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Home My WebLink About196-098MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC A-16A PRUDHOE BAY UNIT A-16A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 A-16A 50-029-20521-01-00 196-098-0 W SPT 8694 1960980 2174 1228 1228 1228 1228 232 224 225 229 4YRTST P Guy Cook 6/6/2023 Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT A-16A Inspection Date: Tubing OA Packer Depth 264 2432 2382 2368IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230605111830 BBL Pumped:4.6 BBL Returned:4.5 Wednesday, July 26, 2023 Page 1 of 1            MEMORANDUM State of Alaska Depth Alaska Oil and Gas Conservation Commission To: Jim Regg q Z�t 710r,6 DATE:. Wednesday, lune 12, 2019 1 / P.I. Supervisor SUBJECT: Mechanical Integrity Tests 423 BP EXPLORATION (ALASKA) INC. 424 A -16A FROM: Matt Herrera PRUDHOE BAY UNIT A- 16A Petroleum Inspector 18 zoo Src: Inspector _ z47o-- Reviewed 6 1 - BBL Returned: —B--y�: –1 P.I. Supre NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A -16A API Well Number 50-029-20521-01-00 Inspector Name: Matt Herrera Insp Num: mitMFH190606124607 Permit Number: 196-098-0 Inspection Date: 6/6/2019 Rel Insp Num: Wednesday, June 12, 2019 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A 16A ype Inj 8694 - 423 423 424 PTD f 1960980 Test SPI Test psi TypeP AnB� 8694 lTubi 18 zoo z478 - _ z47o-- BBL Pumped _ 6 1 - BBL Returned: 5.6 OA 269 - 260 268 272 Interval - 4YRTST P/F �— P ✓ i __-_— --__ --- — — Notes: 1A Pressure tested to 2500 PSI per Operator Wednesday, June 12, 2019 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg �s' r I DATE:Tuesday,June 23,2015 P.I.Supervisor ley l (9l 23`17 SUBJECT: Mechanical Integrity Tests ((( BP EXPLORATION(ALASKA)INC • A-16A FROM: Lou Grimaldi PRUDHOE BAY UNIT A-16A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT A-16A API Well Number 50-029-20521-01-00 Inspector Name: Lou Grimaldi Permit Number: 196-098-0 Inspection Date: 6/20/2015 Insp Num: mitLGl50620170758 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I A-16A ' Type Inj W"TVD 8613 ' Tubing 480 - 480 481 483 PTD 1960980 • Type Test SPT Test psi 2153 - IA 828 2502 2484 2479 • Interval 4YRTST P/F P J OA 327 . 331 343 ' 350 • Notes: 3.6 bbl's diesel pumped,5.5 bbl's returned.Good solid test.All required paperwork supplied prior to test. - ,M4c 4w¢tiS' 1) T O r—f,S(A..-e S (AEA SCANNED JUL 1 3 2015 Tuesday,June 23,2015 Page 1 of 1 ‘P r- 0 1"-- ,..) (.1 4 Plgrgt, C30 k r — ..) —,----- :5 ..2. II -2_ ...i.... t...)'... i ..- cs_J. 4 .., ;.•, 0 .7-- I-- 0 0 2 g 4i w cc ... m CD 14 1 7 I ,.. 1 . .. „ .. .. .. . TREE'= 6"X 7"CAN FLS WELLHEAD 13-5/8"5M MC£VOY SA NOTES.FCLS READINGS AVERAGE 125 ppm ACTUATOR= BAKER C A 6A WHEN ON Mi.WELL REQUIRES A SSSV WHEN ON OKB ELEV_ 80' ML WELL ANGLE>70°@ 10523'.PRE-SDTRK BF.ELEV= 52.4$' WELLBORE 8110W 9 5/8"WINDOW NOT SHOWN ON KOP= 3400' DIAGRAM. Max Angle= 91'@ 11994' Datum MD= 10435' 2099' — 4-1/2'FES X NP,ID=3,813' Datum TVD= 8800'SS — 2700' —FTC] [13-318"CSG,72#,L-80,ID=12.347" l--{ 2700' Minimum ID = 3.725" 10227' "WARNING" RADIO TRANSMTTERINWEATFER MONTTORIJG SHACK MUST BE TURNED OFF BEFORE 4-112" HES XN NIPPLE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGId. CONTACT PAD OPERATOR 19-5/8"X 7"BKR ZXP PKR W/TIEBACK SLV H 8410' I333 p� 9-5/8"X 7"BKR HMC LNR HANGER H 8424' Qu) 9-5/&"SEC 11ON IVLLOIJT VVNNDOW 8580' TO 8630' PERFORATION SUMMARY REF LOG: TCP PERF 10172' —14-1/2"FES X NP,ID=3.813" ANGLE AT TOP PERF: 89"©10940' 10183' Hr X 4-1/2"BAKER S-3 PIR,D=3.875" Note:Refer to Production D6 for historical perf data SIZE SPF WTT3�/AL Opn/Sqz SNOT SQZ 10206' —J4 112'HES X NP,D=3.813" 2-7/8" 4 10940- 11040 0 04/09/97 10227' --I4-1/2"HES XN NP, ID=3.725" 2-7/8" 4 11350- 11410 0 04/09/97 2-7/8" 4 11460- 11500 0 04/09/97 10237' —7"X 4-1/2"BKR ZXP PKR W/ T tHACK,O=3.89" 2-7I8" 4 11800-11860 0 04/09/97 10239' --j4-1/2"WLEG,ID=4.00" 77/8" 4 12180- 12220 0 04/09/97 !i0••. 'Ave �� 10244' —{ELMD TT LOGGED 12-17-97 2-7/8' 4 12240- 12290 0 04/09/97 41.1••. 3-3/8" 4 12730-12868 C 08/04/96 i10P�091�10ddi•�'�. I 12630' —4.1/2"AVA DWP BP 0412/97 •H1HIHIH HI. I�� e••=0740:0 •••11•••••••111.1••••••••1••••••••• 411•111.1441.1.11♦ 11111.1.1.11.1❖'.•••1.1••1.1•1+ 9-5/8"CSG,47#,L-80,ID=8.681" — 10503' 14.".V.V.�•�•1•�•�1�•51�1.11: 4-1/2"TBG, 126#,L-80,BTC-MOD,0.0152 bpf,ID=3.958" H 10238' I 7"LNR,29# L-80,BTC-M,0.0371 bpf,ID=6.182" H 10410' L_PBTD J- 12934' J -- 4-1/2"LNR, 12.6#L-80,.0152 bpf, D=3.958' —f 13020" DATE REV BY — COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/16/81 ORIGINAL COMPLETION 09/22/14 DU/JMD TREE C/0(09/06/14) WELL: A-16A 08/05/96 SRB SIDETRACK COMPLETION PERMIT ND: 1960980 06/19/01 CWKAK CORRECTIONS API No: 50-029-20521-01 07/24/03 JW/KAK PERF DEPTH CORRECTION SEC 35,711N,R13E,3016'ENE&1014'FEL 02/14/11 MB/JVD ADDED SSSV SAYEIY NOTE 01/17/12 TMWJMD ADDED I-QS SAFETY NOTE BP Exploration(Alaska) RGLAGIV , STATE OF ALASKA NOV 2 1 201 ? - ' A KA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well1 Plug Perforations U Perforate U OtherU BrightWater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program p Operat. Shutdown❑ Stimulate - Other Re -enter Sus ❑ Suspended Wel P 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ 196 -098 -0 3. Address: P.O. Box 196612 StratigraphiC Service 0 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20521 -01 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0047472 PBU A -16A 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: Total Depth measured 13020 feet Plugs measured 12630 feet true vertical 9115.47 feet Junk measured None feet Effective Depth measured 12630 feet Packer measured See Attachment feet true vertical 9033.3 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 110 20" 94# H-40 • 28 - 138 28 - 138 1530 520 Surface 2673 13 -3/8" 72# L -80 28 - 2701 28 - 2700.88 4930 2670 Intermediate None None None None None None Production 8603 9 -5/8" 47# L -80 28 - 8631 28 - 7401.45 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10940 - 11040 feet 11350 - 11410 feet 11460 - 11500 feet 11800 11860 feet 12180 - 12220 feet 12240 - 12290 feet 12730 - 12868 feet True Vertical depth 8960.93 - 8962.87 feet 8973.3 - 8976.81 feet 8979.92 - 8982.51 feet 9002.91 - 9004.75 feet 9007.83 - 9011.21 feet 9012.97 - 9017.1 feet 9036.36 - 9056.37 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 25 - 10239 25 - 8739.74 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): 10940'- 11040', 11350'- 11410', 11460'- 11500', 11800'- 11860', 12180'- 12220', 12240 - 12290' $CANNED FEB 2 2013. Treatment descriptions including volumes used and final pressure: 2172 Gallons EC9260A Surfactant, 10001 Gallons EC9378A Polymer, 787 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 3964 0 652 Subsequent to operation: 0 0 4312 0 712 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 U Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ID GINJ ❑ SUSP ❑ SPLUG❑ 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 Garry Catron Email Garry BP.Com Printed Name Garry Catron Title PDC PE Signature .9 ( Phone 564 -4424 Date 11/20/2012 Hp' io : ! 1,.oi 20 iris 7C (1•1 .17--. Form 10-404 Revised 10/2012 � 2��e� ( [ 2. Submit Original Only • ! Packers and SSV's Attachment ADL0047472 SW Name Type MD TVD Depscription A -16A PACKER 8410 7166.59 7" Baker ZXP Packer A -16A PACKER 10183 8613.84 4 -1/2" Baker S -3 Perm Packer A -16A PACKER 10237 8657.04 4 -1/2" Baker ZXP Packer Casing / Tubing Attachment ADL0047472 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110 20" 94# H-40 28 - 138 28 - 138 1530 520 LINER 2000 7" 29# L -80 8410 - 10410 7247.73 - 8859.35 8160 7020 LINER 2783 4 -1/2" 12.6# L -80 10237 - 13020 8738.18 - 9115.47 8430 7500 PRODUCTION 8603 9 -5/8" 47# L -80 28 - 8631 28 - 7401.45 6870 4760 SURFACE 2673 13 -3/8" 72# L -80 28 - 2701 28 - 2700.88 4930 2670 TUBING 10214 4 -1/2" 12.6# L -80 25 - 10239 25 - 8739.74 8430 7500 III . • • • Daily Report of Well Operations ADL0047472 T /I /O = 700/40/220 Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 214 gal. EC9360A (Surfactant) Average of 26.75 gph for 8 hrs. Pumped a total of 214 gal. since start of project. Pumped 1054 gal. EC9398A ( Polymer) Average of 131.75 gph for 8 hrs. Pumped a total of 1054 gal. since start of project 10/25/2012 ** *Continued on WSR 10/26/2012*** T /I /O = 774/40/220 ** *Continued WSR from 10 -25- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 728 gal. EC9360A (Surfactant) Average of 30.33 gph for 24 hrs. Pumped a total of 942 gal. since start of project. Pumped 3175 gal. EC9378A ( Polymer) Average of 132.29 gph for 24 hrs. Pumped a total of 4229 gal. since start of project 10/26/2012 ** *Continued on WSR 10/27/2012 * ** T /I /O = 725/40/210 ** *Continued WSR from 10 -26- 2012 * ** Temp =Hot ( Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 616 gal. EC9360A (Surfactant) Average of 25.66 gph for 24 hrs. Pumped a total of 1558 gal. since start of project. Pumped 2898 gal. EC9378A ( Polymer) Average of 120.75 gph for 24 hrs. Pumped a total of 7127 gal. since start of project 10/27/2012 ** *Continued on WSR 10/28/2012 * ** T /I /O = 724/40/240 ** *Continued WSR from 10 -27- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 4000 bwpd. Pumped 614 gal. EC9360A (Surfactant) Average of 27.9 gph for 22 hrs. Pumped a total of 2,172 gal. since start of project. Pumped 2874 gal. EC9378A ( Polymer) Average of 130.63 gph for 22 hrs. Pumped a total of 10,001 gal. since start of project 10/28/2012 Final WHPS= 737/40/230 Valve postitions= SV= closed, WV,SSV,MV,IA,OA =open v TREE = 7-1/16" CM/ -- WELLHEAD= 13-5/8" 5M MCEVOY AO NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR= AXELSON A-1 6 A WHEN MI. WELL 1. WELL 7REQUIRES � I0 A PRE V WHEN ON KB. ELEV = 79.64' — BF ELEV = 5248' WELLBORE BELOW 9 518" WINDOW NOT SHOWN ON KOP = 3d00 DIAGRAM. Max Angle = 91° @ 11994' Datum MD = 10435' ' I 2099' °-14-1/2" HES X NIP, ID = 3.813" I Datum 1VD = 8800' SS — 2700' H FOC 13 -318" CSG, 72 #, L -80, ID = 12.347 " I--I 2700' I Minimum ID = 3.726" @ 10227' "WARNING" RADIO TRANSMITTER IN WEATHER MONITORING SHACK MUST BE TURNED OFF BEFORE 4 -1/2" HES XN NIPPLE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN, CONTACT PAD OPERATOR. 9 -5/8 " X 7" BKR ZIP PKR W/ TIEBACK SLV —I 8410' I 0 19 -5/8" X 7" BKR HMC LNR HANGER I--1 8424' I 9 -5/8" SECTION NILLOUT WINDOW 8580' TO 8630' PERFORATION SUMMARY REF LOG: TCP PERF 10172' —14-1 /2" HES X NIP, ID = 3.813" ANGLE AT TOP PERF: 88° @ 12730' 10183' H7" X 4-1/2" BAKER S -3 PKR, ID = 3.875" Note Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 10206' 1-14-1/2" HES X NIP, ID = 3.813" 3-3/8" 4 12730 - 12868 C 04/02/97 0 10227' I- -14 -1/2" HES XN NIP, ID = 3.725" I 2-7/8" 4 10940 - 11040 0 04/09/97 2 -7/8" 4 11350 - 11410 0 04/09/97 r 10237' —17" X 4-1/2" BKR 2XP PKR W/ TIEBACK, ID = 3.89" 2 -7/8" 4 11460 - 11500 0 04/09/97 10239' 1-14-i /2' WLEG, ID = 4.00" 2-7/8" 4 11800 - 11860 0 04/09/97 4v 4., 10244' H ELMD TT LOGGED 12 -17 -97 I 2 -7/8" 4 12180 - 12220 0 04/09/97 ; :::::1. 11..1111. .11..1..1.. 12630' —14- 112" AVA DRIP BP 04/2/97 4 12240 - 12290 0 04/09/97 •' •. / 1. •. •, ,1,...1.1...1. 111111.11.111,. .. .11111 • 1.1.11..1: �11..II H1..1 ♦1111 11..1..1...1...11 X11 •.11..11..11 ........'.........X. . 1 10503' ': ::: 19 -5/8" CSG, 47 #, L -80, ID = 8.681" I . • • • • :•::.• 1 .... :.',•::.Y. 4141 / 4 -1/2" TBG, 126 #, L -80, BTC -MOD, 0,0152 bpf, ID = 3 958 " I—I 10238' // 7" LNR, 29# L -80, BTC -M, 0.0371 bpf, ID = 6.182" H 10410' I I PBTD ---I 12934' I 4-1/2" LNR. 12.6# L -80, .0152 bpf, ID= 19541 13020' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff 08/16/81 ORIGINAL COMPLETION WELL A -16A 08/05/96 SRB SIDETRACK COM PLETION PERMIT No: '1960980 06/19/01 CWKAK CORRECTIONS API No 50- 029 - 20521 -01 07/24/03 JW /KAK PERF DEPTH CORRECTION SEC 35, T11 N, R13E, 3016' FNL & 1014' FEL 02/14/11 MB /JMD ADDED SSSV SAFETY NOTE 01/17/12 TMWJMD ADDED H2S SAFETY NOTE BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 J Y . Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 May 18, 2012 Mr. Jim Regg SLAttlilED AUG 1 7 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 6 / Subject: Corrosion Inhibitor Treatments of GPB A -Pad Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad A that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, q 1 A 11 - Q-(1). Mehreen Vazir BPXA, Well Integrity Coordinator S • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) A -Pad Date: 04/15/2012 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal A -01A 2012420 50029201080100 1.3 NA 1.3 NA 11.10 7/21/2009 A -02 1710310 50029201090000 1.9 NA 1.9 NA 13.60 7/22/2009 A -03 1710380 50029201130000 0.5 NA 0.5 NA 5.10 7/21/2009 A -04 1720060 50029201150000 0.0 NA NA NA NA NA A -05A 2061280 50029201160100 0.0 NA NA NA NA NA A -06 1720180 50029201180000 0.8 NA 0.8 NA 6.80 7/21/2009 A -07 1730410 50029201310000 0.8 NA 0.8 NA 5.10 8/12/2009 A -08 1740040 50029201320000 No conductor NA NA NA NA NA A -09A 2001740 50029205520100 0.5 NA 0.5 NA 3.40 7/21/2009 A -10 1810300 50029205680000 14.0 NA 14.0 NA 103.70 7/22/2009 A -11 1810380 50029205750000 5.0 NA 5.0 NA 17.00 7/22/2009 A -12A 2071300 50029205150200 0.5 NA 0.5 NA 3.40 7/22/2009 A -13 1811590 50029206720000 0.3 NA 0.3 NA 2.55 4/15/2012 I A -14 1810770 50029206050000 3.3 NA 3.3 NA 17.00 7/19/2009 1 A -15 1810780 50029206060000 0.5 NA 0.5 NA 3.40 7/19/2009 ----7 A -16A 1960980 50029205210100 0.3 NA 0.3 NA 1.70 7/19/2009 A -17A 2061250 50029205200100 0.3 NA 0.3 NA 2.60 7/19/2009 A -18 1921070 50029206300100 SC leak NA NA NA NA NA A -19 1811270 50029206480000 0.8 NA 0.8 NA 3.40 7/19/2009 A -20 1820130 50029207090000 0.8 NA 0.8 NA 5.10 7/20/2009 A -21 1820140 50029207100000 2.0 NA 2.0 NA 16.15 7/20/2009 A -22 1820180 50029207120000 Sealed conductor NA NA NA N/A NA A -23 1820240 50029207160000 0.3 NA 0.3 NA 3.40 7/20/2009 A -24 1820700 50029207430000 29.0 5.8 0.1 11/27/2009 1.70 3/18/2010 A -25A 2011480 50029207640100 0.3 NA 0.3 NA 1.70 8/13/2009 • A -26L1 1971060 50029207946000 0.3 NA 0.3 NA 1.70 7/21/2009 A -27A 1982350 50029208090100 7.5 NA 7.5 NA 71.40 7/20/2009 A -28 1821500 50029208250000 2.5 NA 2.5 NA 20.40 7/20/2009 A -29 1821670 50029208410000 9.0 NA 9.0 NA 62.90 7/21/2009 A -30A 2040780 50029213720100 0.3 NA 0.3 NA 1.70 7/19/2009 A -31A 1990560 50029213830100 0.8 NA 0.8 NA 4.30 7/19/2009 A -32A 1990580 50029213950100 2.0 NA 2.0 NA 17.00 4/11/2012 A -33 1851830 50029214100000 0.8 NA 0.8 NA 3.40 8/12/2009 A -34A 1851050 50029213390100 4.4 NA 4.4 NA 28.90 7/22/2009 A -35 1850510 50029213130000 1.3 NA 1.3 NA 10.20 7/22/2009 A -37 1930070 50029223310000 0.0 NA NA NA N/A No treat A -38 1930320 500292234700 0.1 NA 0.1 NA 0.85 4/15/2012 A -39 1930280 50029223440000 0.5 NA 0.5 NA 3.40 7/21/2009 A -40 1930140 50029223370000 0.5 NA 0.5 NA 3.40 7/22/2009 A -41 1941580 50029225300000 SC leak NA NA NA NA NA A -42A 2061300 50029225420100 0.6 NA 0.6 NA 5.10 7/20/2009 • A -43 1960860 50029226770000 0.3 NA _ 0.3 NA 1.70 8/12/2009 A -44 2090410 50029234120000 1.5 NA 1.5 NA 8.50 6/24/2009 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, August 05, 2011 TO: Jim Regg a / P.I. Supervisor ( 'I ( SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A -16A FROM: Bob Noble PRUDHOE BAY UNIT A -16A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry z2 NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNITA - 16A API Well Number: 50 029 - 20521 - 01 - 00 Inspector Name: Bob Noble Insp Num: mitRCN110801190012 Permit Number: 196 - 098 - Inspection Date: 7/31/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well A -16A - Type Inj. W' i TVD 8695 ` IA 990 2500 . 2470 2460 ' P. 1960980 'TypeTest SPT Test psi 2173 - I OA � 400 460 500 540 Interval 4 YPTST p/F P Tubing 560 560 560 560 Notes: Friday, August 05, 2011 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg (;J. 01/0,/ùl P.I. Supervisor \\ei1 DATE: Wednesday, August 15,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC A-16A PRUDHOE BAY UNIT A- I 6A FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~a- Comm Well Name: PRUDHOE BAY UNIT A-16A API Well Number: 50-029-20521-01-00 Inspector Name: Jeff Jones Insp Num: mitJJ070812201146 Permit Number: 196-098-0 Inspection Date: 8/12/2007 Rei Insp N urn: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i A-16A !Type Inj. ! w TVD I 8695 ./Í IA 400 2410 I 2370 ! 2350 ¡ i i i I P.T. j 1960980 !TypeTÿst ! SPT Test psi I 2173.75 1'OA j 180 220 ! 240 300 , i i i Interval 4YRTST ;/ P/F P ./ Tubing i 880 880 ! 880 i 880 ! ¡ i ! Notes: 4.3 BBLS methanol pumped. I well house inspected; no exceptions noted, NON-CONFIDENTIAL sCJ.\NN¡;O AU G 2 3 2007 Wednesday, August 15,2007 Page I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon B Suspend B Operation Shutdown B Perf°rater'x-] VarianceB Annular DisposalB Alter Casing E] Repair Well E] Plug Perforations r-'] Stimulate[~] Time Extension E] Otherr--~ Chan.~e Approved Proc~ram D Pull Tubinq D Perforate New Pool E] Re-enter Suspended WelID 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 196-0980 Development ~] Exploratory I~1 3. Address: P.O. Box 196612 6. APl Number Anchorage, Ak 99519-6612 Stratigraphic E] Service r~ 50-029-20521-01-00 7. KB Elevation (ft): 9. Well Name and Number: 81.14 KB A-16A 8. Property Designation: 10. Field/Pool(s): ADL-0047472 Prudhoe Bay Field ! PRUDHOE Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): ITotal Depth TVD (ft): IEffective Depth MD <ft)lEffective Depth TVD (ft): Plugs (md): Junk (md): 13020I 9115,5'1 12934I 8996,3 None ' None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 110 20" 94# H-40 27 - 137 27.0 - 137.0 1530 520 Liner 2000 7" 29# L-80 8410 - 10410 7247.7 - 8859.4 8160 7020 Liner 2783 4-1/2" 12.6# L-80 10237 - 13020 8738.2 - 9115.5 8430 7500 Production 8603 9-5/8" 47# L-80 27 - 8630 27.0 7400.7 6870 4760 Surface 2673 13-3/8" 72# L-80 27 2700 27.0 2699.9 4930 2670 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10940 - 11040 8961 - 8962.9 4.5" 12.6 # L-80 25 10239 11350 - 11410 8973 - 8976.8 11460 - 11500 8980 - 8982.5 11800 - 11860 9003 - 9004.8 12180 12220 9008 9011.2 12240 12290 9013 9017.1 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker S-3 Perm Packer 10183 4-1/2" Baker ZXP Packer 10237 4-1/2" MCX I-SSV 2099 7" Baker ZXP Packer 8410 12. Attachments: Description Summary of Proposal [~ 13. Well Class after proposed work: Detailed Operations Program F'-/ BOP Sketch E] ExploratoryE] Development['-] Service[~ 14. Estimated Date for January 1 2004 15. Well Status after proposed work: Commencing] Operation: ' Oil E] GasE] Plugged[-] Abandoned E] 16. Verbal Approval: Date: WAG/~ // GINJFI WINJFI WDSPLE] Commission Representative: Perpared by Garry Oatron 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge.- Contact Jennifer Watson Printed Name Jennifer Watson Title Petroleum Engineer Signature---- .~~~ L~ ~k~3~._ Phone 564-5764 11/14/03 Commission Use Only I Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ...~ , Plug Integrity FI BOP Testl--I Mechancial Integrity Testr-I Location Clearance r--I Other: Subsequent Form Required: .~q ~ ¢~ ~/L./~',~ll~li~ll Cig FJ,* ~,..¢ ra ~~ f~fA THEBY ORDER OFcoMMiSSiON Date: I'~f~ ApprOved by: Form 10-403 Revised 2/2003 ! I k I I I /'A k su,~,f iN D~/Pi' h~ATE bp To: Gary McBride/John Smart GPB Well Ops Team Leaders From: Jennifer Watson Production Engineer Subject: A-16A APERFs PBLWPA016 Capacity Sustainment Date: July 24, 2003 Est. Cost: $205M IOR: 300 BOPD Type CP IOR PR N DS-WL 300 1 A-16A 300 2 A-16A AFE JOB DESCRIPTION PBLWPA016 IBP/perfs/stim PBLWPA016 Pull IBP PRIORITY COMMENTS/OTHER To be pulled after 3-6 months of injection Status: Max Deviation: Perf deviation: Min. D: Last TD tag: Last Downhole Ops: PWI - 4608 bwpd at 1040 psi 91 degrees at 11,994' MD. 86 degrees 3.725" at 10,227' MD (4-1/2" HES XN Nipple) 12,220' CTE on 9/8/99 (IPROF) Iprof on 9/8/99 Well A-16A is a WAG injector that needs additiOnal perforations to help support the recent sidetrack of Y-35A..The proposed perforations (10,780' - 10,880' MD) are intended to provide additional support in the 46P. The procedure includes setting an IBP and pumping mud acid to ensure that the new perforations are able to compete with established perforated intervals. The IBP will be pulled after 3-6 months of injection. Contact Jennifer Watson at x5764, 248- 8862(hm), 275-7599(pgr) with any questions or comments. cc: w/a: A- 16A Well File J. Watson A. Frankenburg A-16Ai Recompletion Program Prepared By: J. Watson Phoneg: 564-5764(w), 248-8862(h), 275-7599 (p) JOB PLANNING DETAILS: Perfs: Perf Deviation: 10940' 11350' 11460' 11800' 12180' 12240' 12730' -11040' -11410' -11500' -11860' -12220' -12290' -12868'(isolated by plug) Horizontal (Approximately 86° at the proposed add perf depth.) / Gas Lift Design: No GLMs. MIT-IA passed 7.5.03 ISSSV: In TD Tag History: 12220' CTMD, 9.08.99 12600' CTMD, 12.17.97 Displacement bbls: 163 bbls (tubing = 156, liner to top perf = 7) Coil String Weight: 23K# @ 12220', 9.08.99 Static: -3300 psi, 225°F NOTE: BP set at 12630 (4/2/97). PREP WORK: Perform: a bullhead SBG treatment with 163 bbls of SBG solution (136 bbls of hot water mixed with 27 bbls of concentrate). Pump at maximum pump rate with a maximum WHP of 3000 psi. Soak for 3 hours. Overflush with 150 bbls of hot water at maximum pump rate. Return to injection. 2. Pull ISSSV. Drift as deep as possible. 11 / 14/2003 1 CT OPERATIONS: 3. SI injection 24 hours prior to the operation to allow BHT to stablize. . If possible, combine the two runs in this step by using a memory gauge carrier. RU CT. RIH with Memory GR BHA. Run tie-in log and flag the coil. Tie-in to WA GR/Acoustilog (7/28/96). RIH with jet nozzle and stingers as necessary to PBTD. Lay in -30 bbls of filtered 7.5% HCl/20% xylene from the perfs to -10500'. Jet another 70 bbls of acid, taking returns to the perfs, while making a down pass to the perfs. Overflush the acid with 150 bbls of filtered 3% NH4C1 (behind pipe) while making multiple passes. POOH. Please note the injectivity in the WSR. Note the potential for H2S in any returns taken to surface. 5. RIH with 3" IBP, pinned for 3000 psi differential pressure, and set at 10910' +/- 20'. Pump the ball on seat and wait 1 hour prior to inflating the IBP. Pressure test the IBP to 3000 psi. (Don't pressure test more than the inflation pressure). POOH. 6. MU 2-7/8" PJ, 6 SPF and perf from 10780' - 10880' (reference WA GR/Acoustilog, 7/28/96). Tag the IBP for depth control. 7. RIH with jetting nozzle and pump the following while making multiple passes across the perfs: 25 bbls 50 bbls 100 bbls 3% NH4C1 with 10% U~66 and 0.2% F75N 7.5% HC1 9% - 1% HC1-HF Pump the overflush while making multiple passes to PBTD: 150 bbls 3% NH4CI overflush with 10% U-66 and 0.2% F75N Go to 3000 psi if necessary to establish injection. Once acid is at the perfs the maximum treating pressure should be 2000 psi. All fluids should be filtered to 3 microns. Don't add friction reducer. Please note the initial and final injectivity in the WSR. Please note the vitals in the WSR when each stage hits the perfs. Please run a cable so that the pump truck can record back side WHP on the treating report. Please e-mail the EXCEL treating report (1 minute readings) to the program author. 9. Tag the IBP to confirm it's still there. POOH. RDMO. Put on water injection. The IBP will be pulled in approximately 6 months, once injection is established into the new perfs. 11/14/2003 2 Treatment Design: 2100 gal 7.5% HC1 0.5% A261 0.5% A201 20 ppt L58 0.2% Fl03 0.5% W54 0.5% W35 4200 gal 9:1 HCI:HF 0.5% A261 0.5% A201 0.2% Fl03 20 ppt L58 0.5% W54 0.5% W35 4200 gal 7.5% HC1/20% X¥1ene 0.6% A261 4 ppt A179 8 ppt A153 20 ppt L58 0.2% Fl03 0.5% W54 0.5% W35 1.5% U-74 20% A26 -325 bbls 3% NH4C1 water with 10% U-66 and 0.2% F75N Please note the acid titrations and iron ppm on the WSR. 11 / 14/2003 3 TREE= 7-1/16' CIW WR LHEAD= 13-5/8" 5M MCEVOY A 16A/'~ ' sAFETY N°TEs: WELL ExceEDS 7° pEG @ 1 °523'AND A CTU~TOR= A XELSON ' GOES "ORIZONTA L @ 10900'. PRE-SDTRK WELLBORE KB. F_LEV = 79.64' I BELOW 9 5/8" WINDOW NOT SHOWN ON DIAGRAM BF. ELEV = 52.48 KOP = 3400': J Max An ie = 91 ,)~.mr~,~= ~o~' , I ! t 20~,' H4-~,2",~×~,~.,~--~.~" Datum TVD = 8800' SS I13-3/8"CSG, 72#,L-80, ID=12.347" H 2700' J-~ '.W_. ''~ 10227' "WARNING" RADIO TRANSIVITTER IN WEATHER Minimum ID 3,725" , MONITORING SHACK MUST BETURNED OFF BM:ORE 4-112" H ES XN NIPPLE ANY WELL WORK INVOLVING EXPLOSIVES CAN BEGIN. J CONTACT PAD OPERATOR. 