ned '~ 117 !~// DS 12-19 Annular Communication Evaluation Action Plan Discl~s~ion Tubing X 9-5/8" communication is suspected. Well failed a Mechanical Integrity Test to 2000 psi on the tubing x 9-5/8" annulus; lost 240 psi in 30 minutes. Liquid leak rate was measured at 6 gpm at 2400 psi down the 9-5/8 annulus. The following evaluation plan is proposed: Plan 1. Keep well on seawater injection (SWI) only. 2. Install a standing valve in the tubing tail. 3. Perform a spinner/temperature log to locate the source of the tubing x 9-5/8 communication. RECEIVED ! Alaska Oil & Gas Cons. Commission Anchorage INJECTION WELL ANNULAR COMMUNICATION VERBAL NOTIFICATION OF AOGCC PER AREA INJECTION ORDER #4 DATE: TIME: NOTIFIED BY: AOGCC CONTACT: ~REASON: Injection Well /.~-/'~ Annular Communication per Rule 7 Requirements of Area Injection Order.No. 4 AOGCC RESPONSE: Sundry Notice Req'd at this time? YES f NO SIGNED: ~~--,--- ~_~ ~ ~P~iDUCTION SUPPORT SUPT. cc: DSSupv. Sr. Well Supv. FS Supt. Field Area Ops. Engr. Annular Comm. Spec. Verbal No t.-A OGCC ANNULAR COMMUNICATION TEST MECHANICAL INTEGRITY TEST WELL# TYPE OF TEST: SPECIAL INSTRUCTIONS' INITIAL PRESSURE DATA TIME: I000 HRS (ARRIVAL ON LOC.) TBG L]Z0 PSI 9-5/8" SSSV CONTROL/BALANCE LINES TBG HNGR TEST PORT CAVITY: FLUID BLED: 9-5/8" TEST PORT CAVITY: FLUID BLED: WELL STATUS: FLOWING / INJECTING / SHUT IN %-~O PSI 13-3/8" ~--~--' PSI BLED TO 0 PSI? PSI YES/NO PSI BLED TO 0 PSI? ~ PRE-TEST; ~REP~ARA~IONS TBG BLED F/ ~'- PS! TO ~-- 'PSI TYPE OF FLUID AND VOLUME BLED: TUBING LOADED-WI ~----'-BBLS CRUDE + BBLS DIESEL 9-5/8" ANNULUS BLED F/ ~-------~-Sl TO PSI TYPE OF FLUID AND VOLUME BLED: . 9-5/8" LOADED W/ ' BBLS CRUDE + BBLS DIESEL 13-3/8" ANNULUS BLED F/ ~ PSI TO '--" ........ PSI TYPE OF FLUID AND ',/OLUME BLED' .- 13-3/8" LOADED W/ BBLS CRUDE + ...... BBLS DIESEL TEST PRESSURES TIME (HOURS) PRESSURE DATA ,TUBING / 9-~i/8" / 13-3/8" PACKOFFS TUBIN(~ /9-~/8" PRIOR TO PRESSURIZING: INITIAl._ OATA; / / FINAL DATA: TIME: TBG FINAL PRESSURE DATA HRS WELL STATUS: FLOWING ~ SHUT IN ' PSI 9-5/8" ) 7 ~ D PSI 13-3/8" ~' O PSI SSSV CONTROL/BALANCE LINES ~O~ / '3 ~ PSI TUBING HANGER TEST PORT CAVITY: '-"-' PSI 9-5/8" TEST PORT CAVITY: ~ PS! BLED TO OBSERVATIONS/COMMENTS Revised 2/10/91 ANNULAR COMMUNICATION TEST LIQUID LEAK RATE DATE: ~/I)ql. _ TESTED BY: W E L L # TYPE OF TEST: LLRT SPECIAL INSTRUCTIONS: INITIAL PRESSURE' DATA TIME: )%o© HRS WELL STATUS: FLOWING/d~N~ / SHUT IN (ARRIVAL ON LOC.) TBG q2o PSI 9-5/8" / Zoo PSI 13-3/8" ~'.~ PSI SSSV CONTROL/BALANCE LINES - ~7oc~ / ~oO PSI TBG HANGER TEST PORT, CAVITY: (,.) PSI BLED TO 0 PSI? ~;:~[~. FLUID BLED: 9-5tr:~ TEST'- PORT CAVITY:~:--/oo -. PSI ....... BLED~.TO..0.PSI?- FLUID BLED:-' - %~ ~ -:--:- ........ P R E;TE~*' PREPARATIONS . . . TYPE OF FLUID-AND"-VOLOME'~BEED:: TUBING LOADED W/ 9-5/8" ANNULUS BLED F1 PSI TO PSI TYPE OF FLUID AND VOLUME BLED: 9-5/8" LOADED W/ BBLS CRUDE 13-3/8" ANNULUS BLED F/ PSI TYPE OF FLUID AND VOLUME BLED: + ~"),.:. BBLS DIESEL ,J/,J/~_ I ,~:_. ~-'--~D~ 13-3/8" LOADED W/ ...... BBLS CRUDE + /,$ BBLS DIESEL ................... J_ ........................................ TIME (HOURS) TEST DATA PRESSURE DATA TUBING / 9'5/8" ~/ 13-3/8" PACKOFFS TUBING /9-5/8" VOLUME {INCHES} VOLUM[ (BBLS; / / 0 / O / 0 / 0 0 / 0 0 / O / / / :3,5~' / / / / / / / / / / /- / TOTAL PUMPING / / I i VO LU ME :PuMPEm~~-~' :'~-a ~,"~ '~~.~:; ~'~.' 7. -:: AVERAGE:: RATE:; COMMENTS: RATE STEADY? YES/NO ~ O ..- TIME: I L/SS HRS WELL STATUS: FLOWING ~ / SHUT IN TBG r_/2__ ~ PSI 9-5/8" ~ O PSI 13-3/8" ~0 SSSV CONTROL/BALANCE LINES 3~;~--~6 / -~5~ PSI TUBING HANGER TEST PORT CAVITY: (:) PSI PSI 9-5/8" TEST PORT CAVITY:. 0 PSI BLED TO 0 PSI? ~,~ & ,:,-.~u Chris. Comm!:¢:~i~,'~ Revised 2/12/91 O, q /~.! ........... ,~. .....~ ..... ~ =.-~.~. ~._. .... -~-.,:~...,~. ~..~ .... ~.~ -._-~_~. ......... -.~ _~*.-~ ..... ~ ......... . ~. ~_. ......... ...-~....~..~. ~ -~.,. ~ ~.~- ~. ~ ~.~ .......... - ~-..~.~ T'.g_ ~:~-~'2 -.:~ .- ' ' . · · .. -. .,~,:*,.;'~2-"~.::;' ~,,~ L'.'~:-~L;-c-~p· ...... ';-'~ ;~ : .- ~ :.. ~ ~ - :'.~ -. ~ ....~_~ ~:~~:~.~2~~~:~:~~.. ~ . ~._ ~ ..... · . . -- ~.., · -'., -. :., · ...-~.c .... · - -..:,~,'.~ ,, ,. · ,~ ~:~ ~ - ~ ~-~ ~. ' REFERENCE: ~RCO CA~E~ '*~'-~'7'~* ~Z~',~ ~3~Y '~ :'~7~--1 ~--71 ........ '~ ...... - ......... -'" .............. 4-1 5~9.~ N"- .... ~' ........ ' ...... RUN .] ~ 5 ....... , .... :X':--~?~.'-~ - ": L: '%'¢~ '' ~ -: . .~ ~ . _-._ ~ ..- ..~:. . · ~ - -. ...... ....... ,.-..::-: . . ,..-:,._.: ....~?.;;~.,.-: .... ~ .... ,.~-~,:.:--~-.. _...,-.,.._...,~.,.,_.. :.~.~,:~ ..... ..=,.. ,.._ ..... -- - ' ' .... ' "'-"':'¥' ' ..... '~" '6 .................... RUN 1 ~ ~ ~'~u _& 6 ' - - .... :.:- " -. . · ' :'RUN -t,.'5' ;.,'.. -- 7-.-::$CH;.. -.--:~.~ '-:9-~9 :-:;::' 5-5-9t ARCO Alaska, Inc. ~' Prudhoe Bay =lineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager November 3, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-19i, Approval No. 8-169 Dear Mr. Chatterton: Attached is the Report of Sundry Well Operations detailing work performed on the above-referenced well. Sincerely, D. F. Scheve DFS/jp Attachment cc: J. Gruber, ATO-1478 PI(DS 12-19i) W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCornpany AR3B--6132-C STATE OF ALASKA .---...MiSSiON0 g ALASKr~?'~L AND GAS CONSERVATION C, REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Pull tubing Alter casing Plugging Perforate X Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 55' FNL, 4552' FEL, Sec.18, T10N, R15E, UM At effective depth At total depth 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM 5. Type of Well Development Exploratory StralJgraphic Service 6. Datum of elevation(DF or KB) 77' RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number DS 12- 19i 9. Permit number/approval number 82- 198 / 8 - 169 10. APl number 50 - 029 - 20870 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11930 feet true vertical 9218 feet Effective depth: measured 11877 feet true vertical 9179 feet Casing Length Size Conductor 79' 20" Sudace 2352' 13-3/8" Production 11114' 9-5/8" Liner 1033' 7" Plugs(measured) Junk(measured) Cemented 1850 sx Poleset cmt 1800 sx Fondu & 400 sx PFC 505 sx CI 'G' & 300 sx PFC 350 sx CI 'G' Measured depth True vedicaldepth 79' 79' 2429' 2429' 11191' 8677' 11920' 9210' Perforation depth: measured 11328 - 11347'; 11352 - 11452'; 11465 - 11500'; 11510 - 11550'; 11560 - 11585' true vertical 8776 - 8790'; 8794 - 8866'; 8876 - 8901'; 8908 - 8938'; 8945 - 8964' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10833' MD; 4-1/2", 12.6#, L-80, PCT Tail @ 10917' MD. Packers and SSSV (type and measured depth) Baker SAB Packer @ 10821' MD; Camco Bal-O SSSV @ 2210' MD. 13. Stimulation or cement squeeze summary Intervals treated(measured) SEE ATTACHED Treatment description including volumes used and final pressure 14. Representative Daily Average ~r Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Md Water-Bbl 19756 1669O Casing Pressure Tubing Pressure 801 1386 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~~~"-'/,~t_ ~::.~-~--~/Z Title Operations Engineering Manager Date ~'~'~ ~ Form 10-404 Rev 06/15/88 . I M HP.~ SUBMIT IN DUPLICATE DS 12-19i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE : INJECTION PROFILE MODIFICATION 5/1 1/88 : Squeeze perforations were shot as follows: MIRU equipment, and pressure test BOP to 3000 psi. RIH w/perf gun, and shot: 11683 - 11687' MD Ref. Log: BHCS 12/7/82. POH. Rigged down. 5/12/88 : A Pre-squeeze Mud Acid stimulation was performed, followed by a CTU Cement Squeeze as follows: MIRU equipment, and PT equipment to 4000 psi. RIH w/CT and washed perforations at: 11328 - 11347' MD Ref. Log: BHCS 12/7/82. 11352 - 11432' MD 11432 - 11452' MD 11465 - 11500' MD 11510 - 11550' MD 11560 - 11585' MD 11683 - 11687' MD Pumped the following treatment: 60 bbls 12% HCI w/25% Xylene, followed by, 55 bbls 12% HCI - 3% HF, followed by, 57 bbls 12% HCI. Flushed acid away with seawater, and prepared for cement squeeze. Fluid packed wellbore w/seawater. Pumped 53 bbls cement, squeezing perforations: 11328 - 11347' MD Ref. Log: BHCS 12/7/82. 11352 - 11432' MD 11432 - 11452' MD 11465 - 11500' MD 11510 - 11550' MD 11560 - 11585' MD 11683 - 11687' MD 38 bbls of cement were placed behind pipe. Contaminated cement with 88.5 bbls contaminant. POH. Rigged down. 5/13/88: Cleaned out contaminated cement from wellbore. 616188: Performed post squeeze injection test. Injection profile indicated that a resqueeze was required. DS 12-19i DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE : INJECTION PROFILE MODIFICATION 9/16/88: A pre-squeeze acid wash was performed, followed by a CTU Cement Resqueeze as follows: MIRU equipment, and PT equipment to 4000 psi. RIH w/CT and washed squeezed perforations at: 11560 - 11585' MD Ref. Log: BHCS 12/7/82. 11683 - 11687' MD Pumped the following treatment: 57 bbls 12% HCI w/25% Xylene. Flushed pad acid away with seawater, and prepared for cement squeeze. Fluid packed wellbore w/seawater. Pumped 90 bbls cement, squeezing perforations: 11328 - 11347' MD Ref. Log: BHCS 12/7/82. 11352 - 11432' MD 11432 - 11452' MD 11465 - 11500' MD 1151O - 1155O' MD 11560 - 11585' MD 11683 - 11687' MD 61 bbls of cement were placed behind pipe. Contaminated cement with 150 bbls contaminant. POH. Rigged down. 9/17/88: Cleaned out contaminated cement from welibore. 9/30/88: Repedorated: 11328 -11347' MD 11352 - 11432' MD 11432 - 11452' MD 11465 - 11500' MD 11510 - 11550' MD 11560 - 11585' MD Ref. Log: BHCS 12/7/82. Returned well to seawater injection and obtained a valid injection test. ARCO ALASKA: INC F'. O. BOX ANCHORAGE: AL.A~KA 995t DATE' 6-9-89 REFERENCE' ARCO CASED HOLE FINAL~ 7<-9 5-22-89 PRODUCTION PROFILE RUN 3-24 5-22-89 GR SPEC ,TOOL RUN ,_.-:-:~o~., 5-26-89 GR SPEC TOrlL_ RUN 4-t5 5-i7,19-89 TEMF' RUN 4-26 5-i 9-89 PRODUCTION F'ROFILE RUN 4-5~ 5-i 8-89 PRODUCTION PROFILE RUN 5-i3 5-2(~,2t-89 TEMF' RUN 5-i7 5-2G-89 PRODUCTION PROFILE RUN ~7-7A 5-28-89 PERF RECORD RUN 9-t4 5-22-89 INUECTION PROFILE RUN ~i_~-tt ~'-°i. ~ -89 PITS' RUN ~t2-t9 5-2i -89 INJECTION F'ROFILE RUN ~ 4-~ ~ 5-27-89 C[)LLAR/F'ERF RUN ~ 8-o_ ~ ~-o')-~__ .~_ CBT RUN OWDW-NW 5-24,25-89 PIT~ RUN OWDW-~'E 5-25-89 F'IT~ RUN OWDW-~W ~- o' - ~.-~-89 PIT~ RUN PLEASE ~IG t, t, t, i, i, t, t, i, t, t, t, N AND RETURN THE ATTACHED COPY AY RECEIPT OF DATA 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' 5' CAMCO .S'CH S' C H CAMCO CANCO CAMCO C A M C 0 C~'~MCO CAf,~CO CAMCO CAMCO ~'E:I-! CAMCO CAMCO CAMCO CENTRAL FILES ~ ~ PHILLIPS' CHEVRONs'-":,_' i~:~' ~.'-: PB WELL F'ILE3' EXTENXlO~~ EXPLORATION ~ BF'X EXXON ' ~ 3"rATE OF ALA3'KA MARATHO~ .~. ~: - .... ~ TEXACO ARCO ALASKA, INC. P.O. BOX t00360 ANCHORAGE, ALASKA DATE: t-6-89 REFERENCE: ARCO CASED HOLE FINALS 2-6 t 2-t t-88 2-? t 2-9-88 2-t3 t2-t8-88 2-20 t 2-7-88 2-2t t 2-t 2-88 2-24 t 2-8-88 4-t 9 t 2-t 0-88 ?-30 t 2-~ 8-88 ~ 2-~ t t 2-t 7-88 t 2-~ 9 t 2-~ 9-88 ~4-28 ~ RECEIVED HAVE A NI SALLY HOFFECKt AT0-t529 PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE PRODUCTION F'ROFILE 'PRODUCTION PROFILE INJECTION PROFILE PRODUCTION PROFILE PRODUCTION PROFILE INJECTION PROFILE 2-8-88 LEAK DE,TECI'ION SURVEY ~ Alaska.Oil & Gas Cons. Commission '.~-: ~chorage TRAN$ ~89 'e~') APPROVED _~___ DISTRIBUTION RUN RUN RUN RUN RUN 'RUN RUN RUN RUN RUN RUN CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R&D SAF'C STATE OF ALASKA TEXACO ARCO ALA~'KA, INC. F'.O. BOX t0G36~ ANCHORAGE, ALAS'KA 995i(} DATE' tG-7-88 REFERENCE: ARCO CASED HOLE FINALS 4-23 9-J0-88 F'RODUCTION 4-28 i,0-i-88 9-2 9-t7 88 S .... .,:."': 4 i2-19 ..9.30-88 t 4-25 9-2~-88 i 4-37 i 6-i 6 ?-2~-88 t6-i6 ~-i 6-88 F'RODUCT IOi',l PRODUCTION PROFILE F'R ri D i ..... .il"l.. ]"i ';Z!~-',~ .P F':-i,'I~:'.... , i L.E COLLAR/PERK INJECTION PROFILE C: N i_ -- - (.; AMifi A RAY COL. L. AR/F'ERF GAMMA RAY (PRINTED ACTUALLY A FINAL) RUN ?, 5" RUN RUN t, 5" RiJN 1 , 5 · RUN RUr.~ 4, RUN t, 5 · RtJN i , 2 "&5' RUt'4 RUN i, 5' PI_EASE SIGN AND RET~JRN THE ATTACHED COF'Y A::~ RECEIF"i' OF DATA. 0'i" 15' ':--$CH '-- 5'CH CAMCO C: A H C 0 A 'i' I_ A CAMCO A]'I..A;~ A CAMCO RECEIVED BY ............... HAVE A NICE DAY! 3'ALLY HOFFECKER A'I-O- i 52,° TRAN£' ~886i ¢, AF'PROVED'~. D I Z'1"R I BUT I ON CENTRAL FILES CHEVRON D&M EXTENZION EXPLORA¥ION EXXON MARATHON MOBIL PHILLIPS F'8 WELL FILES R & D SAF'C .ZTATE OF ALASKA TEXACO ARCO AI.A&'KA: .]'NC.. !::', 0 ,. FI.'I'IX DATE: ~!~-- I:;: F:' F:' I:!I R F' N C F · ARCO f'.'.A.S'ED I..IF!I.I::' F"[NAI. Fi'llb. Ji . F;.'I IH i . F;:lli'J t . I::.'! INi I:;.'1 li'-.I '~ I:;; !::' i": I::' l' :',/I::' T':' F.: 'v' .................................... ~tchom~,~ ...... f':, '1' .? 'F !::.' '1: 'RI ! ",," T f'l N rE': !E i'-.!'T' I;: A I.. F:' T I.. ~.' .? F'.I.4EVRON F]Y,"f'I!.r.N.~' .T (INEXF'I.. (]RAT '[ lIN E~XFIN MOBT. I ARCO Alaska, Inc. Prudhoe Bay ,-ngineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 10, 1988 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-19 Permit No. 82-198 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp At tachment cc: Standard Alaska Production Company P1 (Ds. 12-19)W1-3 WELL S / 77 AR'.~ Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALAS,... OIL AND GAS CONSERVATION COMN,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Aba_ndon ~ Suspend ~ Operation Shutdown ~,, Re-enter suspended well ~ Alter casing '~ Time extension~ m Change approved program~ m Plugging [] Stimulate ~ Pull tubing ~ m Amend order ~ Perforate ~ Other 2. Name of Operator A~CO Alaska, [nc. 3. Address P.O. Box 100360~ Anchorage~ AK 99510 4. Location of well at surface 572' FSL & 934' FEL, Sec. 18, T10N, R15E, tiM 5. Datum elevation (DF or KB) 77' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 12-19 feet At top of productive interval 55' FNL, 4552' FEL, Sec. At effective depth 18, T10N, R15E, UM 7, T10N, R15E, UM 8. Permit number 82-198 9. APl number 50-- 029-20870 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured true vertical 11930 feet 9 218 feet Plugs (measured) Effective depth: measured 11877 feet true vertical 9179 feet Junk (measured) Casing Length Size Structural Conductor 79 ' 20" Surface 2429 ' 13-3/8" Intermediate Production 11191 ' 9-5/8" Liner 1033 ' 7" Perforation depth: measured Cemented Measured depth True Vertical depth 1850 Sx 79' 1800 Sx & 400 Sx 2429' 79' 2429' 505 Sx & 300 Sx 11191' 8677' 350 Sx 10887-11920' 8464-9210' 11328-11347'; 11352-11452'; 11465-11500'; 11510-11550'; 11560-11585' true vertical 8776-8964' ~bing(size, grade and measured depth) 5~" a , 17#, L-80, 10918' MD Packers and SSSV(type and m~asured depth) Baker SAB Packer @ 10821' MD, Camco Bal-0 SSSV @ 2211' MD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch 13. Estimated date for commencing operation 4/1/88 14. If proposal was verbally approved Name of approver Date approved 15. I hereby,~certify th,~t th/~ foregoing is true and correct to the best of my knowledge Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned_ ~ Commissioner IApprOval NO' ~__/~ ~: by order of the commission Date .. ?/,,.~'% Form 10-403 Rev 12-1-85 W~.T.T..q/77 T_ A. g~]l~n~mlev. ATO-1506. 265-6871 Submit in triplicate DS 12-19 PWI CTU CEHENT SQUEEZE PROCEDURE I · RIH with coiled tubing and tubing tail locator. Tag TT and PBTD. Fluid pack 5-1/2" tubing· 2. Clean out the rathole of biomass. 3. Shoot squeeze perfs ref. BHCS 12/7/82, 11685-11687', 6 SPF. 4. Perform acid wash to clean up perfs. e Pump 50 bbls cement, squeezing existing perfs: 11328-11347' 11352-11452' 11465-11500' 11510-11550' 11560-11585' Ref: BHCS 12/7/82 6. Pressure up on squeeze and hold for 1 hour. . GIH contaminating cement in wellbore. Slowly bleed wellhead pressure to - maintain a 200 psi differential into the formation. 8. WOC 12 hours. Jet out contaminated cement. 9. After at least 2 weeks, test for injectivity. 10. Reperforate: Ref. BHCS 12/7/82 11328-11347' LSD 11352-11392'' LSD 11392-11452' FSD 11465-11500' LSD 11510-11550' FSD 11560-11570' LSD Do not reperforate 11570-11585. , , 11. Return well to injection. 12. Run injection spinner/temp log. TAB/662 1. 5000 PSI '7" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WIR£LIN£ RAMS (VARIABLE SIZE) 3. 5000' PSI 4 1/6" LUBRICA'rOR 4. 5000 PS~ 4 1/6" FLOW TUBE PACK-Orr 2 ]NE BOP EOUIPHENT i i ! I · 6 5 1. 5000 PSI ?" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PIPE RAMS 3. 5000 PSI 4 1/6" HYDRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 4 3 2 COILED TUBING UNiT BOP EOUIPHENT ARCO Alaska, Inc. Prudhoe Bay ,..,,gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager March 30, 1987 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 12-19 Permit No. 82-198 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work performed on the above-referenced well. Very truly yours, D. F. Scheve DFS/TAB/jp At t a chmen t cc: Standard Alaska Production Company PI (DS 12-19)W1-3 to be WELLS / 77 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany .... STATE OF ALASKA '-'-' ALAS .... OIL AND GAS CONSERVATION COM~,..,.,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, :[nc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 572' FSL & 934' FEL, Sec. 18, T10N, R15E, UM At top of productive interval 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM At effective depth 3Azt3t'°t~s~e, pt~716' FEL, Sec. 7, T10N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 11930 feet Plugs(measured) 9218 feet 5. Datum elevation (DF or KB) 77' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 12-19 8. Permit number 82-198 9. APl number 50-- 029-20870 10. Pool Prudhoe Bay Oil Pool Effective depth: measured 11877 feet Junk (measured) true vertical 9179 feet Casing Length Size Cemented Measured depth Structural Conductor 79' 20" 1850 Sx 79' Surface 2429' 13-3/8" 1800 Sx & 400 Sx 2429' Intermediate Production 11191' 9-5/8" 505 Sx & 300 Sx 11191' 1033' 7" 350 Sx 10887-11920' Liner Perforation depth: measured 11328-11347'; 11352-11432'; 11431-11451'; 11464-11499'; 11509-11549' true vertical 8776-8963' Tubing (size, grade and measured depth) 5½" 17# L-80 10918' MD , , , B ,Packers and_..SS~SV (type and measured depth) after SAB ~actcer @ 10821' MD, Camco Bal-0 SSSV @ 2211' MD True Vertical depth 79' 2429' 8677' 8464-9210' ; 11559-11584' 12.Attachments Description summary of proposal :M Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation 5/1/87 14. If proposal was verbally approved Name of approver Date approved 15. ' hereby/,.)certify that~he~or~oing is true and correct to the best of my knowledge Signed ~j~,/~~~~ Title Operations Engineering Manager Date ~/'~'~/¢,,~ Commission Use Only approval Notify commission so representative may witness I Approval Conditions of No. ,.-~/ [] Plug integrity [] BOP Test [] Location clearanceI -/ ,"~4/ / by order of Approved by Commissioner the commission Date '~-' Form 10-403 Rev 12-1-85 WELLS/77 T. A. Billingsley, ATO-1506, 165-6871 Submit in triplicate DS 12-19 PWI SAA~ PLACEMENT FOR LOWER CHANNEL SHUT-OFF PROCEDURE · · · . . · · · Tag PBTD (last PBTD was 11714' on Run CCL to locate tubing tail. 5/7/86). Reduce injection rate to ± 3000 BWPD. RIH w/coiled tubing· Tie in with tubing tail locator. Set CT nozzle at 11550'· Start pumping gelled seawater with approximately 2 lbs/gal 12-20 mesh sand. Pump 2000 lbs stage of 12/20 mesh sand. Monitor injection pressure and rate. Allow first sand stage to settle· Tag PBTD to determine how much sand went into formation. Pump second stage of 12/20 mesh. Tag PBTD. Keep pumping stages of 12/20 mesh sand until either: a. Sand top in wellbore nears lowest perforation at 11584'. Final stage of sand should have ± 10% 100 mesh sand mixed with the 12/20 mesh sand. b. Significant injection pressure increase is noted. c. 6000 lbs of 12/20 mesh sand and 600 lbs of 100 mesh sand have been pumped. POH w/CT and return well to normal injection· (10,000 BWPD.) Monitor pressure and rate and compare to pre-treatment values· Run post-treatment injection spinner/temperature survey· Sand Volume Calculation Rathole volume (11714-11584) (7" liner) 130' x 1 bbl = 4.8 bbls or 2900# sand 26.92 ft Max. channel volume (11750-11584) = 166' x 1 bbl = 3.7 bbls or 2200# sand (8~" bit x 7" liner) 44.28 ft *Some sand may enter the formation. 8.5 5100# sand Contingency* 1500# sand Total 6600# sand TAB/90 3 2 1. 5000 PSI 7" WELLHEAD CONN[.CIOR FLANGE 2. 5OD0 PSi WIRELINE RAMS (VARIABLE SIZE) 3. 5000 PS! 4 1/6" LUBRICA'I'OR 4. 5000 PS1 4 1/6" FLOW 'I'UBE PACK-OFF H~IRELINE BOP EOUIPMENT 6 5 4 J I j 1 ! I ! ~ -I i 1. 5000 PSI 7" WELLHEAD CONNECIOR: FLANGE 2. 5000 PSI 4 1/16" PIPE RAJVlS · ~.5000 PSi 4 1/6" I-h'DRAULIC SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PS1 4 1/6" BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX COILED TUBING UNIT BOP EOUIPMENT i · ARC-:3 ::- (aska: i'nc ~ .................... A. · c,-'- ~ 5--S-88 ?--8~'' 5 -1 ---':'": S:p ,'n -c,: ...... 9.-i 2/ 5- 2---:;=:--_:.: "- .................. "' .... - ' ;e r; c,.'.,.-, " 'i i - ~ -!-x --/-8--88 --; 9-, c,,/ 5-- · J-2 .2,2/ .... - ...... -; .-- -- .- ?: _-:- - ,' - u--_, i ',-., _i ~- c .---_ i S- 18 / 5:-- ':" - 8 ~ 4-- ~ a / 5-- !. i 4-25/ 5:-- 2-.'-E: & Zp i ~--.-, 7 ,/ 5-.=:- ;:; A :-- ......... ..... ~-- ..... _--:.: S~ur vey i .4-SA / ~-,4- a.-::, .... in ! :-:-:-':: T i O'i~ :-"rC~T i --'~ ~ .4- t: *.;~ t:--- ~- -{::- ::'. A i :---.:- ~ ""'- i 6'~ i 2-26-85 : ..... ~ ..... ...... Lc, 9 ,....s 5' 5' 5' Pi~,n--.~ ---.:c-r, ~:---~ ~:'-:'"'~- ~ ':-'::;-'= '---'**': ' ~ ' ""]UNO Z~ 1986 ,<-~ --' .aTT:'- ! :.-'-,'-=- ? ~__, .~ :...~ ~ : :'.?.:~- -: -=-:,-2-:_-'-'=- c:.f data. <. D i :£TR l BUT :! ARCO ALa.s'ka, Inc., F',.O., Box t GOS60 Anchorage, A Las'ka 995i0 DATE' ,~ep'fember i3, i984 REF:'EREN[.'.I:-.i' ARCO Pressure I) a fa 2- i A~'~'' '7-2'2--84 <P_BU: -- 7-2 7-i 8 7-4-84 CDBR ~ 2-~ 9 i4.-.S6/ 8--27-..8.,1 F;~atic ~'urvey Camco ..... o i 8-~ ..... · ' ._. . 7-7--S4 CDBR C 8 hi C O C ¢] hi C 0 C a m c o 60 F'Lease .sign and 'ce'turn ~he a't'bached~ (~op~¥-?~s' receip+. Received By ' ' - ~ ,':' }~J84 HAVE A NICE DAY! KeLLy HcFarLand ATO-..t429F TRAN~. o f cl a '1: a, DI£'TRIBUTION Chevron ExpLoration 5'err ices Exfen.sion ExpLora'['ion Exxon Getty Marathon Mob i !. MobiL E & F' Phi L L ip.s F'rudhoe Bay WeLL R&D S'oh i o State of ALa.ska F:'i Les ARCO Alaska, Inc Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 Date: January 29, 1985 Reference: ARCO CH Finals r-_~j-~l~-6 Prod. Loggoing Svs. 1-9~ Production Profile 12-19Injection Profile 4-14 Spinner 18-3 Prod. Logging Svs. 4-4'_-Spinner 1-9 CNL 15-9-'~epth Determination ~i2-22Perf. Record 12-28Perf Record ~6-17 EPL .... 12-27Perf. Record ~4-8 Spinner 4-15 Spinner j6-3 Spinner ~3-18Spi~ner .... 6-3 Diff. Temp. _~15-9 Collar Log ~2-15 Temp. Survey 12-27-84 #1 DA 5" 1-3-85 #1 Camco 5" 1-2-85 #1 Camco 5" 12-16-84 #1 GO 5" 1-10-85 #1 DA 5" 12-15-84 #1 GO 5" 12-20-84 ~1 GO 5" 11-9-84 ~1 Sch 5" 11-29-84 ~1 Sch 5" 12-3-~4 ~1 Sch 5" 10-4-84 31 Sch 5" 12-1-84 ~1 Sch 5" 12-27-84 ~1 GO 5" 12-16-84 Pi GO 5" 12-21-84 ~1 GO 5" 12-26-84 ~1 GO 5" 12-21-84 ~1 GO 5" 12-2~-~4 ~1 GO 5" 12-24-84 #1 GO 5" Please sign and return tha attached copy as receipt of data. Received by ~~~:' Pam lambert Trans 016 ~'." ATO i429C Chevron D & M Exploration Services Extension Exploration Texaco Marathon Mobile Mmbile E & P Phillips Prudhoe Bay Well Files R & D Sohio State of Alaska ARCO Ata-~'l<a, Inc. F',O. Box iOOS60 Anchorage, Al. as'ka 995i0 DATE' Sep'tember R E F-" E R E N C E · A R C 0 t ') t 984 Cas'ed HoLe F*inat'~ S- 7'~- 6-i 0-84 S'-28--- 6-4-84 4- t ~, _,--~.~-8 _ 7-6 ~ 4-26--84 t o t 9 ~ 8-8 '-~-' 6-.~ ~-84 ~ 8-8 --- 6-8-84 ~ 6.-.8 ~ 6-.d.-,,4 ~6-8 / 7-i8-84 ~ 6-8 i 7--i ~/- 6-i 5-84 D i 'F f T e m p CBL./VIO ACBI_/VDL/,'~ i gna 'f tt'~" e/(;R CCL/Perf Record CNI_ CH CF'-S / S,'p inner D i f f T e m p CCL./Perf Record EPL CCL/Per f Record gET CET EPL Run t 5' Fi:un t 5" Run R t~ nt 5" R tx nt 5" Run 2 Run 2.'5' R u n 2 5" Rt.tn Run i Run i 5' F;,'tln t.-"::" R u. ~"~ .sign and ret'urn 't'he at'facheci copy as' rec:e i p !' of (:1 a t a, Recei ved By_~ .............. ~'-..~Z'~ T.: ' :' ' ' · :(.7:: -'--- '- KeLLy McFarLand ATO- t ,1,..."~°F, 'FRANS. ~33'7 DI$I'RIBUI'ION Chevron ExpLorat'ion Services' Ext;en.sion ExpLora'l:ion E x x on Marathon Mob i L MobiL E & F:' Phi L L ip.