9-5/8" SECTION MILLOUT WINDOW 858O' TO 863O' 10172' 4-1/2 HESX NIP D 3 813 SUMM^. " , --. "1 ~:LOG: TC~mR~ / ~//[ 10183' ~7"X4-1/2"~AKEaS-3PK~,~D=a. aTS"I ANGLEATTOP PERF: 88 @ 12730' . . Refer to Production DBfor historical perf data ! J / /1 ~u,~uu j j , - · j Note:j SPFSIZE INTERVAL I OprYSqz, DATE ~ ~,/.~' 10227' H4-1/2"HESXN NIP, ID=3.725"J 3-3/8,, 4 12730-12868 c 04/02197 , , .,'~/ //i '10237 I-'17"X 4--1/2"BKRZXPPKRW/TIEBACK, ID=389" i 2-7/8" 4 10940 - 11040 0 04/09/97 ~ ')(.. ~. ~ ' 2-7/8" 4 11800-11860 0 04109/97~0~00~0~~ ~ .1U'~I.~ .. 2-7/8"4 12180-12220 0 04109197 ~~ ~1 120:10~' 1~4-112"AVADW~P0412/97 o / ' : _ I,,"~To H ,~2~4, l"~_ I 4-1/2" LNR, 12.6# b-80, .0152 bpf, ID = 3.958" I 13020' DATE REV BY COMMENTS DATE REV BY COMIVENTS PRUDHOEBAY UNIT 08/16/81 ORIGINAL COMPLETION WELL: A-16A 08105/96 SRB SlDErRACK COMPLETION PERMIT No: 1960980 I 06/19/01 CH/KAK OORRECTIONS ARNo: 50-029-20521-O1 07/24/03 JW/KAK PERFDB~THCORRECTION I ' SEC35, T11N, R13E, 3016' FNL &1014'FEL I BP Exploration (Alas ka) PERFORATION SUiVIMARY REF LOG: TCP PERF ANGLEATTOP PERF: 88 @ 12730' Note: Refer to Production DB for historical ~erf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12730 - 12868 C 04/02/97 2-7/8" 4 10940 - 11040 O 04/09/97 2-7/8" 4 11350 - 11410 O 04/09/97 2-7/8" 4 11460 - 11500 O 04/09/97 2-7/8" 4 11800 - 11860 O 04/09/97 2-7/8" 4 12180 - 12220 O 04/09/97 2-7/8" 4 12240-- 12290 O 04/09/97 DATE REV BY COMMENTS DATE REV BY COMIVENTS 08/1 6/81 ORIGINAL COMPLETION 08105/96 SRB SIDETRACK COMPLETION 06/19/01 CH/KAK OORRECTIONS 07/24/03 JW/KAK PERF DB~TH CORRECTION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: WelllA-35 P.T.D.I1850510 Notes: Welll^-16A P.T.D.I1960980 Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / A 07/05/03 Pat Lattner John Crisp Packer Depths (ft.) I Pretest Initial 15 Min. 30 Min. Type test Test psiI 2,062~ I Casin~l 6001 2'5201 2'4901 2'490l P/F/ P I s I MD~V~I I I TubingI 9001 9001 9001 9001 IntervaI 4I Ii Typelnj' iTypetest P I Testps,l 2,1731 I Casinc, ll 6501 2,5001 2,4501 2,4201 P/FI PI Type Type Inj. Type Inj. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive 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 O = Other (describe in notes) MIT Report Form Revised: 06/19/02 MIT PBU A-16, 35 07-05-031 .xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: July 5.2003 Commissioner ,,~k~,~.-~ .~, SUBJECT: Mechanical Integrity Tests THRU: Jim Regg "":~/2~ BPX P.I. Supervisor Prudhoe Bay Field A Pad FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. We,,IA-~eA I Typelnj.I S I T.V.D. 18248 I Tubingl 900 1900 1900Ieoo I lntervall 4 P.T.D.I 1960980IType testI P I Testpsil 2000 I Casingl 650 I 25OO I 2400 I 2420 I P/F I P Notes: Pretest OA psi. 420 600 psi. during test. 4.2 BBL pumped. WellI A-35 Typelnj.I S I~.V.~.I~4~I Tubi.gl,oso 11050 11050 1~050 lintervall 4 P.T.D.I 1850510 Type testI P I Testpsil 2000 I Casingl 600 I 2520 I 2490 I 249° I P/F I E Notes: Pretest OA psi. 0 100 psi. during test. 2.9 BBL pumped. Well l I Type Inj. P.T.D. I I Type test Notes: WellI Type Inj. P.T.D.I Notes: WellI P.T.D. I Type test' Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = 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 Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2__ Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. cc: MIT report form 5/12/00 L.G. 2003-0705_M IT_PB U_A-35_jc.xIs 7/17/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Schmoo-S-Gone Pull tubing _ Alter casing _ Repair well _ Other_× Schmoo B Gone 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 81 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2263' FSL, 1014' FEL, Sec. 35, T11 N, R13E, UM (asp's 654394, 5947430) A-16A At top of productive interval 9. Permit number / approval number 908' FNL, 3821' FEL, Sec. 02, T10N, R13E, UM (asp's n/a) 196-098 At effective depth 10. APl number 2484' FNL, 369' FWL, Sec. 02, T10N, R13E, UM (asp's 650600, 5942603) 50-029-20521-01 At total depth 11. Field / Pool 2492' FSL, 145' FWL, Sec. 02, T10N, R13E, UM (asp's 650383, 5942297) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 13020 feet Plugs (measured) 4-1/2" AVA DWP BP @ 12630' (04/02/1997) true vertical 9115 feet Effective depth: measured 12630 feet Junk (measured) true vertical 9033 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110' 20" x 30" 72 c.f. concrete 137' 137' Surface 2671' 13-3/8" 3794 c.f. Arcticset II 2698' 2697' Intermediate 8553' 9-5/8" 1590 c.f. Class 'G', 130 8580' 7364' c.f. Arcticset II Liner 6410' 7" 200 c.f. Class 'G' 8410' - 10410' 7247' - 8858' Side Track Liner 2783' 4-1/2" 335 c.f. Class 'G' 10237' - 13020' 8738' - 9115' Perforation depth: measured Open Perfs 10949;' - 11040', 11350' - 11410', 11460' - 11500', 11800' - 11860', Open Perfs Continued 12180'- 12220', 12240'- 12290', Below BP 12730'- 12868' true vertical Open Perfs 8961' - 8963', 8973' - 8977', 8990' - 8992', 9003' - 9005', Open Perfs Continued 9008'. 9011,9013' _ 9017', Below BP 8955' - 8975' ~ O Tubing (size, grade, and measured depth) 4-1/2" 12.6#, L-80 TBG @ 10183'. 4-1/2" Tubing Tail to 10239'. Packers & SSSV (type & measured depth) 9-5/8" x7" BKR ZXP Packer @ 8410'. 7" x 4-1/2" BKR S-3 Packer @ 10183'. 7" x 4-1/2" BKR ZXP PKR w/Tieback @ 10237'. 4-1/2" HES X Nipple @ 2099'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative DaiIv Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 09/29/2001 13613 3610 Subsequent to operation 10/02/2001 20503 3475 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service Miscible Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~4~J)~ Title: TechnicalAssistant Date October04, 2001 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE A-16A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 10/01/2001 SCHMOO B GONE: SBG TUBING WASH EVENT SUMMARY 10/01/2001 SBG TUBING WASH FLUIDS PUMPED BBLS 15 METHANOL 198 2% KCL WATER 193 SCHMOO-B-GONE 406 TOTAL Page 1 PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 07/21/98 RUN RECVD 96-098 96-098 96-098 96--098 96-098 96-098 96-098 96-098 96-098 96-098 CCL- SETTING ZDENS/CN/GR DIFL-GR ACOUSTIC/GR L~615-8952 ~n/10420-12950 ~0420-13008 ~I~- 10420-12970 BOREHOLE PROF ~/10420-13008 SSVD ~/10420-13008 7427 '~~10420-13006 NGP-MD ~ 9155-13020 NGP-T~ ~L 7828-9112 7919 ~D/2,4-11 SPERRY GR 10-407 ~COMPLETION DATE :/ ~-1/~/ DAILY WELL OPS R P/ q/ '~1 TO ~/ ~-/q~/ Are dry ditch samples required? yes ~And received? 