~ Prudhoe Bay WeLL R & D $ohio Etate of ALaska F:'i Le.s ARCO Alaska, inc. Post Office E'~-~ 360 Anchorage,. ,ka 99510 Telephone 907 277 5637 April 13, Reference · 1984 ARCO Pressure Data D.S. 6-9f 3-23-84 Static D.S. 6-17 ~-- 3-24-84 Static D.S. 7-16 ~ 3-10-84 Horner Plots w/listing D.S. 12-8B- 3-22-84 Static D.S. 12-19 J~3-21-84 Static D.S. 14-8 f 3-23-84 Static D.S. 14-27 ~ 4-2-84 Static D.S. 14-32f 4-2-84 Static D.S. 14-34f 3-25-84 Static D.S. 15-4j 3-15-84 PBU - 3-15-84 Common Data Base Report D.S. 15-13f 3-11-84 PBU 3-11-84 Common Data Base Report Camco Camco Sch Camco Camco Camco DA GO DA Camco Camco gn and return the attached copy as receipt of data. FRIDAY THE 13th is upon us - Have a Nice One! Kelly McFar la~evr°n ATO-1429F Trans. # 148 DISTRIBUTION D&M Dallas Drilling Ext. Exploration Exxon Getty Marathon Mobil Mobil E & P Phillips Prudhoe Bay Well Files Carolyn Smit~ Sohio State of Alaska ~;;~'~,~'~ ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer January 23, 1984 Mr. C. V. "Chat" Chatterton State of Alaska Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: ~DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Enclosed are the Completion Reports for work done on the above-mentioned wells. Very truly yours, D. F. S cheve Regional Engineer DFS/JCD/lmi Enclosures cc: SOHIO Alaska Petroleum Co. File 100.0 DS 12-19, 12-20 RECEIVED JAN2 5198t O~ & Gas Cons. CommLmkm Anchorage ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIchfleldCompany · -¢ '~'.~.:.'- STATE OF ALASKA -- ' ALASKA ,k AND GAS CONSERVATION C~'~ -'"'MISSION ~~_.- WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [J~ Water Injection 2. Name of Operator 7. Permit Number ARCO Alaska~ Inc. 82-198 2. Address 8. APl Number P.O. Box 100360~ Anchorage, Alaska 99510. 50- 029-20870 4. Location of well at surface 9. Unit or Lease Name 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 55' FNL~ 4552' FEL, Sec. 18, T10N~ R15E, UM DS 12-19 At Total Depth 11. Field and Pool 323' FSL~ 4716' FEL~ Sec. 7, TiON, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0il Pool 77' RKB] ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/30/82 12/16/82 12/29/82I N/A feet MSL 17. Total Depth (MD+TVD) :18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost l1930'MD, 9218'TVD 11877'MD, 9179'TVD YES [~ NO []I Nipple @ 22~e~t MD 1800' (approx) 22. TvPe Electric or Other Logs Run DIL/SP/BHCS/OR, FDC/CNL/OR/CaZ, CBL, ~/CR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5~ H-40 Surf. 79' 30" 1850~ Poleset 13-3/8" 72.0# L-80 Surf. 2429' 17½" 1800 sx Fondu & 400 s~ Permafrost C 9-5/8" 47.0~A Surf.. 11191' 12¼" ~0-¢~s~Class G & 300 sx Permafrost C L-80 7" 29.0~ L-80 10887' 11920' 8½" 350 sx Class G 24. Perforations oPen to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 11328-11347' MD 8699-8713' SS 5~" 10917' 10826' 11352-11432' MD 8716-8774' SS 4spf . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Ref: BHCS 12/17/82 ~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) Water InjectionJ N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO N/A I TEST PERIOD ~ FlOw Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) ,. Press. 24-HOUR RATE I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chi Form 10-407 . Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Sadlerochit O/W Contact Water Moved From To I; MEAS DEPTH !i TRUE VERT. DEPTH 11760' h 9015' Base Sadlerochit 11666' 8946' 11685' 8961 LIST OF ATTACHMENTS Not Reache~. 30. FORMATION TESTS Include interval tested, pressu'e GOR, and time of each phase N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~l~*'~j.~~--~----~/~--,z ...... T,tle Regional Engineer 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 measurem~.~nts 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 (multii)le completion), so state in item 16, and in item 24 show the producing intervals for only the interval rel)orte(] in item 27. Submit a separate form for each additional interval to be separately produced, showin.q tt~e 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 we lng and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". should show the details of any multiple stage cement Rod Pump, Hydraulic Pump, Submersible, Water In ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer July 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 12-19 Permit No. 82-198 DS 12-20 Permit No. 82-191 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments CC: Sohio Petroleum File Pi(DS 12-19)Wl-3 File PI(DS 12-20) W1-3 ARCO Alaska, Inc. Is a Subsidiary of AtlanllcRIchfleldCompany STATE OF ALASKA ALASKA?~L AND GAS CONSERVATION C¢""MISSION SUNDRY I , TICES AND REPORTb ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHERY~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well (Surface) 572' FSL, 934' FEL, Sec 18, T10N, R15E, UM (Producing Interval) 55' FNL, 4552' FEL, Sec 18, T10N, R15E, UM (Total Depth) 323' FSL, 4716' FEL, Sec 7, T10N R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 6. Lease Designation and Serial No. ADL 28330 7. Permit No. 82-198 8. APl Number 50- 029-20870 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 12-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate ~ Alter Casing {~] Perforations Stimulate '..--I Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each coml31etion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any propo~d work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to add perforations on DS 12-19 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: 11432 - 11452' MD (20') 11465 - 11500' MD (35') 11510 - 11550' MD (40') 11560 - 11585' MD (25') Ref: BHCS 12/17/82 RECEIVED JUL 2 Naska 0il & Gas Cons, C0mrnission Anchorage 14. I hereby c~if~ that the fore~qoing Ls true and correct to the best of my knowledge. /~~~,/~ / ~,~~_. Regional Engineer Signed Title The space below for Commission use Conditions of Approval, if any: 6111111AL 1tt1[I Approved by _APproved returned By Order of COMMISSIONER the Commmssion Oate Form 10-403 Rev. 7-1 ~0 Submit "intentions" mn Triplicate and '*Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay ~ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer February 8, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: DS 12-197 DS 12-20 Permit No. 82-198 Permit No. 82-191 Enclosed are "Subsequent" Sundry Notices detailing work done on the above-mentioned well. D. F. Scheve DFS/JCD/lmi Attachments cc: SOHIO Alaska Petroleum Co. File 100.0 ARCO Alaska, Inc, Is a Subsidiary of AtlantlcRIchfleldCompany ,--"- STATE OF ALASKA -- ALASKA ..,IL AND GAS CONSERVATION C~. ,1MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WEL'L [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of Well 4 ' . 572'FSL, 93 FEL, Sec 18, T10N, R15E, UM (Surface) 55'FNL, 4552'FEL, Sec. 18, T10N, R15E, UM (Top Prod) 323'FSL, 4716'FEL, Sec. 7, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 77' RKB I ADL 28330 12. 7. Permit No. 82-198 8. APl Number 50- 029-20870 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other ~]X 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. has converted Drill Site 12-19 to a water injection well. 14. I hereby certify that the fore_going is true and correct to the best of my knowledge. /~~Z/,~ Regional Engineer Signed . . . Title The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay Engineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4245 Donald F. Scheve Regional Operations Engineer December 14, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: DS 12-19 DS 12-20 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Attached are Intention Sundry Notices for conversion to water injection wells for the above-mentioned drill sites. Sincerely, Donald F. Scheve Regional Engineer DFS:la cc: J. C. Dethlefs J. R. Schuyler D. Smiley Sohio Alaska Petroleum Co. Well File, DS 12-19 & 20 ARCO Alaska, Inc. Is a Subsidiary of AltantlcRIchfleldCompany STATE OF ALASKA ALASKA ~JIL AND GAS CONSERVATION Ct...IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-198 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-20870 4. Location of Well 572' FSL, 934' FEL, Sec. 18, T10N, R15E, OM (Surface) 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) ! 6. ~ease Designation and Serial No. _77' R~B I ADT. 28330 12. 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12 -19 11, Field and Pool Prudhoe Bay Field Pruelhoe Bay O~l Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well - [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) L 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to convert Drill Site 12-19 to a water injection well. This well is within the Flow Station 3 Injection Project area, and it is scheduled to begin receiving water in late December, 1983. / S bsequeat Work Bepo~tea 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~', ~ _~'~ Z).]~L'-, ,~__~.~v ~,, Title Reqional ~.ng±neer The space be,ow f;~; ~om~ss(. ~e ' Date Conditions of Approval, if any: Approved by ORIGINAL SIGNED BY LOHNIE C. S~ITH Approved Copy Returned By Order of COMMISSIONER the Commission Date For'm 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office/'--'.x 360 Anchorage. jska 9951 0 Telephone 907 277 5637 October 17, 1983 Reference: Arco Pressure Data D.S. 4-5 9-7-83 9-7-83 D.S. 4-11 7-24-83 D.S. 4-15 8-11-83 b.S. 12-15 9-24-83 D.S. 12-16 9-24-83 D.S. 12-17 9-24-83 D.S. 12-18 9-25-83 D.S. 12-19 9-25-83 D.S. 12-20 9-26-83 D.S. 15-12 9-21-83 9-21-83 Pressure Build-up Pressure Build-up Data Sheet Pressure Build-up Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Static Survey Pressure Build-up Pressure Build-up Data Sheet Camco otis Sch DA DA DA DA DA DA otis 'P~lease sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429F Trans. # 578 Chevron Dallas Drilling Exxon Getty Marathon MobiI DISTRIBUTION North Geology Phillips Prudhoe Bay R&D Caroline Smith Sohio State of Alaska ARCO Alaska, Inc. Prudhoe Bay ~-ngineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer October 3, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 30bl Porcupine Drive Anchorage, AK 99501 Re: D.S. 12-15 D.S. 12-16 D.S. 12-17 D.S. 12-18 D.S. 12-19 D.S. 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Attached are "Subsequent" Sundry Notices detailing work on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS:la cc: Sohio Petroleum Co. File 100.0 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieidCompany STATE OF ALASKA ~-~ ALASK, OIL AND GAS CONSERVATION ~ MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of Well 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM (Surface) 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF., etc.) I 6. Lease Designation and Serial No. 77' RKB I ADL 28330 12. 7. Permit No. 82-198 8. APl Number 50-- 029-20870 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 12-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Check Appropriate Box To Indicate Nature of Notice, Report, or )ther Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) (Submit in Duplicate) ~ Altering Casing [] [] Abandonment [] [] Other [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Began perforating 24 September 1983. equipment. RIH with gun ~1, shot 11410--11430' MD, 4 spf. rate & took shakeouts. POH, all shots fired. RIH with gun 92, shot 11390-11410' MD, 4 spf. RIH with gun #3, shot 11370-11390' MD, 4 spf. RIH with gun #4, shot 11350-11370' MD, 4 spf. RIH with gun #5, shot 11326-11345' MD, 4 spf. RIH with gun #5 (2nd try), shot 11326-11345' MD, 4 spf. fired. RD. Secured well 25 September 1983. All depths referenced to CBL 23 December 1982. RU perforating unit, pressure test surface Flowed to tank for clean up, monitored Flowed to tank. POH, all shots fired. Flowed to tank. POH, all shots fired. Flowed to tank. POH, all shots fired. Flowed to tank. POH, no shots fired. Flowed to tank. POH, all shots _ 14. I hereby C,~l'tify that the foregoing is true and correct to the best of my knowledge. Signed . _ . Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Prudhoe Bay ;meering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F. Scheve Regional Operations Engineer September 12, 1983 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Re: DS 12-15 DS 12-16 DS 12-17 DS 12-18 DS i2-19 DS 12-20 Permit No. 83-32 Permit No. 83-11 Permit No. 83-4 Permit No. 82-206 Permit No. 82-198 Permit No. 82-191 Dear Mr. Chatterton: Enclosed are "Intention" Sundry Notices detailing work proposed on Drill Sites 12-15, 12-16, 12-17, 12-18, 12-19, and 12-20. Very truly yours, D. F. Scheve Regional Engineer DFS/JCD/la Attachments cc: Sohio Petroleum Co. Well File 100.0 ARCO Alasl~. Inc. Is a SubJldlary of All,~nllcRIqhfleldCompan¥ STATE OF ALASKA ---~ ALASK, .)IL AND GAS CONSERVATION t _MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1, DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 82-198 3. Address - - 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-20870 4. Location of Wel 572' FSL, 934' FEL, Sec. 18, T10N, R15E, UM (Surface) 9. Unit or Lease Name Prudhoe Bay Unit 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM (Top Prod) 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM (TD) 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB I 6. Lease Designation and Serial No. ADT, 28330 10. Well Number 12-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 12. (Submit in Triplicate) Perforate [~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to perforate selected intervals within the Sadlerochit sand from the Prudhoe Bay unit. Upon perforating, the well will be flowed to a tank for cleanup. ~The perforated intervals will be given in the subsequent report. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed perforated Intervals: 11328-11347' MD (19') 11352-11432' MD (80') ref: BHCS 12/17/82 Subs~u~t Work Reported ~ Foz~ No./~-ql)$ Dated ~/~,~----~ 14. I hereby certify that t!~e foregoing is true and correct to the best of my knowledge. L Signed~:~t: F, · ~ _ _ ~t~u-~__ / ~ .~.'~ Title Regional Enqineer The space below for Commission use ~ Date Conditions of Approval, if any: Approved Copy J~eturned By Order of Approved by. BY [0N~{!E C. SI~II'II COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~,~CO Alaska, Inc..~--. Post Office ; 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 10, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for January on these drill sites' 1-24 1E-20 7-18 1E-21 7-19 1E-22 7-20 1F-1 12-17 1G-6 12-18 1G-7 13-9 1Y-13 13-98 WSW-IO WSW-11 Tract Well 24-11-14 CIRI Wolf Lake Well #1 Ravik State #1 A1 so enclosed are well completion reports for' 2-11 1E-23 7-17 1F-2 12-19 1F-3 13-11 1G-8 13-21 WSW-8 13-24 WSW-9 The survey for 2-22 needs to be reran; a completion report 'for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-24A, 2-11, 13-21 (3 reports), and 13-24. ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany . , *'~ STATE OF ALASKA -~ 0 RIG IN A £ ALASKA LAND GAS CONSERVATION C~. MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL]~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-198 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20870 4. Location of well at surface 9. Unit or Lease Name 18, T10N, R15E, UM ~[~,':"~..~[~ii~T~[ Prudhoe Bay Unit 572' FSL, 934' FEL, Sec. At Top Producing Interval'I \/F-i-~JFJ~D t 10. Well Number 55' FNL, 4552' FEL, Sec. 18, T10N, R15E, UM ~Sur[. ~-, i 12-19 At Total Depth tL~- ~- ~-___L_j~ 11. Field and Pool 323' FSL, 4716' FEL, Sec. 7, T10N, R15E, UM"~' Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 77' RKB ADL 28330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 11/30/82 1 2/16/82 12/29/82I N/A feet MSL 1 17- Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I i2;l~;p~hwhereSSSVset I 21.Thickness of Permafrost 11930'MD,9218'TVD 11877'MD,9179'TVD YES IX] NO [] N 2211 feet MD 1800' (approx) 22. Type Electric or Other Logs Run D IL/SP/BHCS/GR, FDC/CNL/GR/Cal, CBL, CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZEIWT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# U-40 Surf 79' 30" 1850 # Poleset 13-3/8" 72.0# L-80 Surf 2429' 17-1/2" 1800 sx Fondu & 400 sx Permafrost C 9-5/8" 47.0# L-80 Surf 11191' 12-1/4" 500 sx Class G & 300 sx ~ermafrost C 7" 29.0# L-80 10887' 11920' 8-1/2" 350 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2" 10917 ' 10826' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FQR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ^l~,~.kc~ Oil & ~;~as u~ns. Commissio~ ' Anc;norag ' Form 10-407 Submit in duplicate Rev. 7-1-80 GRU1/WC20 CONTINUED ON REVERSE SIDE 29. NAME GEOLOGIC MARKERS Top Sadl erochi t O/W Contact Water Moved: From To Base Sadlerochit MEAS. DEPTH 11324' 11760' TRUE VERT. DEPTH 8773' 9093' 11666' il 9023' i 11685' i 9037' Not Reached ~ I 30. FORMATION TESTS Include interval tested, pressure data. all fluids rec~.ve~ud and gr;~v~y, GOR,and timeof each phase N/A 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey ~ copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~~ Title Area Drilling Enginee~Da,e 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 i~jection, 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". DS 12-19 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1330 hrs, 11/30/82. Drld 17-1/2" hole to 2460'. Ran 58 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2429'. Cmtd 13-3/8" csg w/1800 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Pumped 100 sx Permafrost C top job. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.3 ppg EMW - ok. Drld 12-1/4" hole to 11209'. Ran 291 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 11191'. Cmtd 9-5/8" csg w/500 sx Class G. Set 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11930' TD (12/16/82). Ran DIL/SP/BHCS/GR f/11925'-11169', FDC/CNL/GR/Cal f/11925' - 9-5/8" shoe. Stuck tool 11740'; recovered. Arctic packed 9-5/8" x 13-3/8" annul us w/300 bbls H20, 300 sx Permafrost C, & 120 bbls Arctic Pack. Ran 26 jts 7" 29#/ft, L-80, BTC liner (w/tieback receptacle) f/10887'-11920'. Cmtd 7" lnr w/350 sx Class G. Baker running tool backed off & was left in the hole. RIH; latched onto fish & recovered. Drld cmt to 11877' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaC1. Ran CBL f/11843'-10770' & CNL/GR f/11290'-2400'. Ran 5-1/2" completion assy w/tail @ 10917' & pkr @~10826'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi ~- ok. Displaced tbg to diesel; back-flowed 30 bbls into ann. Dropped ball & set pkr. Nipple for SSSV @ 2211'. Secured well & released rig @ 1800 hrs, 12/25/82. Gyroscopic survey ran 12/29/82. JG'llm 01/03/83 GRU1/DH5 , ARF;O ALASKA, INC. , _ ] '-' ' :::.'Ei:2RO342-X O 13~ 12 WELL Nh: 1 PRUDHOE BAY, NORTH ::;[_OF'E, ALASKA : GMS;:, 0-11F::77' MD, SURVEYOR: ,JAHN/MILLER DATE F.:I..,~;!:~""~':'J;-~q~r'r:,_.-,:,..'."""-' · N J. 1 CAMERA NO. 1644 ._ ' I ",1 t'. ·ii F [ RE.:, I GHT - N.5 45W VERTICAL .:.E_.T I ON C:ALCLIL A PETROLANE COMPANY RECORD OF SIJRVEY RADIUS FtF CUI-RVA"FLIRE METHOD F:'C:UDI-JOE BAY NORTH · , oL JF E ALASI<A ,]OB NO: A1282RO342-XG TB.L.E MEASURED DRIFT f/RI FT 'COUF~SE VERT I C:AL VERTIC:AL ~'1 '" c, JBc, EA R E C T A N 6 U L A R C: L 0 S U R E DOGLEG DEPTH Al,lISLE D IREC'T ION "P ' LEN~lH DEPTH SECTION TVD C 0 0 R D I N A T E S D I'-' I .... · =,TAN..E lEI I REC:'f I ON :--;EVER I T¥ ........ FEET D M lEI M FEET FEET FEET FEET FEET FEET D M DG / 100F] O, 67. W 0 ':4 59 ""' .,:4 S 52 W O, ..z,=: 1 02 W 1 ,:.,/_. c. 54, 0 W 0 ':.~':' . .=,.z, W 1.77 ._,'=' 4.9 27 W O, 07 · . O0 0 ,., . .:, ) ..,6:36 W 10C). ~ ~ 600. 0 12 S ..._5 ~ :36 W 100 . ..~ .-.=':~ ~'.-.,. '? 9 .\ -0 02 422,99 1, =~ , .. c.,~ S 0 04 ="~'" 99 1 93 S w ,_l -" .~. · · -'=-"=; S ':' .c,=. W 2 47 49 M W 0,'"1 :39 W ..::. c),=, 51 7 W O. 0.05 622.99 ~..":' · 03 ._,c. -0.11 722.99 2, 1'1 S -0 · 7C; oo,=, ¢19 2. '=:/ ..I ", 10C)O. 11 O0 · 0:36'.:, ~' 26 1~.":' E 0 30..,c' 12 0 E 1200. 0 30 S 2 36 E 1300. 0 30 S 18 48 E ......... _1._4C2J~, ........... ~)__4_:_3._~.S__:_2:_3.. _Q E 1 ,-, .)0. 1600. 0 18 S 3 30 E 0 18 .S 4 30 W ,_,o. 03 :=: 0 '--;. W ':' 55 ':' c) 10 W O. 5;4 O. (:)4 170 c). 1 ,:, .)(.) · 1900. 0 24 S 9 24 W 0 .q/- o .-., ....... ~1 48E ! 12 ~.; ~-'9 24 E 100. 16, 99 . 'P 6, - 7 .00 1/-_,._..s":'. ¢~.. 6, 9.. 15 S C) .10 W ~'- · ·:,._, 10.01 S C).O1 W 100. 17 ;~ ~. 95 -7 72 1722 ':'= 100. 1899.94 -9.26 18:22.94 11.36 S 0.79 E 9.16, F; 0 37 W 1 o · 01 S 0 '.=.' W 11 49 c. 3 .~'--; E O. 10 (:). '~':, C). 6.:'-, 20C)0. 2100. 1 18.=,'-' 5o. 3c3 E 1 36 S 62 24 E 1 O0 · 1 '2';.?'~. 91 - 11 · 43 1922.91 12.90 :--; 2.3:3 E 100 2099.88 - 13 E. 5 '"C '"", .. · . ,' J ..- =. 8b: 14.30 ¢; 4.44 E 1:3.11 :E: 10 14 E 14.97 S 17 14 E 0. ' .~ O, 4.2 2200. 2300. 2400. ~ 0 E 2 18 S .... , '2 42 S 50 18 E 3 O_ o~" 40 12 E 100 ~.' . . . . ,1 '-.?'-] 82 100. 2299,73 100. 2:39'P. 60 -17.06 ' 2122.:s:2 -21.31 2222.73 -26.25 '=-::3'='. "2.60 16.c37 S 7.34 E 1F:_.71 ¢'~, 10.:=:1 E 22.'21 S 14.:2::3 E 17.6/-, '.F.; 24 '~'-' _ o..- E O. 74 21,6,1 .S :30 1 E 0.4-5 26.4:3 '.=; :32 50 E O. 5:E: '2500. 2600. 1 36 S 27 30 E :3 24 N 77 24 W 100. 2499.5~' 100. 25'2'2.42 -3C). 23 24~',.'.'= F,~2 -:31.01 2522.42 2.5.53 S 16.56 E 28.29 S 14.44 E .~_ 0 .4. 3 S ._,'='- ? 58 E · _,'='1.77 S 27 2 E 1.4-8 4./=.0 2700. 2:300. · -,¢/-) .,-'; L 0 · 7 24 N /=.'.-? 0 W ._'-~ 48 N 61 12 W 11 0 N .~o 24 W 100. .,.6, :7,_. 96 1C)C). ..'7 Y7.96 100. 2 E:'.-T, 6.4-6. , .... 19 2621.96, -10.48 2720.96 6. 32 -:,o · ,:..=. 19.46, 25.58 S 5.44 E 1'2.65 S 7.33 W ._.o.6.3 S 20.37 W 26, 1.~._ S 1:'.. 1 E 20. 'P7 :=; 20 217 L4 22, 12 ,..c' 6,7 :3 W 4.07 1.7:-=: 4.4-5 t ARCO ALA::;k~A, INC. Do I , WELL NO: 19 GMS;. g 0 B N CI: A 12 ,:: 2 R ¢)..:: 4 ..'- - X O C: 0 M F' U'I"A T I f_] N 7'1 ME DATE FRUDHLE BAY NORTH F;LOPE', ALAL:;KA .... :..,= 1 17 -,_1A N -,.. F'AG'E NO.' ' 2 [, MEASURE[m DRIFT DRIFT TRUE COI.IRSE VERTICAL VERTICAL SUBSEA R E C:.T A N O LI L. A R C L 0 ..S I_l R E ,[IOGLEG i' DEF'I'H FEET ANGLE DIRECTION LENGTH DEPTH D M El M FEET FEET oECTICN TVD FEET FEET C 0 0 R D I N A T E 8 [I.:,FANL. E D IREC:TIC~N SEVER I'I'Yi' FEET FEET D' M DG/100Fli · .-,000. 14 36 N 41 0 W · '3100. 17 36 N 45 6 W 100. 2993. '.-]6 100. 3090.03 28.47 2.916,96 ,.6 14 201 03 3~tO. 19 12 N 44 48 W :-_-:300. 20 24 N 44 54 W · _.40t. 21 .~ 3(] ..6 N 44 W 100. 3184· 91 100. ¢,z,~' ~' '~ o;.. 00 100. :3372. :36 8.42 N, 34.52 W 35.53 N 76 18 W 3.64 28.67 N 53.45 W /:,0.65 N 61 47 W 3.21 51.01 N 7'~ 2~, ~ i:,l 91. :3:2 El 56 2 ~]' 75.03 N 9$;.6:3 W 124.72 N 53: 1 W 1.20 100.50 N 124.84 W 160.27 N 51 10 W 1.21 3500 ~4 12 N 43:~4 W · _-~60C. ,;.T,/._. 36 N 4:3 48 W 10C). 3464.47 ,1 O0. :3554.79 195.77 3387.47 .~ ,' 238. ,. :3 3477.79 128.~'~ ' 15 .97 ~.:~ N 1 W 1.~,.~.32 N 1:31.68 W 19:=:.94 N 4.9 48 W 24-1./:.4 N 48 45 W 2. Z-,1 100. o643.20 100. :3729.04 100. 3811.24 Lc,,.· 13 ,:,..,oc,. ~0 1.-,.,. 18 N '21.::. c,:, W 3~6, 31 ..... 3652 04 23A 62 N ,:..~o'"'~'", ,~:'-'-.:~ W 393 12 ~v~ - . ~-o-~. 24 '272. ~ 1 N 287./:,4 W · '"l i'"l i'l z.o,:,. 19 N 47 55 W · _.3.. 21 N 47 11 W 2:9/:,. 09 N 4/:, :":4 W ,'i -.._1 :3.51 4.20 4000. 40 42 N 42:36 W 4100. 43 42 N 42 18 W 4200. 47 0 N 42:36 W 4300 48 '"/. · o~', N 43 6W 4400. 4:3 42 N 43 48 W 4~00. 4o 24 N 43 42 W 4600. 48 18 N 4£) ~ ._0 W 1081=,m~ ~Ei~;. ~ 4~,5./:~1 :3,.-,1~.,. ~.1 .31:.~. z6 N .... O. 1-'- W , ~ ' ~, ~, ,~, , ~ ~ ~ . 1 10C). 72 ~ , )mq. o .7 '. EF3 4. ,, . W 100, 4232,98 817,33 41 ~E~N~~Y N 577,30 W 100, 42~9 ,45 8'~1 ,97 _.,~a.~,o~, 45 6~.:.'-'~.S, 70 N 627, 38 W .so 55 N 4.6 :3 W F,25_ ./:,0 N 45 ..,'--'~.. W 3. :3. ,FD 1 '""-"~/. 6:3 N 45 1~ W ..I .'. ",. 670.6(:, N 44 57 W 74._,.71 N 44 4:3 W 820.6.5 N 44 42 W 895.29 N 44 29 W 0. :B 1 2· :3'~ 4700. 48 6 N 40 42 W 4:;:00 .... 48 6 N 40 ~_,4 = W 4~;00. 48 0 N 40 48 W 1 CDC). 4366 .10 966 .50 4289 .10 _./- c¢.=,...., 2:1 N 100. 4432. q¢ .92 ,_ d 1040 .4:355. :3:3 751.65 N 100. 4499.72 1115.25 4422.72 ' 807. ~;0 N /:,75. oo · c... W '.'769 68 N 44 11 W 724 ._~. W 104:3.99 N 4:':: ._7 W 773. 15 W 111:::.24 N 4:3 44 W 0 1 '=' · 0.12 5000. 48 0 N 40 4:3 W 51o0. 48 24 N 40 12 W 100. 456.6.64 11:39.55 44:3'.P. 64 "':.' G' 100. 4/:.33:. ,;. 1264 .09 _,.._ _.. 29 864.15 N 920.84 N 821·71 W 1192.46 Iq 4:3:3:--: W 870.1°~ W 1266.91. N 4:-_-: 2:3 W ('D. 60 · J.--OC 4:3 1:3 N :::9 48 W 5300. 48 24 N 39 30 W 5400. 4:3 42 N 39 24 W · · ~l · . · · 100 469':'] 75 13._,,3.80 4622.75 97:3 08 N 918 16 W 1:341 51 N 4:3 11 W 100. 47/:,/:.. 21 1413.52 4689.21 1035.61 N 965.83 W 1416.09 N 4F~: 0 W 100. 4832.41 1488.48 4755.41 1093.49 N 1013.4.7 W 14'70.92 N 42 50 W 5500. 