1 07/26/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/30/96 FINAL 02/19/97 FINAL 02/19/97 03/12/97 yes ne- Was the well cored? Are well tests required? yes ~_____Received? ,- Well is in compliance ~/ Initial COMMENTS yes ~_~Analysis & description received? STATE OF ALASKA -- . ALASKA C ~,ND GAS CONSERVATION COM, ~.JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 []Operation Shutdown []Stimulate I--I Pull Tubing l--lAIter Casing F-I Repair Well i--I Other t5. Type of well: [] Development [--I Exploratory [] Stratigraphic [~ Service 4. Location Of well at surface 3016' SNL, 1014' WEL, SEC. 35, T11N, R13E At top of productive interval 908' SNL, 3821' WEL, SEC. 02, T10N, R13E At effective depth 2726' SNL, 5086' WEL, SEC. 02, T10N, R13E At total depth 2776' SNL, 5130' WEL, SEC. 02, T10N, R13E [] Plugging [] Perforate 6. Datum Elevation (DF or KB) KBE: 81.14 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number A- 16Al 9. Permit Number / Approval No. 96-98 10. APl Number 50-029-20521-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 13020 true vertical 9115 Effective depth: measured 12934 true vertical 9077 Casing Length Structural Conductor 11 O' Surface 2671' Intermediate 8553' Production Liner 6410' feet Plugs (measured) feet feet Junk (measured) feet Size Cemented MD TVD 20"x30" 8 cu yds concrete 137' 137' 13-3/8" 3794 cuft Arcticset I! 2698' 2697' 9-5/8" 1590 cuft Class 'G', 130 cu ft 8580' 7364' 7" 200 sx Class'G' 8410'-10410' 7247'-8858' Perforation depth: measured true vertical 1~94~'~11~4~';1135~~~1141~';1146~'~115~~~;118~~'~1186~';1218~'~1222~';1224~~~1229~'; 12730'-12868' ~pen) 8960'-9056 ~ intervals) Tubing (size, grade, and measured depth) 4-1/2", L-80, 12.6# @ 10239 Packers and SSSV (type and measured depth) Packer @ 10183' SSSV @ 2099' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classifications as: E] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended [] Daily Report of Well Oper,~ons _ 17. I hereby o,¢¢if~ that ti?o' forcfg,Cing is true/anC/,e/~rrect to the best of my knowledge S igne.¢"' ~C~H~ //¢/1'~/~~'~-~' Title Technical Assistant III Service Miscible Injector Prepared By Name/Number: Form 10-404 Rev. 06/15/88 Submit In Duplic~ A-16A ADDPERF O4/09/97 SUMMARY The following additional interval were perforated using 2 7/8" guns, 4 SPF, zero orientation and 90° phasing. 10940' -11040' MD 11350' - 11410' MD 11460' - 11500' MD 11800' - 11860' MD 12180' - 12220' MD 12240' - 12290' MD .r- -SLJn O Fi I I_1_1 IM G WELL LOG TRANSMITTAL To: State of Alaska March 12, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~w MWD Formation Evaluation Logs - A- 16A, AK-MW-60090 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-20521-01. 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company O F:t I I--I-- I IM G S ~ I:tL/I r" ~: S WELL LOG TRANSMIIWAL To: State of Alaska February 19, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs A-16A, AK-MW-60090 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of.' £rrn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 A-16A: 2" x 5" MD Cramma Ray Logs: 50-029-20521-01 2"x 5" TVD Gamma Ray Logs: 50-029-20521-01 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc, Company STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION CuMMISSION 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 BP Exploration (Alaska) Inc. 96-98 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20521-01 4. Location of well at surface ~ ~;~.,~,i '., ..... ~ '~~,~ 9. Unit or Lease Name '""' Prudhoe Bay Unit 3016' S NL, 1014' W EL, SEC. 35, T11N, R13E { ~..~,~!.~~-¥-~-/¢--~ ~ At top of productive interval 10. Well Number 908' SNL, 3821' WEL, SEC. 02, T10N, R13E -"-- ~ ~ f7~' [: A-16Ai At total depth i .--~~'--~i- ~.Ii' 11. Field and Pool 2776' SNL, 5130' WEL, SEC. 02, T10N, R13E Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 81.14I ADL 047472 12. Date Spudded07/13/96 I13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fIsh°re I 16' N°' °f C°mpleti°ns07/27/96 08/04/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~l. Thickness of Permafrost 13020 9115 FTI 12934 9077 FTI []Yes []NoI (X-Nipple) 2099'MD! 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, LWD: DIR/FE, GR, CCL, DIL, CZDL, CNL, DAL, DLL, MLL, CBL 23. CASING, LINER AND CEMENTING RECORD CASING SE'FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20"X30" Insulated Conductor Surface 110' 36" 8 cu yds concrete 13-3/8" 72# L-80 Surface 2698' 17-1/2" 3794 cu ft Arcticset II 9-5/8" 47# L-80 Surface 8580' 12-1/4" 1590 cu ft Class 'G', 130 cu ft Arcticset 7" 29# L~80 8410' 10410' 8-1/2" 200 sx Class 'G' 4-1/2" 12.6# L-80 10237' 13020' 6" 335 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom !25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 4 spf 4-1/2", L-80, 12.6# 10239' 10183' MD TVD MD TVD 12730' - 12868' 9036' - 9056' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protect with 155 Bbls Diesel i27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 8, 1996 I Miscible Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I iFIow Tubing Casing PressureCALCULATED ~ OIL-DEL GAS-MCF WATER-DEL OIL GRAVITY-APl (CORR) iPress. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. ~)l~t~'o~ [l~sE D AUG 50 1996 Alaska 0Il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate -~' Geologic Mark ~ 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Sag River 10407' 8856' Shublik 10440' 8875' Top of Sadlerochit 10722' 8949' 31. List of Attachments Summary of Daily Drilling Reports. Surveys 32. I hereby certify tha~t'"~ foreg~e'¢and correct to the best of my knowledge ~ I~,~.,~/ff ~, Signed ~'Y/~'~'V'( ~k/~.'~ Title Senior Drilling Engineer Dan Stoltz Date ~.'