48 30 N 2:9 12 W 5600. ~:--: 0 N 39 6 W 100 ~ ¢'':'' o Y o W 1565.7 '.P ':: 9 , ,o~,~.. 54 15/:,3.49 4821.54 1151· 5:": N 1060. ~' N 42 ._. W 100. 4965.1:3 163:8.09 4888.1:3 1209.39 N 1108.08 W 1640.'26, N 42:2:0 W 5700. 48 ic'.-, N oo._.,_, 42 W 5:30C). 4:=: 12 N :3:3 4:3 W 5900. 48 0 N 39 12 W 4;/~,4.84 1267.36 N 1154.~.=, W 1714,61 N 42 2(:) W 100. 5031.84 1712.58 ~ = ,:: ~ 10 o. 5 o9:~ 4:3 1787 1 ~' ..... 1.4:3 1 ._ ..._,. · ...... ........ o .=,r).z, 3°= 5F, N '1201 56 W 17:::9 08 N 42 11 W 100. 5165, 21 1 o :. 1.60 5088. c, 1 12:6:.'_-:. 39 N 124.6:. :39 W 1,_,c'/-_.._,:'. 40 N 42 4 W C'), 412 FD. 12 0. :]-:6 ARCO ALA:E;KA _M.. JOB NO: A!282RO.342-XG .... [J~ = 12 PRIJDHOE BAY, NLRTH oLJFE, ALASKA L.L MF LI 1 A T I ON PAdlF NO: :3 TIME DATE ,, "' TRUE :i ~' ' m ' C: 0 ¢' - MEAc, URE£ DRIFT DRIFT COLIRSE VERTICAL VERTICAL SUBSEA R E C T ~ N G U L A R L ._, U R E DnGLEG DEF'TH ANGLE DIRECTION LENGTH DEPTH SECTION TVD C 0 0 R D I N A T E..,':' DISTANCE DIRECTION :=;EVERI'I'Y FEET.. ..... B .... J~__.,~ D M FEET FEET FE. ET FEET FEET FEET D M DO/100F7 ,/:,00CD. 48 30 N 38 48 W .__(::. CL~4.___J 4.8 24, N "'..:,o '~. .'=,._4 W 1 CDC.') =o.~ · ' '¢ ~ "' '.)CD =j~.:,. 80 1.9:36 20 5154·8) 1441.37 N 12o5:34 W lrY..~7. N 41 57 W m m · ' ,' · · · 100. =,ooo ....12 .'011 05 =.OOl 12 14~Y.~ 6,3 N 1342.~,°° W ~C'" )1~ ~' 64 N 41 50 W /-,200. 48 3/-, N 39 18 W 6300, 48 o/-, N 38 42 W 6400. 49 6 N :39 42 W · 51 W 2087.45 .... c,..,7.79 N 1 , N 41 44 W 1 CDc) 5364 28 2C)85.94 5287 38 1 == ..,~ "-" °,., ... 100. 5430 .51 2160 .94 ~.~.~....~m~. 51 1616 . OE, N 14o :,. 71 W~' 1/-,2 . "'"'.:,o N 41 .:,,z,~'~" W z.,:.,~7 61 N 41 ~"~ 100 5496.31 o.,,m/. '24 5419.21 1674.44 N 1484:30 W '-'""'-' · =,._, W C), '='/. 0.45" 0. '70 ..,,.,61 92 2311 71 ~n~,n 92 84 N 1532 10 W 231c' ' .-, 6500. 48 54 N 38 54 W 100. ==. . ~,~,:,-,. 1732.. ..,. 0- N 41 ~.~"F~ W ..... · _4. N 41 W 6/-,00 49 18 N 38 48 W 100 5627 3:-) 2387.2~ oo..,0:39 17~1 72 N 1._,7~. 51 W 2: :J :-: :-: . F; 24 6700. 48 54 N 38 30 W 680c) 4,~ 42 N . o,~ 24 W /_-,gCDC). 49 6 N '"~' '"c · :,,:, .:,-) W 1 CDC). =',.,o¢~'"; ~-. 86 2462. o7~' =,.,61 .=,,.. E, 6' 1 ~'=c,..,0.74 N 161:'-'/"'.. 72 W ,:46,4" .04 N 4.1 19 W lc)0 5758 73 ~_=~,o =-,~ 909 673. 2539 18 14 W ~.j.~,~ 09 I 73 I 67 N 1 51 W N 41 . . . ...m ,':, C.i m . . · 100. 5824.47 '2613.43- 5747.4.7 1968.68 N 1720.o6 W ..-..,14. 45 N 41 9 W cED. 46 0.21 0.41 7000. 49 0 N :38 48 W 7100. 49 24 N~,'~9. 1~'c, W I 7200. .=, ' 39 · _o 30 N 12 W 7300. 50' 0 N 39 30 W 7400. 4'..) 42 N 3'7 54 W 7500. 49 30 N 40 18 W 7/:,00. 49 42 N 40 12 W - -, - ..-, ~ ,- =c, -. ) " '=, /. ' 5'-' .-,/. o,~. 90 N 41 W 10j..5~0.ClJLm___?_.6688?,,:.,'::,,~~l:..~,_.cJ_L z0~7.66 N 17::.7..-.~ N .,:.. ........ .5 u '-,.-.,,'-. 07 40 5.?, u 10 '" ' ':' '~" 2$., ,.- 1.23 W 29;o5.:34 N 4, 0 54 W 100, 6212, q'"'.'..:, 3070, 6/-, ~c, ', "~b~E~-/2~?LA~'E:'GiDMF~y.= ........ ~.:',~, ~..- N '2010 ,28 W '-.z:('J71 ,49 N 40 ~"'°,.-:, W 10c), 6277, 74' 3146, :=:1 6200, 74 238c),:37 N 2059, 4:=: W :]¢147,64 N 44) 52 W 0. :2!5 0.55 1. 10 C). · - ._mm ciD. 4:3 0. cid...'? 1 7700. 49 30 N 40 6, W 7800. 4':} 24 N 4c) 12 W 7900. 49 42 N 4C) 24 W · · ~'~61~. 56 2438 58 N 210,=,.59 W 3223.79 N 40 51 W 100. 6342 5/., 3222 ~/., "~. · ~' 100. 64c)7.57 32~8.94 6330.57 2496.65 N 2157./:,0 14 .:,..-.-.'-'"°':-=~.; 77 N 40 ~'._ 0 W 100. /:,472.44 3375.03 6395.'44 2554.69 N 2206.81 W :3375.86 N 40 49 W 0.21 0.13 0.2:4 ~' D'. :30 '='F :3451 18 6460 26 2/-,12.77 N 2.':,MA 06 W '-' ='-' 1 N 4.0 W .::OC 0 49 N 4cED 12 W · 1 c) 0. 6537. ~.: ...... .:,4._, .'. 0 4'..) 8100. 4?/ 0 N q8~ 3/-, W 100. 6602.53 3526.c~':'.. ~, 6525.53 2671..::1 N 2304.14 W .:,~.~7.75 N 40 4.7 W 0. ' ./ 1. :.:.:1 ..:.. .............. :,0.:. A'-.-., Iq 40 44 W 10c). /-.668.20 3602.33 6591.20 2730.41 N '~qSch ':i'.,':) W o/ ---.... 100. 6734.2:3 3677.2:2 6,/,57 . .c|?,._ ~-,7c.C/_~... · 44 N 2397 .27 W :2:/.,7:5:. 03_ N 40 41 W · -' '-' '~ .~i '-' . 100. .68c) 1.12 3751.71 6724.12 2:34:3.29 N -.'44.-'.:34 W ._7._~.:37 N 40:37 W :3'.2 6.2 o._,00. 47 1Z N :2:7 12 W 86c)c). 46:30 N 37 12 W ~,o.-,/. 03 N 4.0 32: W 100. 686:3.61 :2:825 .45 6791 .61 .-.c'¢~r'x.--,. '..)5 N 2487 .61 W o~,.' .... 100. 69:37. O0 3898.34 6860. c)0 2965.06 N 25:31.72 W :2:8'~:=:. :37 N 40:2:0 W 0.7::: ' 0.70 8700. 46 6 N 37 6 W 880c'D. 45 c) N 36 1:3 W 8900. 45 30 N 36 0 W 100. 7006.09 3970.58 6929 0¢Y 3022 68 N ...,/~ .l.:~: W 3971 04 N 40 26. W lc)0. 7076.12 4041.87 69~'?. 12 3079.92 N 2618.04 W 4042.28 N 40 ;:.'2 W 1 CDC) 714/: .... o . . . . · ~.. 4112.76 706.9.5L-' 31:2:7 27 N ~- ...... v._, W 4113 11 N 40 1:=: W 0.41 1.24 0.54 ARC:O ALASKA, INC. _.[._~ 12, WELL NO: 184 GMS~ , , , C(]P'IPUTATION F'AbE NO. 4 JOB NO: A1'',~'~'~r''''n''' vc~ TIME DATE ' ,~. ,'"" -'"- I-~ ~.' .""' "? ."'- ~ A . , ~ [ PRUDHOE BAY NORTH SLOPE, ALA._F...A TRUE 1:3: ._, ~. 21 17- J A N- 8:3 MEASURED DRIFT DRIFT C:OURSE VERTICAL VERTICAL' SUBSEA ,R E C T A N G U L A.R C L. 0 S U R E DOGLE:Gi 'DEPTH ANGLE, D I RECT I LIN LENGTH DEPTH SECT I ON TVD FEET D M D M FEET FEET FEET FEET C 0 0 R D I N A T E c. D IoTANL. E D IREL. T ION SEVER ITYI FEET FEET D M I]G/10C)F'I't 9000. 46. 18 N 36 0 W 9100. 46 4.2 N ~:5 6 W 920C~. 46 54 N .34 36 W . .-.~.11 .::1 .:36 N ~70~.14 W 41o4 72 N 40 1:3 W 100. 7216.11 41 o4 4.4 71 ':'" 95 ._-, o .~ . 100 7284.94 . ~.~ ~,, c, .. 7207 ~4 3254 ~":' W · :,,-, N 2744 W 4~..,7 02 N 40 8 . . . ..... 4.:,~ ~. 61 N 40 :3 W 100 735:3 40 43')9 45 7276.40 3:314 20 N 2785 97 ~ .... '" 0. :30 0.77 0.42 ~.~300. 47 54 N 34 4.2 W ?400. 48 0 N :34 36 W 100. 7421 08 4402 77 7344 08 , 35::74 75 N ,-.--.o-~ 8 N W ~.,:, ..:. I W 4, 402 c,9 :::'T~ =~':' 100. 74:38.07 4476.75 7411.07 :3435.83 N 2870.0'2 W 4476.82 N :39 52 W 1.00 C). 1~'=' 9500. .4:3 5:: 6, N 5::4 .:,0 W 9600. 49 0 N 34 54 W ~ 4...,~,1 16 N .:,. 47 W · 7..,~,4. 4551 32 ~' .... :Y 100 == =¢ · . ,.,~,' .13 7477.59 3497. N 2¢/1~. ....6, W == ., .:_~. =- .-, ..-. ~.~,.-. .-,,-,,= ~- ,~ 1.00. 76..-U. 46 4626. ! 0 7~.,4.-,. 46 ~,.,.. ~ · 1'8 N ..',-,._,;J. 1 W 4626 · 1 i N ..:,.~'-"- 42 W 0./=,0 ¢). ), ..... 100. 76o~,.67~'= 4701.63 7608.67 5::621 ........ 55 N 2998 30 W 4701 6,4. N c:9 2:7 W . .56 7673.41 36:34.37 N 3041 47 W 4777 56 :39 '::':' 100. 7750 41 4777 . . N .... W lOC). 7814.89 wo~,.:."'-'=~'. 68 7737. o:,~'° 3747.47 N .:,0E, 4.60 W w,: ...... 6? N z,:, W 0.71 ('), 18 0.4,9 10000. 49 42 N 33 36 W 10100. 49 '-',:,0 N ...,'='2 ~,.4 W 10200. 49 36, N' 3:3 24 W 1030C). 49 61 N~-~.~':' 42 W 10400. 4.9 6 N :-":2 30 W 10500; 48 5::6, N 31 lo ~' W 10600. 4:3 4:3 N 31 6 W 0.49 0 0.39 0.7:]: 0. 15 1. ()3 0 · '"' ''='' 10700. 48 0 N 30 18 W l"-'c' . . 54 W 10S/C)0. 46. 30 N 3C) C) W 100. 8337. ~''' . N 41 W · ,:,~ ._,4._,4.31 . o,:, -.,~,- ,:,. 10 N 340'FY 52 W ,-,'~,- -~ ...... 10C). 8405.12 5527.32 mo'-.o. , . ~...~.,',.~ 12 4322 14 N 3446.64 W 552:_--: 13 N 38 34 W 100. 8473. ~2 ' 5599.43 ~'~'¢,~ ~ 5600 .=, ,:,o 27 W oc .... ~,..::2 4385.50 N 34c'° 16 W 4..- N ~"'-' · -- . m.m ._I · · 1.00 0.58 1.00 11000. 45 48 N 28 18 W 11100. 45 1E: N 26. 18 W 10C) ':'.~4'-, 59 5670 3& 846.5 59 444:3 48 N :351:3 .-,o · .',_, W 5671 /=,2 N :]:8 20 W · ~_m,_ _." · · -- · · ,m · 100. 8612.62 5740. i 2 A5,.._'._'::5.6.2 4511 · 91 N 3551.02 W 5741 · 7(:) N :3:3 12 W i .51 11200 44 12 N ~.s 1:3 W 11:300. 44 0 N 25 C) W 11400. 4:3 18 N 24 42 W 100 '-'/R'- .=,~ ~ .:.5o 5'-' 4:3 .:.: .... ~.64 ._,~0...50 :3606.6,4 4575.30 N 1 6.6 W ._o10 N :]::3 W · ._m._ m_m · · ._ 100. 8755· 45 5875.91 8678.45 4638.29 N 5::6.11.24 W -5E:78.33 N 5::7 54 W .:.7~ .) ~:1 470(') 92 N 364A 75 W 45 N :]:7 4.5 W 10(;~.~ :9827. :31 5~42.67 ~-' 5('. - . . ' 59 .59 115C)C)·. 42 42 N 24 0 W 116(30. 42:30 N .-'='._, '-~ 42 W lC)C). 8'FY00.94 60C)8.49 o'-'°'-'"'~....:.. 94 4763.06 N 3668 · 37 W 6011. . '.-'y6 N :]:7 36 W .......... · =,6.~*._,.74 W 6077 72 N :]:7 27 W 1¢)0 8'F'74 55 607:3 6.5 8897 ~.=, 4c":'4 96 N '-' '-= 0.77 0. '=-:9 11700. 42 12 N 23 24 W 11:300. 42 4.:3 N .s:2 1:3 W 100. 9048.46 6138.40 8971.46, 4886.72 N 3722.,65 W 614:3.14 N 37 18 W · · · '":' -),-, ~,-, lC)C). 9122.1:3 620:3.11 9045 18 4948 9:3 N 3'748 :--::3 W 6zL.:,.._.=, N :]:7 9 W ARC:O ALASKA, INC:, : ' D'~ _12~ W F LI - . _ I- ' ""' -I" '-" F:'R~ iDHnE BAY., NJF:TH .=.LLFE C:OMF'LITATI r~N F-'A~SE NO. 5 TI ME DATE 1 ~-:: ~.~:'="~.: 21 1 ?-,J faN- ~,~, MEA.:,LIRE[ DRIFT [.RIFT COLIR::;E VERTICAL VERTICAL. c:IIBSEA R E C T A N O U L A R C L' 0 S U R E DOGLEG DEPTH ANGLE DIREC:I'ION L_ENGTH DEPTH SECTION TVD C 0 0 R D I N A T E $ DI.STANCE DIRECTION '.E;Ek)ERITY ........ E~.~Z ~! .......... M D M FEET FEET FEET FEET FEET FEET D M DG /iOOF] 77. ';~17:3. .6:3 '-'~-~c Jo 'P 10 1 6,.,-° 4997 3:3 N 37A:~ 74 W /--,s':~..,~ ..... 17 N 37 I W O. OC) THE FOL. LOWING STATION I$ PROJEJCTED '= O"'. W 11 ¢.~'0 z '-, 4© ':"".~ 1 ;3 =;':' ':'7"-~ 1 '7 ,..,7 /~ .-.,07 ,.=,1 5' ~" ..... ,l,z .... N W ..... ,...--,_,-. 4.7 140 ._7 o0.::0 7() N .=-:7:=:2 40 W 6294 00 N :36 '-~ O. 00 D I SI"ANC:E: /.., .... -:,,--/zl... 00 FEET ARCO ALASKA, [..:, 1 WELL NO' lfY GMS ' · C: Fi M P LIT A T I 0 hi ,.lOB NO: A1282R0342-XG TIME DATE . F AbE iqO. 1 ,, PRLIDHOF2 BAY~ NORTH .=,LJFE, ALA.=,KA ,.,- ..... 14 1 ..... IflN ...... . MARKER-- TRUE C:;LIB'.=;EA CODE MEA.:,_RED VERTICAL MD-TVD VERTICAL. R E C T A N G IJ L A R C L 0 ':' LI 1.2 E NAME DEPTH FiEF 7 H D IFF [.. EF TH FEE']' FEET FEIFT FEET ~' .=,9' AN _.E D I REr:T I FiN C: 0 0 R D I N A T E .:, r~I'"" ' r" FEET FLEE]" D M - i, ~-. F.. FEF .:,A=, RIVER TOP '.'3HLIBL I K A TOF' .:,HUBL. IK B TOP .=,HL BL. I K C I OF SADLEROCHI"F 4608.68 N ':-' 5 ¢17... .. .. _. 34 W 4623.17 N 3604.14 W 41-,~S:.~-''-''. ~. ..,,- N 3618..,:.0 W 1LF ZONE 3 WATER MOVED FROM 11605. C;0 11666,. ':'":' '-' :3/_', '..:~ 7 ') '- 4,., ~ o. 05 N . (. ,:~ W ,:,c,.J.72 N 3713.50 W '#j '#' ."-! mm-i -r. z i.. NE ..: / W. MOVE D T 0 1 16,:,._,. O0 0 / W C:ONT A C:T 11760.0 C) F'B T D I 18'77.00 o ;~60. :3'7 9015.6,9 9101.6:--: 4,:, 77.46 N :3'71,.'q. 6,1 W 4924.07 N 3738.;::'F.~ W 4.997. :~'- . · .,~ N 3'7/:,:3 74 W 61':":' '="':' N :7=:7 .1.9 W .1, 82.40 N 37 1'2 W 625':.-~. 17 N :37 I W TI] .... ,,, o.,:,z 40 W ,Whipstock. ' A PE'rROLANE COMPANY 6,.~ .-. 4 00 hi :-':6 56, W Eastman/ Whipstock A PETROLANE REPORT of SUB-SURFACE* DIRECTIONAL SURVEY ARCO ALASKA, INC. COMPANY DS 12, Well Number: 19 WELL NAME JA N2 ~ i983 Alaska Oil & ~as Cons. c,,,.~n_/' Ai~.u'i~orage "zssion Prudhoe Bay, North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY Teleco/Directional Single Shot DATE 13-Dec-82 SURVEY BY Dale Rendrix OFFICE (Cont~.o.l!ed Drilling Consultants) ) DS 1'2, WELL NO: 19 D::;S/I"EL. EC:O (CDC) "'" ~ ' ALASKA F'RUDHOE BAY, NORTH .:,LEFE, i.._____IELEC.fl ~__(L~I_i~.q~rL..MI!, .... DB.I LL E El.: .... D, BL E.... ~,.Ig N 5!B.I.X .......... ,, . ] SURVEY F'ROVIDED BY C:C;NTRiZILLEr~ [IRILL I NO CONSULTANTS. , .......................................................................................................................................................................... i ) \ "t ................................................................................................................................................................................................................................................... V_E..,R_'TICAL SECTI ON CALCULA I ' A II~ REC:ORD CIF SLIRVEY R~l-IIl_l.'__.; OF C:URVATURE HETHOD "i ARC:O ALASKA, INC. ' · iD.'_'-; 12, WELL NO: 19 D'._:;S/I'_E._LECI~ ........... F'RLIDHOE BAY, NORTH SLOPE, ALA.:,KA 1 " TRUE 'i~ MEASURED DRIFT DRIFT COMF'LITAT ION PAGE NCI ' ( C:DC ) T I ME DATE 09: 03: 43 11 - J A N- 83 .... ,-ll ~.l= . DOGLEG j F:I-II IR'.::E VERTICAL VERTICAL .=,_B.:,_A R E C: T A N O I_1 L A R C L 0 S U R E C 0 0 R D I N A T E '.3 DISTANF:E DIREC:TION '._:;EVERITY! DEF'TH FEET ANGLE DIREr:TIOI',I LENr'.;TH DEPTH D M [I M FEET FEET SECT I ON TVD FEET FEET FEET FEET D . M [lO/IOOFT!' ,J C). '0 C) 0 0 C). O. O0 2429, 0 0 0. (') ~....._'", a ._:,,--~... 242..: 9 .0 C) C),. C) C) .-- 77.00 C). C) O C). C) C) ' O. O0 C) C) C). O0 2::::52. O0 C). O0 O. O0 O. O0 C) 0 6,,:,.. 87 4.77 :~[:, 1.. 8'7 . .:, 54 N 7:3 (") W 1-'-' '"='- .... . ~.7,_,4.6,1 23.57 2'7C)7 6,1 27:-':6,. 9 0 N 6,1 C) W 18'P ":' ':' . 29'4P; 12:3(:) N :36 0 W 1=~' 6,:3 8(1) <3 0 r...-.._-~ .-,,"',/..'-. · :, ~. ' 2940 ":"' ':3134 1'-' ~, .~ N 45 (:) W 1~"':~ ~' . . ~'" . · c, "C o:.. c,I~Z~ c, 4 lC)3 06 .:,.)4.!5 84 ~ .-~~ .~, .~ ~ - ,.-~ ~ ~,-~,,- ,-,. .- .?.-~ · ............... ........... .......... ................ ........ .[ .............. ....... 11 ""'='("~ 24 '-' 68 '"' .. · :,~,.,~. 24 N 44 0 W lo6. 34. 86 ~'-'~'~.:,~,. E,,:, c,~ ..... ...~"t ,86 '-~ ~'-~"~ 2 ~ = . ._,4 N 42 0 W 21'7 :3661 88 3:34 68 '"'~':"' 88 :3940 ~'~' ':'c'~c' 12 456 E:5 3'7~,~5 12 . .:,,:, 24 N 41 36 W 21~',=,. ..,~,~. . . ................................................. 4186,. 4.6 ..~0'-'" N 40 12 W 46,,:,..,. 48 C) N 41 36, W 5211. 48 18 N 40 12 W 5730. 48 18 N 39 30 W ~ '-'= '-' 30 48 ........... ~.:_,: 1_. .......... ,4..~, N '~'-' ...................... :.-..'t~ .......... .'_ W 6,7(1)6,. 49 6 N :37 42 W 7227 N W · .50 0 37 24 1.6,7 N 5.47 W .y~-, N 24.97 W 29.44 N 47.n0 W 6,7.79 N 79.75 W 111.67 N 123.63 N 162.54 N 173.62 W 2:34.9:3 N 241.12 W 326. (:)7 N 3:22.6,2 W 7750. 49 18 N .38 6, W 799:3. 49 12 N...-,=, 0 W .... E____j23_:Z... 48 18 N 37 0 W 4~;,,~,,,,,;~ 4o~.._.. 4~ /.-,.,~.,.. 7~ ..-~.. ~1 ~. 4... 4,_ 1.46 N 4.:~1. z3W 4..c" ~.?;'~:~.:; .... 4..6~...3 '~' ~ . ...... ~'~'"' ''''~ '' ?':""':~ ',~,.,.~i~!. '"'.~...~ ' o~: o. 71.14 W W ~ ,;~:~:,~ ~;C)5O ~.,-: "' :-'.,: ~ i~ o c..:: , ~,~.~ -) . ..... ........ , ~.-, ~,~,,,~= .-,,~ .-,. ,~ ..... ~,, , 98 W ~ .... ~.,70.:,. ~ o ~..,u0. 04 ~,,.:.~ .... . ..... ~,. := . ¢~ ~ 1~ .... 6o ~ 26,.88 N 6,6:16 W 5.72 N 73 0 W 2.32 55·46 N 57 56 W .:,".6,2 C). O0 C). C)O 2.78 104.6,7 N 49 .:,""° Wo 166.6,0 N 47 == · .,.Z, W 237.83 N 46, =m~,.., W 336.6,5 N 45 45 W 458.70 N 44 42 W 3. z ' · .'."'" O0 i' 624. :3:2 N 4:3 41 W 99C).4,6, N 42 39 W 1382.13 N 42 10 W 176'P.4C) N 41 39 W 2158.68 N 41 12 W t ::' :31 J · _~ · O. 36[ C). '21 (:). 1 C) O. 11 .. O. '2'2 ' C). 18 ......,_, ....:,', 6o,:,0'""-' ,61 :'_-:294.. 6::: 6,:'::C)3.6,1 ..._,.....-'"' '='''''' . .=,¢)_ _ N "~ 119 ,51 W 3294 .74 N 40 ".'.." W C). 17 . . . .:. :Y 56. (') 05 24:3· ='-'" 6,._,.:,;~ 2:3 '" '- 2667 49 N 97 W :3478 74 N '~'- W . .:,47,_x 67 6,46,2.2:3 ,..,_._'-'. ",'3'-'...-. . 244. 67C)0.11 3:/_-,6.1. ?.-T~ 662:3.11 281:3. C)2 N 2344.6,4 W 3662.0:3 N 39 49 W' O. 48 8757. 45 1'2 N :36, 0 W ._,~:(.)~'-". 7056.36, 4040 ....16, 6979:36 :3117.45 N 256'B. ?'C) W 4040.16 N ..,'-"-.~ 3(:) W O. 6,1 'F, 306.. 47 24. N 34 30 W s ¢, . ~,~ -'-'~'-'. .-_- . · _ 4 .'. ·74:35 /:_.3: 44.._' .... S/1 7._-.._ o 6:3 3:441. ~5 N 277F-:. 96 W 443:6.. 04 N 3:'.:'/ 7 W 0 45 1(]).'-':42. 4'9 .'_-:6. N 31 (') W 516.. 8113.91 5'214.12 80:--:6.91 40S/6.. 12 N 3228.46. W 5215.47 N 38 15 W O. 41 105:~6. , 49 (') Iq :30 48 W 244 827:3 (')2 53'P6.'.-.-"~ 81'.T, 6 (])2 '-'~ . . · . . 4..'._4 ;34 N 3:32:3 45 W 5398.98 N :3:z: () W 0.25 ..................... ~ ........ - ................................................................................................................................................... 108:32. 47 6. N 28 54 W 246. 8437.46 5577.32 :FB:::60.46. 4413.51 N 3:414.51 W 5580.14 N 37 44 W 0.96 · '-":. -- Iq: '-' . . . N 37 19 W 1.26 11137 44 42 N 24 42 N .:.C)._, :364'.:.).70 5790.:~:-: ~._,7---.7A 460::: 9.5 N :3513 24 W 5795.28 11.'F7:30.' .... ~'~ ....... C-i '-~'~-~ ....... i:'.')'-~ .... 7'F/3"-' iT"::.J~.'6.~'F/ ' '6. :31._-': ' 5 ::'i .... [:/i4'~;~ ...... ~'b?3~'~,~'"N-'37~"~'--~--6'-324,E:1 Iq :3/:, 8 W C).41 FINAL C!'L]ibi3[i-R~-'"-'-' 'i"iREcT'IC~N: ................. N 36 DEGS" 7 HI-Ni3" :3-'i~' 'sE'-"S'-'Ei ....... D I ::;TANC:E: 6:324. ,::,'-'1 FEET DRIFT CHART"S RELATED DP~TA F][LE ARCO ALASKA, INC. PRIJDHOE BAY, NARTH °'' r ' '" -~ .=.L_IFE, Am_AoKA ,.{-'i~i~i'~O'~'~"-FILE' NLIMBER ! 475 '~ BOTTOM HOLE ASSEMBLY 't VALUES USED FOR DEPTH ARE MD i DEPI'H DESCR I PT I ON DR ILL I I',IG DAYS VALUES LISED FOR DEPTH ARE MD [,AY DEPTH · 1 110.00 2 739.00 :3 1721.00 2460. O0 5159.0.0 6778. O0 7 7638.00 :3 - 8466.00 S) 9125.00 10 9673.00 11 ' 10404.00 1 '2 106:30.00 3 11209.00 4, 11209.00 848. l:~ 0 930,'00 930. OA L.Eastma n ~ Whipstock A PFTROLANE COMPANY WEIGHT ON BIT WEIGHT I.~ GIVEN PER 1OOO F'OUND~ VALUES USED FOR DEPTH ARE MD DEF'TH WE I GHT 1 10. O0 O. O0 '":" ~ ./- ':' O0 70. O0 '""'"'":'"' O0 55 O0 10404. O0 60. O0 112 O':T,', 00 45.00 REVOLUTIONS PER MINUTE V~LI_IES LISED FOR. pEPTH ,ARE MD .......... _[L..E._P_.T...I:!_= ................ _R_;. F_'_,..M, , ............... 1.1_.[.!,,,_, £_~.C2_ 170. O0 .,.'"" '~, ._./- ~'":'. CD 0 15 O. 00 ,=,o ..- .:,, 00 170,00 10404. O0 15,n. O0 L,Eastman Whipstoct¢ A PETROIANE COMPANY 112 CD 9.00 ? 0.00 t J Suggested form to be inserted in each "Active" well folder to d~eck for timely compliance with our regulations. Operator . Name and Number Reports and Materials to be received by: D~te Requi.red Date Received Remarks - ComPletion Report Yes Well HiStory Yes _Samples . ,~ Core Chips --'--~. ~ /7/~/ . Core Description F'~J/~P~-- · Registered Survey Plat ~ Inclination Survey . , 'Directional Survey Drill Stem Test Reports Production Test Reports · · . . '' '~. Logs Run. Yes / .. . Digitized Data ~ / _~ /~. ~ ,."'! ' i, , ,· , , , , ,, ~'""'"' Anchorage. Alaska 99510 Telephone 90'"~'77 5637 February 3, Reference: 1983 Arco Cased Hole Finals · '.o i D.S. 2-11j 12-27-82 , D.S. 12-19-~12-23-82 12-23-82 t D.S. 13-16~12-31-82 ~ D.S. 14-26~'-12-29-82 ,'D.S. 14-30 ~'12-25-82 , D.S. 15-5-/ 12-30-82 · D.S. 18-10J12-18-82 P.A.L. cBL/VD CNL Perforating Record Perforating Record Completion Record Depth Determination Completion Record Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 Run 1 11 5" 5" 5" 5" 5" 5" 5" Sch Sch Sch Sch Sch Sch Sch Sch se sign and return the attached copy as receipt of data. Kelly-McFarland AFA-403 Trans. ~ 115 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO- MARATHON CHEVRON ARCO Alaska. Inc. is a Subsidiary of AllanticRichfield.Compan¢ EXXON MOBIL GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska, Inc. Post Office F~''-'' 360 Anchorage. A,.,ska 99510 Telephone 907 277 5637 January 28, Reference: 1983 Arco Open Hole Finals D.S. 12-19 12-17-82 CPL/Cyberlook Run 1 5" 12-17-82 BHCS Run 1 2" 12-17-82 DIL/SFL/GR Run 1 2" 12-17-82 FDC/CNL (Poro) Run 1 5" 1217-82 FDC/CNL (Raw) Run 1 5" scn & 5" & 5" ~sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 095 DISTRIBUTION NORTH GEOLOGY R & D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOB I L GETTY D&M DALLAS F EBb'-" Alaska Oil & Gas Cons. Commission Anchorage Post Office Box 360 Anchorage, ~""~ka 99510 Telephone 90, ~/7 5637 January 18, 1983 Reference: Arco Directional Surveys D.S. 1-24 12-3-82 Single Shot EW D.S. 7-17 12-8-82 Single Shot EW D.S. 12-19 12-13-82' Single Shot EW · Please sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9-051 DISTRIBUTION NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON EXXON MOBILE GETTY D&M STATE OF ALASKA DALLAS ARCO Alaska. Inc. is a Subsidiary of AllanticRichfieldCompany ARCO Alaska, Inc. Post Office.~-%x~ 360 Anchorage, ska 99510 Telephone 907 277 5637 January 11, 1983 Reference: Arco Magnetic Tapes and listings , . D.S. 7-17---'12-16-82 D.S. 13-11f12-13-82 D.S. 12-19/12-17-82 D.S. 12-19/ 12-23-82 D.S. 1-24 12-14-82 D.S. 14-19/12-9-82 D.S. 14-15/~12-6-82 D..S. 3-15~ 12-9-82 OH tape 66202 OH tape 66160 OH tape 66203 CH CNL 66233 OH tape 66173 Sch Sch Sch Sch Sch CN/,MSN 1567. DA CN/MSN 1564 DA CN/MSN 1573 DA -ase sign and return the attached copy as receipt of data. Kelly McFarland AFA-403 Trans. 9 026 DISTRIBUTION . ~OLOGY R&D DRILLING PHILLIPS SOHIO .MARATHON CHEVRON EXXON MOBIL GETTY D&M GEOLOGY STATE OF ALASKA DALLAS ~'~ ARC(~ Alaska, Inc. Post Office £ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 13, 1983 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' State Reports Dear Mr. Chatterton' Enclosed are monthly reports for December on these drill sites' 1-24 13-14 1G-7 2:11 13-98 1G-8 7-16 1E-22 WSW-8 7-17 1E-23 WSW-9 7-18 1E-24 WSW-IO 12-18 1F-2 Tract Well 24-11-14 12-19 1F-3 CIRI Wolf Lake Well #1 13-11 1F-4 Also enclosed are well completion reports for' 1-22 13-13 1-23 14-6 6-24 1C-1 7-15 1C-IOGI 12-20 '1E-25 13-6 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including subsequent Sundry Reports for 7-17, 13-6, 14-6 and lC-1. Since the information on the Wolf Lake and Tract wells is of a confidential nature, we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JGL28'llm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany Oil & Gas Cons. C0mmissi0~; Anchorage STATE OF ALASKA · ALASKA _AND GAS CONSERVATION CC '911SSION 1. Drilling wel(X[~ Workover operation [] 7. Permit No. 2. NA~), o~r~t~[(a' Inc. 82-198 3. A~d. res(~. BOX 360, Anchorage, AK 99510 5o- 9. Unit or Lease Name FSL, 934' FEL, Sec. 18, TION, R15E, UM Prudhoe Bay Unit 4. Location of we~72a I at surface 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 6. Lease Designation and Serial No. ADL 28330 10. Well No. 12-19 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of December ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1330 hrs, 11/30/82. Drld 17-1/2" hole to 2460'; ran, cmtd & tstd 13-3/8" csg. Drld 12-1/4" hole to 11209'; ran, cmtd & tstd 9-5/8" csg. Drld 8-1/2" hole to 11930' TD; ran logs; stuck tools & recovered. Ran, cmtd & tstd 7" liner. Running tool backed off & was recovered. Ran CBL. Ran 5-1/2" compl, assy. Secured well & released rig @ 1800 hrs, 12/25/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 9~.5#/ft, H-40, weld conductor set @ 79'. Instld w/1850# Poleset 13-3/8 ,72.0#/ft,L-80,BTC csg w/shoe @ 2429'. Cmtd w/1800 sx Fondu & 4(~0 sx Permafrost'C. 9-5/8",47.0#/ft,L-80,BTC csg w/shoe @ 11191'.Cmtd w/500 sx Class G & 300 sx Permafrost C. 7", 29.0#/ft, L-80, BTC csg f/10887'-11920'. Cmtd w/350 sx Class G. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SP/BHCS/GR f/11925'-11169' FDC/CNL/GR/Cal f/11925' - 9-5/8" shoe CBL f/11843'-10770' CNL/Gf, p/11290'-2400' 6. DST data, perforating data, shows of H2S, miscellaneous data N/A Alaska Oil & Gas Cons. COmmlssior~ /~chorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S,GNED ,/'-/~-~'~'' %- ?// /~Z~'->~'~J T,TLE Area Drill ing Engineer DATE //' O//S~ l~ NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU1/MR7 Submit in duplicate DS 12-19 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1330 hrs, 11/30/82. Drld 17-1/2" hole to 2460'. Ran 58 jts 13-3/8" 72#/ft, L-80, BTC csg w/shoe @ 2429'. Cmtd 13-3/8" csg w/1800 sx Fondu & 400 sx Permafrost C. ND 20" Hydril & diverter. Pumped 100 sx Permafrost C top job. Instld 13-3/8" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 11.3 ppg EMW - ok. Drld 12-1/4" hole to 11209'. Ran 291 jts 9-5/8" 47#/ft, L-80, BTC csg w/shoe @ 11191'. Cmtd 9-5/8" csg w/500 sx Class G. Set 9-5/8" packoff & tstd to 5000 psi - ok. Drld FC & cmt. Tstd csg to 3000 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 11930' TD (12/16/82). Ran DIL/SP/BHCS/GR f/11925'-11169', FDC/CNL/GR/Cal f/11925' - 9-5/8" shoe. Stuck tool @ 11740'; recovered. Arctic packed 9-5/8" x 13-3/8" annulus w/300 bbls H20, 300 sx Permafrost C, & 120 bbls Arctic Pack. Ran 26 jts 7" 29#/ft, L-80, BTC liner (w/tieback receptacle) f/10887'-11920'. Cmtd 7" lnr w/350 sx Class G. Baker running tool backed off & was left in the hole. RIH; latched onto fish & recovered. Drld cmt to 11877' PBTD. Tstd lnr lap to 3000 psi - ok. Displaced well to NaCl. Ran CBL f/11843'-10770' & CNL f/11290'-2400'. Ran 5-1/2" completion assy w/tail @ 10917' & pkr @ 10826'. Tstd tbg hanger & packoff to 5000 psi - ok. ND BOPE. NU tree & tstd to 5000 psi - ok. Displaced tbg to diesel; back-flowed 30 bbls into ann. Dropped ball & set pkr. Nipple for SSSV @ 2211'. Secured well & released rig @ 1800 hrs, 12/25/82. JG:llm 01/03/83 GRU1/DH5 ARCO Alaska, Inc. · Post ~ffice B~ 360 Anchorage, '.ka 99510 Telephone 90~ 277 5637 December 9, 1982 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine. Drive Anchorage, AK 99501 . SUBJECT State Reports Dear Mr. Chatterton' Enclosed are monthly reports for November on these drill sites' 1-22 13-6 1-23 13-11 1-24 13-13 6-24 13-14 7-15 1C-9GI 7-16 1C-IOGI 12-19 1E-24 12-20 1E-25 WSW-6 WSW-7 WSW-8 At so enclosed are well completion reports for' 1-21 1G-4 6-23 WSW-4 13-15 WSW-5 18-10 WS.24 1F-7 The survey for 2-22 needs to be reran; a completion report for this well will be submitted when an approved survey is received. We also are including a subsequent Sundry Report for WS 24. Since the information on the WS 24 well is of a confidential nature,.we would appreciate it if you could store it in a secure area. Sincerely, P. A. VanDusen District Drilling Engineer PAV-JG'sm Attachments GRU1/L3 ARCO Alaska, Inc. is a subsidiary ol AllanlicRichfieldCompany ' STATE OF ALASKA ALASKA C AND GAS CONSERVATION COl llSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well ~]X Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-198 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20870 9. Unit or Lease Name FSL, 934' FEL, Sec. 18, T10N, R15E, UN Prudhoe Bay Unit 4. Location of Well 572' at surface 5. Elevation in feet (indicate KB, DF, etc.) 77' RKB 6. Lease Designation and Serial No. ADL 28330 10. Well No. 12-19 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool November 82 For the Month of. , 19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 1330 hfs, 11/30/82. Drld 17-1/2" hole to 1337' as of 11/30/82. SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40, weld conductor set ~ 79'. Instld w/1850# Poleset. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run None to date 6. DST data, perforating data, shows of H2S, miscellaneous data N/A · ~.~.l~sl~a Oil & Gas Cons. Commis~;io,~ A~chorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~'~ Area Dril ling Engineer SIGNED TITLE DATE NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 GRU1/HR7 Submit in duplicate DS 12-19 DRILLING HISTORY NU 20" Hydril & diverter. Spudded well @ 1330 hrs, 11/30/82. Drld 17-1/2" hole to 1377' as of 11/30/82. JG'sm 12/07/82 GRU1/DH5 RECEIVED Alaska Oil & Gas Con,s. Commjssjo,~ ~lcho[a§~ MEMORANDUM Sta e of Alaska ALASK~OIL AND GAS CONSERVATION COMMISSION To:c. erton DATE: E~cember 13, [~LE NO: 108A/I Lonn~e C. Smith Commi ssi°ner TELEPHONE NO: FROM:~d~r We Sipple~ Jr~ Petroleum Ins~ctor 1982 SUBJECT:Witness BOPS.' Test on ARCO's DS 12-19 Rowan Rig 26 Sec. 18, T10N, R15E, Permit No. 82-198 Thursday, _December 2~ ~19_8~ - I traveled to ARCO's D8 12-19 Ro%~-~n Rig No. 26 to witness a BOPE test. Upon arrival at the drilling rig they were in the process of cementing the casing. The DOPE test commenced at 8:45 p.m. and was conclud, ed at 7:45 a.m. D~cember 3, 1982. There ~a~re six failures, the well sign ~s not current and there were four valves on the mt~d cross that leaked° Replaced. the four valves, all tested except one valve. ~r. John Emery, of ARCO, will call the A.O.G.C.C. office when the valve is replaced and teste~ to 5000 psi, he %~11 also notify the A.O.G.C.C. office when the well sign is updated. The A.O.G.C.C. BOPE test report is attached with this re,rt. In sum~ry, I witnessec~ the BOPE test at AP, CO's DS 12-19 P..o%,,~n Rig 26. Attachment: ~r. John Emery of ARCO called this office on r~cember 7, 1982, the well sign ~s updated, also the valve was changed out and tested to 5000 psi. 4181 STATE OF ARAS1:.\ AIASKA C & CAS COL~SERVAT.[~ ': ! :?CHbIISSION B.O.P.E. Inspection NeF©rt BOpE Stack Annular Preventer---- pfpe Rams B1 ±nd Rams Ch,o~e LLne Valves. H.C.R: .Valve ~. mte _/ 2. -- Inspector 147. ' _ ............ ' .._ Operator_ ~X~'4 a Representative J~-J*zY '~~~ ~tion: Sec ]~ T/~t. JR.~o~ M ¢,Pi /]~?~Casin9 Set 0~/~ , ~illinq ~n~a~or 3~0~ --Ri~__~ Z~ -Repre~ntative- S~O ~e~a0~ ~mtion, ~nera] o ~< Well Sign ~J~ du/~e~'T J ~11 O~arge ~es~re ...... ~oo psig ceneral Hollering ali' ~essure After Closure.../_~ psig Pese~e pit ~< i ~p incr. clos. pres. 200 psig / rain 6 Z sec. ~9 ~ ~11 Chaz~e ~essure At~in~ ~_mn~ & sec. R~te_~ .... Blinds m~itdl_.gOVer Test ~es~e Kelly ~d Flor Safe%, Valves - 0 K ~00 o ~per Kelly ~ O~.Test Pressure ~% __ ~ ~o o ~er Kelly ~O/~Test ~es~e _.'~/~-' __ oI<~ o~¢-~ I~ide ~P~ ~ P~; Test ~es~reS~r;~9 ~ x ~ ~ ~ o Choke b~nifold_ Test ~essure O ~ ~ ~'~.~ ~. Valx~s_ Oh rr'~:~-~ -~ No. flanges ~6 ~'"':> ~" t~,draui~lly operat~ choke l-~ Test Re,lis, Fail~es RePair or Replac~ent of fail~ ~uipmnt to ~ ~de wi~in. 3 ~ys and I~~or/C~sion office notifi~. ' Kill Lih'e Valves Check Valve ' ~ . Distribution orig. - BO&CCC cc - Ope r~tor - Supervisor CC 2 ~ove~ber 24, 1982 ~r. ~ark A. Area Drilltn~ Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska-995!0 Prudhoe Bay Unit DS 12-10 ARCO Alaska, !nc. Pem~it No. 82-198 Sur. Loc. §72'FSL, 930'FEL, See. 18, 710}5, R15E, ~..-~. Btmhole Loc. 167'FSL, I§2'FB~, Soc. 7, T10N, R15E, ~.~. Dear }~r. Encto~ed is ti~e approved application for permit to drill the above referenced well. If coring i~ conducted, a one cubic inch chip frmn each foot of recovered core is required. Samples of ~,-ell cuttings and a r:~ad log are not required. A continuous directional survey ia required a~ per 20 AAC gS.050(b)(5). If available, a tape containing the digitized log infomation shall be submitted on all logs for copying except experimental log~, velocity surveys and dlpmeter ~urveya. ~-~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadrmous fish. C~erations in the~e areas are subject to AS 16.~5.870 and the re~lations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to conm~encing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article ? and the regulations promulgated thereunder (Title I8, Alaska Administrative Code, Chapter 70) and by the Federal ~ater Pollution Control Act, as amehded. Prior to co~mncing operations you may be contacted by a representative of the Department of Envtrop~ental Conse.'~vation. To aid us in scheduling field ~ork, please notify this office 24 hours prior to con~3encing installation of the blowout Mr. Mark A. Major Prudhoe Bay Unit DS 12-!9 -2- November 24, 1982 prevention equip~ent so that a representative of the Con~nission may be present to witness testing of the equipment before the surface 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 witness testing before drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Chai ~mn of Alaska Oil and Gas Conse~ation ~ission Eric I o sure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w]o encl. CVC= be ARCO Alaska, Inc. ~'. Post Office B~.._ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 November 19, 1982 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 12-19, Permit to Drill Dear Mr. Chatterton: Enclosed is our application for Permit to Drill DS 12-19 and the required $100 filing fee. Attachments to the application include a plat detailing the section and plan views of the proposed wellbore; a proximity plat showing the subject wellbore's position to the nearest well drilled; a discussion of nearby wellbores; a sketch and description of the BOP equipment; and a sketch and description of the surface hole diverter system. Since we estimate spudding this well November 29, 1982, your prompt approval will be appreciated. Sincerely, Mo A. Major Area Drilling Engineer MAM/JG:sm Enclosures GRU2/L43 RECEIVED NOV 2 2 1982 Alaska 0[t & Bas Cons. Commissio~ Anchorage ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO~,,,vllSSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work. DRILL J~( REDRILL [] DEEPEN [] lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE [~X MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 572' FSL & 930' FEL, Sec, 18, T10N, R15E, UN At top of proposed producing interval 195' FNL & 401' FWL, Sec. 18, T10N, R15E, UN At total depth 107' FSL & 152' FWL, Sec. 7, T10N, R15E, UN 9. Unit or lease name Prudhoe Bay Unit 10. Well number DS 12-19 11. Field and pool Prudhoe Bay Field Prudhoe Bay 0il Pool 5. Elevation in feet (indicate KB, DF etc,) 6. Lease designation and serial no. RKB 77', PAD 41' ADL 28330 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line Deadhorse 0 miles 195 feet 17. Number of acres in lease feet 2512 20. Anticipated pressures MAXIMUM HOLE ANGLE 47.5° (see 20 AAC 25.035 (c) (2) 16. Proposed depth (MD & TVD) 11850'MD, 9203'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT2450 feet. 21 15. Distance to nearest drilling or completed 12-12 well (~ 4511 ' HD = 175 feet I18. Approximate spud date I 11/29/82 3508 psig@.____ Surface 4125 psig@ 92f)_~ ft. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE I 8-1/2" i Hole Casing Weight b0" 20" 91.5# ~!7-1/2" 13-3/8" 72# 2-1/4" 9-5/8" 47# 7" 29# CASING AND LINER Grade Coupling Length H-40 Welded L-80 Butt I L-80 Butt I 11076 ' I iL-80 IButt J 1041' 22. Describe proposed program: SETTING DEPTH MD TOP TVD 80' 36' I 36' I 2364' 36' 36' 33' ~ 33' 10809' 18501' I MD BOTTOM TVD 116'11 116' 2400' I 2400' 11109' I 8703' I 11850' !9203' I QUANTITY OF CEMENT (include stage data) 2000 # Poleset 2300sx Fondu + 400 sx PFC 500sx Class G 1st Stage 300 sx PFC 2nd Stage 400sx Class G ARCO Alaska, Inc., proposes to directionally drill this well to 11850' MD (9203' TVD) to produce the Sadlerochit zone. Logs will be run across selected intervals. A 13-5/8" 5000 psi RSRRA BOP stack will be installed and tested. The annular preventer will be tested to 3000 psi and rams tested to 5000 psi. The BOP equipment will be pressure tested each week and operationally tested each trip. A string of 5-1/2", 17# L-80 tubing and packer will be run. Provisions for subsurface safety equipment will be run. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. The packer will be set above the Sadlerochit. A Sundry Notice will be submitted when the well is to be perforated. A surface diverter will be installed and operationally tested prior to spud and at least daily thereafter. RECEIVED See attached proximity analysis. ng is true and correct to the best of my knowledge 23. I hereby certify that the fore~ I~l~JV 2 The space below for Commission use Samples required []YES ~ZCN O Permit number Y/~ ~ Form 10-401 GRU2/PD28 CONDITIONS OF APPROVAL Mud log required [-]YES ~NO Approval date D~?ectional Survey required ] APl number YES []NO 50- O'L ~' - "~ 0 ~7© SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE by order of the Commission Nov_~n_her _9,4, 1982 Submit in triplicate DS 12-19 PROXIMITY ANALYSIS The only well within 200' of DS 12-19 (as planned), in the directional portion, is DS 12-12. The minimum distance is 175' at 4279' TVD (4511' MD) on DS 12-19. At this point, Well #19 is past Well #12 (see diagram). In reality, Well #19 will be led to the left of what is proposed. This will increase the distance between the wells, since Well #12 is further below Well #19 the more Well #19 is led to the left. The Teleco drill collar will be used throughout this interval and frequent surveys will be taken. JG'sm 11/19/82 GRU2/AWP3 ECEIVED NOV 2 2 1.982 Alaska Oil & Gas Cons. CmnmJssion Anchorage ! : - i j f t 526-- 5249 i 2900? ......... 2800-_L~ __. 27.00 . 26.00[. 500 24C , ',. ~ . ,, ,-,.~ [ , ~ ,| ,.,-: , ........... ~ :-4::: ~ ........ ;_-~_~:.~..--[~:.~-~ .... ~ ....... ~ ...... t. ~---:-~ ~... ~ .... ~ ...... : f. ! . : I 8894-:--' I :--l---e''~-L--- ' -7044 .... ._ -690c- _ _ . L~ ! . ~ 2o0, ......... ~ z_..?? ........ ~ 'PRUDHOE'BAY~"-NORTHjSLOPE ALASKA" I .... [-.~_~. ANNULAR PREVENTER BLIND RAMS PIPE RAMS DRILLING SPOOL PIPE RAMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test 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 simultane- ously and record the time and pressure remaining -after all units are closed with charging pump off. 4. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. .. 13-5/8" BOP Stack Test 1. Fill BOP stack and manifold with a non-freezing liquid° 2. Check that all hold down screws are fully retracted. Mark running joint with predeter- mined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close annular preventer and chokes and bypass valves on manifold. 4. In each of the following tests, first hold a, 250 psi low pressure test for a minimum of 3~ minutes, then test at the high pressure. 5. Increase presure to 3000 psi and hold for a minimum of 3 minutes. Bleed pressure to zero. 6. Open annular preventer and close top set of pipe rams. Increase pressure to 5000 psi and hold for at least 3 minutes. Bleed pres- sure to zero. 7. Close valves directly upstream of chokes and open chokes. Increase pressure to 5000 psi & hold for at least 3 minutes. Bleed pressure to zero. 8. Open top set of pipe rams then close bottom set of pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams and hold for at least 3 minutes. 9. Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure downstream. 10. Bleed pressure to zero. Open bottom set of pipe rams. 11. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for at least 3 minutes. 12. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full of non-freezing liquid and all valves are set in drilling position. 13. Test standpipe valves to 5000 psi. 14. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 15. Check operation of Degasser. 16. Record test information on blowout preventer test form. Sign and send to Drilling Super- visor. 17. Perform complete BOPE test once a week and functionally operate BOPE daily. Rev. 5/13/81 WELL SURFACE HOLE D TVERTER ARCO ALASKA RESERVE PIT AREA NOTE' IO" HYDo OPR. BALL VALVE V~LL BORE (SEE DETAIL) IO'° HYD. (]PR. BALL VALVE ALL 90' TURNS ARE "TEE" CUSHION I I SYSTEM SCHEMATIC INC'. FLOWL INE DR ILL ING R I SER , F L 20" 2000 PSI WP ANNULAR PREVENTOR 'Valves on diverter ~ lines open automati- cally when the annular preventer is closed. 20" CONDUCTOR PIPE "DETAIL" 2026010203 ARCO Alaska, Inc. Post Office [:~,-~"-~-.~60 Anchorage, ~. .(a 99510 Telephone 907 277 5637 December 2, 1982 Mrs. Elaine Johnson State of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - Drill Site 12, Wells 15-19 Dear Elaine- Enclosed is an as-built location plat for the subject wells. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG: sm EnClosure - GRU2/L52 &laska Oil & Gas Cons. 'qnchorage c°mmlssio~ ARCO Alaska, Inc. is a subsidiary of AllanticRichfieldCompany ~10 '1' Io,N_~ VIClNI'I"Y MAP ~',C,a I e, ~ I'" 4000~ ! i · I HEREBY CERTIFY THAT I AM ' P~OPE~LY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF A~~ AND THAT THI~ P~T RE~ESENTS AN AS-BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER D~AILS ARE CORRECT, AS OF: 12/15 12/16 17. ZO- 12/17 12/18 12/19 Y= 5,930,400.95 X= 696,720.53 LAT= 70'12' 50.660" ~ 148' 24' 47.771" NW O0R _C~J3AR BOX ~KV = 41.6' Y= 5,930,520.80 X= 696,708.71 LAT= 70'12' 51. 842" IDN(~ 148'24' 48. 024" NW COR C][I2AR BOX FiIKV = 41.9' Y= 5,930,639.98 X= 696,696.63 LAT= 70'12' 53.017" ~ 148'24' 48. 284" NW CDR ~AR BOX ELEV -- 42.0' Y= 5,930,759.49 X= 696,684.7 8 IAT= 70'12' 54. 195" LON~ 148'24' 48. 538" h]2 COK C~I'.TAR BOX ELEV = 41.7' Y= 5,930,879.28 X= 696,672.84 DEC 0 6, ~-'.0~lg LA2~- 70'12' 55.376" .... , LONG= 148'24' 48. 794" CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. l¥- f ,~ ITEM (1) Fee (2) Loc APPROVE DATE ""~&x.._.-. /.,..'u~.,...~'~..~ thru 8') 3. Is well located proper distance from property line ...... 4. Is well located proper distance from other wells ........ 5. Is sufficient undedicated acreage 'available in this pool 6. Is well to be deviated and is well bore plat included .... 7. Is operator the only affected party .... ; ................ 8. Can permit be approved before ten-day wait .............. (3) Admin ~-,/ ..... //,, '2,'~,-~"'~, 9. (9" thru 11) 10. 11. (4) Casg ~.~,~, //-O~-g~-. (12 thru 20) (21 thru 24) 12. 13, 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. (6) Add: ~.~.~/ M-~P-~- Does operator have a bond in force.. oo .................. .... Is a conservation order needed .... ''.''.'''''''''''''''''' '''.'''' Is administrative approval needed .................................. YES NO 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 and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a 'diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~-OOo psig .. ~, Does the choke manifold comply w/AP1 RP-53 (Feb.78) .................. Additional requirements ............................................. REMARKS Additional Remarks: ~>~ Geology: ' Engineering WVAz~ JKT ~ RAD rev: 08/19/82 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. 2/29 IN(;'.: !.5 i':~ ~ t,.: 1 0 ECT; 1. ~ '17 A "I: A L TRY: ;) ,, 12-19 0 9 0 ,.) 0 0 0 0 0 0 [) 0 0 t)0 000 0 0 0 CATE 0 0 0 O0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 () 000 SIZE O26 008 0!2 0O4 0O4 0O2 O12 0 t) 6 006 CODE 065 Ob5 065 Ob5 065 065 065 065 ('65 SERVICE SERVICE t,~IT API ~PI API AP'I PlbE ,SIZE FROCE;,S5 8..~IPbE REP~ ["-:PT 11.292.50[Iu i',;PD l .l.O. 1562 ~',/R n, T 1,7695 Ri'~RA 1.8916 Ct,, I., 1939,00t)0 FCNI~ 1025,0(,)00 (.;r~ 132.3750 2%,34,1a 45 ;~. 25 00 243, ' 2F;q, 0000 57, .. 2,t2 179, 750 21, t,.. 5 7,9102 165,0 t') o 0 195 . 0000 1 '19,375 1 ~ 2. b 000 46,7285 214. ~ 250 q7.4121 21 ~, OUO 0 19~, 25O0 47.9 492 ~67. B750 46.6 'l 9 7 153.7500 4 i , 2109 244. 6250 7 8418 279.0 o O i) ]5,791r) 2.7 9 3 0 49'0313 3,7207 4 1 · 1562 4 ,, 5469 4 ~. 4375 4. 0664 117,3!,25 ~. 5781 4. ()'23 ~ 102.0625 4.3:750 134,.b250 4:. 3945 66,6250 3,966a 8 ], 6 25 v 4.0039 9~.8750 4,08~9 94.1 ~50 4,031 ] 65.4375 3.96~9 52.2~13 ] , 6641 56,3~3q 3.4765 58.6250 50.3438 'j.3~52 59.9()6~ 2.9023 3,9375 3. 5,41:41. 4:, 0703 5,1.836 4,2305 4,8320 .~. 4141 3.7109 3.9277 4, 4:,2734 4.6016 3o~750 3,4121 3,5547 3.7637 ,'P O10.HO1 ~/[!:RIFIC~,'C].C;,",~' LISTIkCG PAG5 5 7 !v IL, 674.5 tt u 0 F C K~ F'. P T q 2 () (). O O 00 u F' l.i I : N L 789. C, l,) 00 F C N L .1 n i, 793.50 u u F C., ~',: [, ,7. N L ~.,.'. 33 . 00 Il 0 ~ (. b I !: P'I; 890 O, 000 () N P.H 1 ".%' L 93 ~. 500 t') w C, N L, g 700. OOUU NPH'[ ,7 A} L 792.000 () F C', i'~ I',., ;~'PT' 8300.U000 ~ P '"' !,~ !_, ~ 5 '1.00 t.) O F C .t',, 1 1142,, OOUO FCn:T~ E P T 79 (.) 0.00 (.) ~..) ~'~ P H 1 C f,d I_, .942.0 () U 0 t5 C I,, 922. OOC, 0 Fcr~L C :,r L ? ~ 7, i,~ ~'." U '9 f-' C i,,: i._, 4 H. 7793 I 71 , ,~, t'), :337 9 1. 7 2.5()00 41 216 ~ ~ 250 43 , .......... 233,375 ~ 39. ,,~ .484 204. ~ 500 253. 36. u84.0 236. ~>250 55. ~688 171. ~751~ 1~9.2500 52.7 l~ 32 5'~.1~5~ 205.8750 45,6543 208.7 5(')0 176.25U0 4:0. 234~+ 176,(~250 38.72O7 273.50U0 35.351~ ,12.9t99 254.~750 36. ("':; R NRAT NRAT G R D,'. R A T' G~ N R A '] (; R G R t,, ~'~ A'r GP ,,,NAT ~,. P A T 4,. 07~:~ 1, 54. o625 3.9434 3, !!75fl 5 5.968 7 3,7 7 3 q ~,3,343a 3,5762 5 6,8 4 37 3,3~03 ,<~ 9,3750 3,3 ~ 09 61,08oo 4.44~3 58.4 6 8 ~ 4,14 4 5 70,62b0 4,2969 51.3125 4 3 I.. ~"* 3 9U82 ~,2227 5~,7500 3,6094 56.6563 3,5273 33.0u09 3.3,~38 30.32at 3.757~? 2~.7500 3,3~48 37,~7~ q. 9062 3,9082 3. 640b 3.3984 4.0781 3.6875 3.531,3 4,7266 4.50 5,0000 3,~457 ~,0742 4.5469 ~,4531 4,1719 3.9316 3.6230 ,:? P T 7 5 0 0 7 N L ~ 9 9 F, P T 7300 "N L 749 F, PT 70 0 0 ~ N [,,, 919 ~900.0000 ~ N L 94 b E P T ~ 700 [~ h L 835 E P T 66 i) 0 ~NB 979,5000 g P T 65 () 0 6400 780 ~: P T 6300 CNI., CNL CNL 7~5,0000 C ~ L 71 ~ 4. :2...3 ~,: 2 ~ 2~9,5(,(,[1 GR 4:3 94.53 229,0000 G ,,, r. ql 245,3750 (.; 52, {~ ~'~ 55 ~v. p A T 14 6 · 6250 (:; 2 79. 5 O 0 ~4.t~289 229,~750 38,~160 NR:AT 261. [) 00 31,8359 282 · OOOO 27,581., NRa a'[. 8945 a RA[I' 26!.0000 GR 41 , 3086 NRAT 211.7500 33,496! 22'~, 6250 GR 22~, t) OO() G 5 ~. t:, q 14 I', ~ A T 163.8750 53. '7598 lu ~ A T i 50. 2500 t>l .~52 ,'RAT 149. b259 59,8633 1!6,6750 GR 3.72~';5 6~.~.. 6250 4: , 81.25 .093 3,55O8 38,81:25 3,644. 5 4.293 o 43,4688 3,3750 1.9.2187 3,8516 25. 984.4 3,5371 32,~[25 3,1484 23,6406 33.8125 3,7012 20~468a 3,b699 43.3438 3.2,402 28,2187 3. 7246 29. 3906 4.~11 49,468~ 49,8750 4,7969 42,8937 42.343~¢ 2,9277 4.6992 3,9277 5,1055 3,4707 4,0000 3.4375 3,3535 3,5703 ].7520 3,8457 3,425S q,2~09 4,0977 ~,7773 ~.i094 ~ol4Ub (P T 5.' ~ 00. _'. N !i, 647, ~':'P q' ,5 7 0 0.0 0 0 0 ,~, P r 5500, ( '.~N 1, 872. :NI, ~49,000u FCN[, ~: P T 510 U. 00 L=pT 50U(),(1000 i4PH 1 !',PT 4900.000 U UPhI U N l, 835, (; 000 F C t<. L E g T 4700.00 (.) 0 '~ P b '[ (~ tq I, 803. (} 000 H' C N i,., EF'r 450U.~)000 C ~ L ~ ~ ~. 5 0 <.) 0 F C k !.,, FPT 4 300 CN[l 7~.0000 FCNL E'PT 4 1 O0. O0 149. 375O ~9. g535 1. 32. '150 43, U 52 21 3. 47,6 51. 186,7500 57, l 8 7,1250 44,7266 1. 67.6 ~1. ,2~95 1 ~)7,0 (') 00 55,b~41 li~5.6250 222. J 25o 4~1,287 2(~b, t25f: 205,12s~ 52.7~32 170. S '750 39.0625 153. I 250 4.025O 29'2969 36, () 93'8 4,6914 51.. 87 b 0 3,7 9 ~ 9 32 , 4C) 63 4,7109 45,093g 4,Ol17 40.5938 4.2227 22,~563 7 500 4. 3,85 74 27.8125 q.. 21.43 39,593H 4,4570 40.9375 3.7188 39.343H 3,~320 3~.3125 3.7t)1~ 40.0625 4,296c~ 4,01~5 31.4531 3.54~9 ,4.32b: 1 b,O89B 5.1211 4.0'142 5. 375O g, 4,5430 ~, 4258 4.3633 4.3008 5. 0000 ~, 5430 3.6133 -~.2451 4.3281 4.6641 4. 597 7 4.2i~7 7 (). 5 5 t> h ! 37, fl 7 50 ~ !')., ", 1, 13 ~ .5 0 0 0 ~ ~' .,, 61....~ 62 4. ~ . b '170 139 ' 625 0 b 3,7,109 1 ".~ 9,1 '250 1n4.31.25 St ,9043 17q.. 25()o '138. 61.4'746 13 ~.~, 5 ()0 0 17b , 3750 41,6504 192.1 6 'l. 3 340 lO4,7500 67.627 ~g. 6 (;. 9375 122, '1500 62. 1094 t 5~. d 7 St) ~2. 597 l ~72. 750o r:,~ R A (., p,, R A '[ GR N R A T GR (; 'R b~ R A T NRA'Z' b; R A T GR ,i',l R A T (;; R G R NRAT GR k: t~ A T r,~ R A q: N~AT ~'.~ ~ A T 5 . 2734 4,2305 33.9062 43.6 2:5 o 4,. 082u 51.6250 4,3477 26 · 9 f,~ 44 44,0313 4.25OO 5.05,17 ag,125n 4,7734 35.7tB~ 3.9141 34.4o63 3.6875 17,8i25 5,093~3 2~.7813 40.9375 4.74t, 1 25,4375 41,5313 4,63~ 5.2695 19. 4. '15 O 0 5,570 ..1t 4.B71.1 ~.1367 4. 250O 4.6211 5.8320 /4.2969 5. 0000 4,621.1 4,0 0 0 0 t,. 1641 6,39a4 5.'7'148 4.55,47 5.5703 6,3320 PAGE 9 LIS TAPE VP OIO,HO1 V.~:NIF.I, CATIO~'~ I.!IS'.['INC PAGEi !. ERV!CM NAME' :$ERV1C ATE :82/1 APE NAME : ONTINOATION REV IOI.)S T A P ~..', * INFORMATION RECORDS NE~ N : AT N : PR OWN: 10 ECT: 1~, OU~: NO TAT: AL, TRY: U, ********* L, ANTIC RICHFIELD COMPANY 000 O0() 026 065 I[,,LSI'P~i; 12-19 000 000 01,6 065 [J[)H(')E BAY 000 000 012 065 E 000 000 004 005 N 000 000 004 065 000 ()00 002 OhS RTH 5!.,OPE OUO 000 012 065 ASKA 000 O00 OOo 005 S,A, 000 000 006 0&5 S ** ********************************************************************** )8 t~tt, I.H.~..,N AT .ACC ~ 662(. 3 ITRIX SAN[)$TOf~EI ************************************************************************************** SP~,~,RICAI, bY b[)CU~ED LOG (DI~) LOG (Ct~,) ~E~ SERVICE SERVICE UNIT API AP1 AP.! API rl[~7 $IZ, E PROCESS 8AMPbE REPR 'ID [)RDER , !.,f')G TYP~'.i Cb.~8S ~OD r~O, I, ETVEL COD~: EPT F'~r 0 0 0 0 0 4 0 I ~8 F b U D l L 0 ~ ~i b~ 7 0 0 0 0 4 0 1 68 bM D'[L DH~I~ 7 0 0 0 0 4 ._ 0 1 68 U D [') ! L 0 H ~ ~ 7 1 2 4 6 0 0 4 0 ! 6 8 !P OIO.H01 VSRI~'ICA 1101~!' LISTING PAG~j 4 4 0 4 0 ti 0 4 0 4 0 4 0 4 0 4 0 4 0 4, 0 4 O 4 0 4 0 68 1 68 1 68 1 68: DATA EPT P PHI CNL EPT P .PHI CNL NRA EPT PHI CNL NRA EPT P CN L NRA 11 960 5000 0 ~93 -999 . O0 -999 2500 -999,2500 900 , -66,0625 27 , 4902 434,00 00 2.3320 1.1~00,0000 65,00O0 2b.3672 1463,0000 2,339~ 11~00.0000 1.7,6875 24.5117 1442.0000 2,4316 EPT 11600.0000 P -19,0938 PHI 24.0723 CNL 1603.0000 ~a 2,2090 .[.,;PT pCN L NRA 11500,0000 -72,3750 28,2715 1339.0(100 2,53'11, 1!400,0000 S V [, U GR [> R H (] CALl S F" [... (.I GR CALI SFI, U GR D R H 0 CALl S [~' Il tt CAI.,1 SFL, U GR C~LI G~ D R t-i 0 CAt,, I $ F [., U 10 -999 '999 :3 ~219 063 500 2500 3a()9 ,~406 C'O 7 B 2422 2.550H 21,5156 0.0195 8,3906 10,9062 3~,2~13 · .0747 8,5547 26.9219 71 4375 0:0181 .8,4844 41,093~ 25,8437 0,0093 8,4688 48,8437 I [,, M DT I. I.., DT I L Iv~ DT GR I L M GR I DT F .H U P~ DT GR 3,1504 IbD 90,~750 GR -999 ' ~500 NCNL -999 '2500 NR.AT 2.31.()5 IbD 2 637 28,0000 NRAT 1.g395 ILD 91,7500 GR 2,2461 NCNL 22.3438 NRAT 8.9141 lbo 92,7500 GR 2.3984 NCNL 40,1875 NRAT 20,3435 82,0000 GR 2,2734. NCNb 39,5000 NRAT 26.0000 94.0000 GR 2.2852 NCNL 25.0781 NRAT 31,9687 IL, D 28,4063 -999.2500 -9'99,2500 2,1,641, 25,6406 3346,0000 2.550B 1,8809 21,5156 3424.000O 2.4883 9,7656 30,2813 350~.0000 2,3809 34,9375 71,4375 3544.0000 2,3438 56,46~8 25,8437 339~,0000 2.623O 68,1875 'P OI()oNOI VE~IF1C. ATII.!t',~ LIiS'Ii'ING PllGE. 5 ~ 6 6 T 2 .1.5 2 D 0 ,, 0 17 O ~H[)b 8,4844 (,;R 1,, 1. 25 i~ I [., 3750 DT O.O' 1.81. 9 ' 1 2 5 0 000,0()00 iI.,~.~ 54,6:875 bT 999,2500 -99:9,2500 GR 88, i. 875 GR 2.31.84' NCNt., 29,4531 hi:RAT 51. ti 1. 25 ILD 67,0000 GR 2,5 9 96 ~si C bt 86,4375 .~RAT '" ( 00 ,, 0 z 3 00 I [, D 63,5938 GR -999,2.500 NCNi., '999,2500 NRAT 26,1.562 385~,U000 ,2676 8"1,0000 85,3750 4032.Ci000 1,6904 :13,6563 75,6250 3150,0()00 2,343~ 6.8984 54,~875 999,25()0 2999,2500 FILL, TRAILER ~;RV ICE N A. IqE ~TF: : %XI~UP; l,}~':NqT~ : 1024 [IoE TYPE EXT' FILE NAME TAPE 3'RAILE;R ** ~:RV:I. CE ~AME :SER'V1C ~7'E 182112/2! G 1 h : 6620 ~PE N ~i~E; : EXT TAPE N~': : 9a~ENTS :LI'BPARY