//7. ~' Prepared By Name/Number: Terrie Hut~ble, 564-4628 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 §: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23' Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO WelIName: A-16Ai Rig Name: Nabors 18E AFE: 4P0827 Accept Date: 07/09/96 Spud Date: 07/1 3/96 Release Date: 08/04/96 Jul 9 1996 (1) Rigged down Drillfloor / Derrick. Rig moved 100 %. Jul 10 1996 (2) Rigged up Fluid system. Rigged up Drillfloor / Derrick. Held safety meeting. Removed Hanger plug. Circulated at 9152 ft. Installed Hanger plug. Circulated at 9152 ft. Installed Hanger plug. Removed Xmas tree. Rigged up BOP stack. Jul 11 1996 (3) Tested BOP stack. Rigged up Lubricator. Pulled Tubing hanger. Laid down 9100 ft of Tubing. Rigged down Tubing handling equipment. Rigged up Top ram. Tested BOP stack. Conduct braided cable operations - 5/16 size cable. Jul 12 1996 (4) Conduct braided cable operations - 5/16 size cable. Tested Casing. Removed Wellhead primary components. Tested Casing. Made up BHA no. 1 . R.I.H. to 6000 ft. Tested Kelly cocks. R.I.H. to 8840 ft. Circulated at 8840 ft. Laid down 280 ft of 5 in OD drill pipe. Milled Casing at 8580 ft. Jul 13 1996 (5) Milled Casing at 8580 ft. Circulated at 8630 ft. Pulled out of hole to 230 ft. Pulled BHA. Serviced BOP stack. Ran Drillpipe in stands to 8730 ft. Washed to 8730 ft. Circulated at 8730 ft. Jul 14 1996 (6) Circulated at 8730 ft. Mixed and pumped slurry- 36 bbl. Pulled Drillpipe in stands to 7570 ft. Circulated at 7570 ft. Held 1500 psi pressure on 0 bbl squeezed cement. Pulled Drillpipe in stands to 0 ft. Made up BHA no. 2. R.I.H. to 8000 ft. Circulated at 8000 ft. Held drill (Kick (well kill)). R.I.H. to 8280 ft. Washed to 8381 ft. Drilled cement to 8585 ft. Set tool face. Drilled to 8714 ft. Operations Summary for: . ,6Ai Jul 15 1996 (7) Drilled to 9155 ft. Circulated at 9155 ft. Pulled out of hole to 664 ft. Pulled BHA. Made up BHA no. 3. R.I.H. to 9155 ft. Drilled to 9160 ft. Repaired High pressure lines. Jul 16 1996 (8) Repaired High pressure lines. R.I.H. to 9120 ft. Drilled to 9411 ft. Repaired Mud pump fluid end. R.I.H. to 9400 ft. Drilled to 9580 ft. Jul 17 1996 (9) Drilled to 9580 ft. Circulated at 10126 ft. Pulled out of hole to 660 ft. Pulled BHA. Made up BHA no. 4. Serviced Block line. R.I.H. to 10100 ft. Drilled to 10131 ft. Took MWD survey at 10131 ft. Pulled out of hole to 2500 ft. Jul 18 1996 (10) Pulled out of hole to 660 ft. Pulled BHA. Tested BOP stack. Made up BHA no. 5. R.I.H. to 10109 ft. Drilled to 10400 ft. Circulated at 10400 ft. Drilled to 10432 ft. Circulated at 10432 ft. Jul 19 1996 (11) Circulated at 10432 ft. Pulled out of hole to 9269 ft. R.I.H. to 10432 ft. Circulated at 10432 ft. Pulled out of hole to 660 ft. Pulled BHA. Rigged up Top ram. Ran Casing to 2000 ft (7 in OD). Circulated at 2000 ft. Ran Drillpipe in stands to 8580 ft. Circulated at 8580 ft. Ran Casing on landing string to 10410 ft. Circulated at 10410 ft. Mixed and pumped slurry - 40 bbl. Displaced slurry - 216 bbl. Retrieved downhole equipment - Liner hanger. Jul 20 1996 (12) Reverse circulated at 8410 ft. Pulled Drillpipe in stands to 8250 ft. Circulated at 8250 ft. Laid down 700 ft of Drillpipe. Circulated at 7550 ft. Pulled Drillpipe in stands to 0 ft. Rigged up Top ram. Made up BHA no. 6. R.I.H. to 8410 ft. Washed to 8462 ft. R.I.H. to 10324 ft. Circulated at 10423 ft. Tested Casing - Via annulus and string. Held drill (Kick (well kill)). Drilled cement to 10323 ft. Jul 21 1996 (13) Drilled cement to 10442 ft. Performed formation integrity test. Circulated at 10410 ft. Pulled out of hole to 182 ft. Pulled BHA. Made up BHA no. 7. Serviced Block line. R.I.H. to 10399 ft. Logged hole with LWD: DIR/FE from 10360 ft to 10392 ft. Drilled to 10506 ft. Circulated at 10506 ft. Pulled out of hole to 4000 ft. Page 2 Operations Summary for: . ,6Ai Jul 22 1996 (14) Pulled BHA. Made up BHA no. 8. R,I.H. to 10435 ft. Logged hole with LWD: DIR/FE from 10436 ft to 10482 ft. Circulated at 10410 ft. Pulled out of hole to 4000 ft. Pulled BHA. Made up BHA no. 9. Rig waited: Materials. Made up BHA no. 9. R.I.H. to 10453 ft. Washed to 10506 ft, Drilled to 10565 ft. Jul 23 1996 (15) Drilled to 10745 ft. Circulated at 10720 ft. Pulled out of hole to 216 ft. Pulled BHA. Made up BHA no, 10. R.I.H. to 10745 ft. Drilled to 10875 ft. Jul 24 1996 (16) Drilled to 11793 ft, Pulled out of hole to 1000 ft. Jul 25 1996 (17) Pulled out of hole to 213 ft. Pulled BHA, Retrieved Wear bushing, Investigated pressure change. Tested BOP stack. Installed Wear bushing. Made up BHA no. 11. Serviced Block line. R,I.H. to 11793 ft. Drilled to 12180 ft. Jul 26 1996 (18) Drilled to 12604 ft. Circulated at 12604 ft. Pulled out of hole to 229 ft. Pulled BHA. Made up BHA no. 12. R.I.H. to 12604 ft. Drilled to 12680 ft. Jul 27 1996 (19) Drilled to 12745 ft. Pulled out of hole to 4741 ft. Pulled BHA, Made up BHA no. 13. Singled in drill pipe to 5200 ft. R.I.H. to 12745 ft. Drilled to 12776 ft. Jul 28 1996 (20) Drilled to 13020 ft. Circulated at 13020 ft. Pulled out of hole to 10410 ft. R.I.H. to 13020 ft. Circulated at 13020 ft. Pulled out of hole to 4740 ft. Laid down 438 ft of 3.5 in OD drill pipe. Pulled BHA. Held safety meeting. Rigged up Logging/braided cable equipment. Ran Drillpipe to 4700 ft (3.5 in OD). Serviced Block line. Jul 29 1996 (21) Ran Drillpipe in stands to 10031 ft. Set downhole equipment (wireline). Ran electric logs. Held safety meeting. Ran electric logs. Held drill (Fire). Conduct braided cable operations - 5/16 size cable. Flow check. Pulled Drillpipe in stands to 5000 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Rigged down sub- surface equipment - Formation logs. Held safety meeting. Ran Casing to 120 ft (4.5 in OD). Page 3 Operations Summary for: ,, i6Ai Jul 30 1996 (22) Ran Casing to 2700 ft (4.5 in OD). Circulated at 2700 ft. Ran Drillpipe in stands to 6500 ft. Held safety meeting. Ran Drillpipe in stands to 10400 ft. Circulated at 10400 ft. Ran Drillpipe in stands to 13020 ft. Circulated at 13020 ft. Held safety meeting. Mixed and pumped slurry- 71 bbl. Circulated at 10230 ft. Pulled Drillpipe in stands to 5000 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft. Laid down 2800 ft of Drillpipe. Ran Tubing to 90 ft (2.375 in OD). Jul 31 1996 (23) Installed Bore protector. Ran Tubing to 2450 ft (2.375 in OD). Circulated at 2450 ft. Pulled Tubing in stands to 1535 ft. Held safety meeting. Pulled Tubing in stands to 0 ft. Made up BHA no. 14 . R.I.H. to 10237 ft. Circulated at 10237 ft. Pulled out of hole to 8500 ft. Held safety meeting. Pulled out of hole to 0 ft. Held drill (Spill). Laid down 2492 ft of 2.375 in OD drill pipe. Aug I 1996 (24) Pulled BHA. Tested All functions. Made up BHA no. 15 . Held safety meeting. Singled in drill pipe to 2800 ft. R.I.H. to 10325 ft. Washed to 10746 ft. R.I.H. to 12177 ft. Drilled cement to 12207 ft. Held safety meeting. Drilled cement to 12240 ft. Laid down 650 ft of 5 in OD drill pipe. Drilled cement to 12530 ft. Aug 2 1996 (25) Drilled cement to 12934 ft. Circulated at 12934 ft. Tested Casing - Via annulus. Circulated at 12934 ft. Tested Casing - Via annulus. Pulled out of hole to 2704 ft. Pulled BHA. Aug 3 1996 (26) Serviced Block line. Rigged up Wireline units. Ran electric logs. Rigged down Wireline units. Held safety meeting. Ran Drillpipe to 2763 ft (2.875 in OD). Ran Drillpipe in stands to 12868 ft. Rigged up High pressure lines. Held safety meeting. Perforated from 12730ftto 12868 ft. Reverse circulated at 10114 ft. Circulated at 10114 ft. Laid down 5250 ft of Drillpipe. Aug 4 1996 (27) Laid down 12718 ft of Drillpipe. Laid down 154 ft of Tubing. Rigged up Top ram. Held safety meeting. Ran Tubing to 10239 ft (4.5 in OD). Circulated at 10239 ft. Ran Tubing on landing string to 0 ft. Injectivity test - 120 bbl injected at 1900 psi. Page 4 Operations Summary for: r, ~6Ai Aug 5 1996 (28) Injectivity test - 120 bbl injected at 1900 psi. Set packer at 10182 ft with 3650 psi. Installed Hanger plug. Rigged down BOP stack. Installed Xmas tree. Removed Hanger plug. Tested Permanent packer. Freeze protect well - 35 bbl of Diesel. pits with Water. Fill Page 5 SPERRY-SUN DRILLING SERVICES .... ANCHORAGE ALASKA PAGE 1 SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai 500292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 MWD SURVEY JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8501.16 7309.71 7228.57 46 10 8585.00 7367.92 7286.78 45 52 8747.57 7490.31 7409.17 36 28 8779.14 7515.83 7434.69 35 42 8810.94 7541.88 7460.74 34 20 S 54.69 W .00 1922.66S 2483.68W S 55.19 W .55 1957.32S 2533.07W S 44.50 W 7.21 2025.33S 2615.13W S 37.70 W 12.91 2039.31S 2627.34W S 32.30 W 10.64 2054.24S 2637.81W 3026.59 3083.90 3187.50 3206.01 3224.24 8842.51 7568.05 7486.91 33 40 8874.38 7594.65 7513.51 33 5 8906.58 7621.51 7540.37 33 54 8936.75 7646.57 7565.43 33 45 8967.97 7672.55 7591.41 33 33 S 29.00 W 6.21 2069.42S 2646.81W S 24.70 W 7.64 2085.06S 2654.73W S 21.50 W 6.02 2101.40S 2661.70W S 17.60 W 7.21 2117.22S 2667.32W S 13.80 W 6.78 2133.87S 2672.00W 3241.79 3259.05 3276.32 3292.35 3308.49 8999.59 7698.88 7617.74 9030.43 7724.53 7643.39 9062.25 7750.98 7669.84 9087.98 7772.39 7691.25 9167.95 7838.85 7757.71 33 43 S 9.50 W 7.55 33 39 S 5.60 W 7.02 33 53 S 1.30 W 7.55 33 32 S 3.60 E 10.65 34 4 S 10.10 E 4.57 2151.02S 2675.53W 3324.35 2167.97S 2677.78W 3339.27 2185.61S 2678.84W 3354.05 2199.88S 2678.56W 3365.31 2244.01S 2673.24W 3397.49 9261 . 45 7916 . 39 7835 . 25 9354 . 88 7994 . 04 7912 . 90 9448 . 50 8071 . 99 7990 . 85 9540 . 27 8148 . 80 8067 . 66 9633 . 07 8227 . 14 8146 . 00 33 52 S 12.10 E 1.21 33 40 S 10.90 E .75 33 35 S 10.30 E .37 32 44 S 8.20 E 1.56 32 5 S 9.20 E .91 2295.28S 2663.18W 3432.55 2346.18S 2652.83W 3467.14 2397.16S 2643.29W 3502.28 2446.71S 2635.21W 3537.14 2495.88S 2627.69W 3572.04 9728.05 8307.80 8226.66 9821.01 8387.04 8305.90 9914.31 8466.71 8385.57 10007.83 8546.35 8465.21 10064.72 8594.71 8513.57 31 39 S 8.80 E .50 31 23 S 7.90 E .58 31 19 S 5.80 E 1.17 31 55 S 7.40 E 1.10 31 38 S 4.40 E 2.82 2545.42S 2619.84W 3607.04 2593.50S 2612.78W 3641.34 2641.70S 2606.99W 3676.50 2690.40S 2601.35W 3712.14 2720.19S 2598.27W 3734.17 10102.00 8626.44 8545.30 10132.58 8652.39 8571.25 10163.22 8677.99 8596.85 10194.16 8703.29 8622.15 10225.99 8728.77 8647.63 31 39 S 5.60 E 1.69 32 15 S 2.90 E 5.07 34 25 S 1.40 W 10.45 35 49 S 4.60 W 7.47 37 49 S 8.20 W 9.24 2739.68S 2596.56W 3748.76 2755.81S 2595.37W 3760.98 2772.64S 2595.16W 3774.34 2790.41S 2596.10W 3789.14 2809.36S 2598.24W 3805.60 10257.49 8753.21 8672.08 10288.55 8776.47 8695.33 10319.61 8798.90 8717.76 10349.93 8819.98 8738.84 10382.73 8841.67 8760.53 40 25 S 12.80 W 12.37 42 37 S 16.70 W 10.93 44 56 S 19.60 W 9.87 46 58 S 23.40 W 11.24 50 13 S 25.60 W 11.11 2828.88S 2601.88W 3823.42 2848.78S 2607.14W 3842.51 2869.19S 2613.84W 3862.87 2889.46S 2621.84W 3883.90 2911.84S 2632.05W 3907.94 RECEIVED AUG 3 0 1996 Alaska 011 & Gas Cons. Commission Anchorage S~-ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai 500292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 MWD SURVEY JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10458.10 8885.73 8804.59 58 9 10487.22 8900.14 8819.00 62 33 10523.42 8914.69 8833.55 70 1 10555.60 8924.19 8843.05 75 37 10587.60 8932.06 8850.92 75 52 S 28.90 W 11.10 2966.08S 2660.09W S 33.40 W 20.21 2987.72S 2673.19W S 36.70 W 22.23 3014.81S 2692.23W S 36.90 W 17.41 3039.42S 2710.64W S 37.20 W 1.22 3064.17S 2729.33W 3968.18 3993.35 4026.46 4057.19 4088.20 10619.76 8939.33 8858.19 78 0 10649.91 8944.33 8863.19 82 52 10680.45 8947.18 8866.04 86 26 10710.96 8948.86 8867.72 87 13 10746.91 8950.85 8869.71 86 25 S 36.40 W 7.05 3089.25S 2748.09W S 35.60 W 16.33 3113.30S 2765.56W S 35.40 W 11.74 3138.05S 2783.21W S 35.40 W 2.56 3162.88S 2800.86W S 35.30 W 2.24 3192.16S 2821.63W 4119.52 4149.24 4179.64 4210.09 4245.98 10777.71 8952.77 8871.63 86 24 10809.24 8954.73 8873.59 86 27 10839.98 8956.65 8875.51 86 22 10870.92 8958.17 8877.03 88 0 10900.79 8959.12 8877.98 88 21 S 35.50 W .65 3217.21S 2839.43W S 34.60 W 2.85 3242.98S 2857.50W S 34.70 W .42 3268.22S 2874.95W S 34.50 W 5.28 3293.65S 2892.49W S 34.90 W 1.80 3318.19S 2909.49W 4276.71 4308.16 4338.82 4369.70 4399.54 10933.09 8959.99 8878.85 88 33 10964.10 8960.72 8879.58 88 44 10994.26 8961.32 8880.18 88 58 11026.23 8961.87 8880.73 89 2 11057.23 8962.38 8881.24 89 4 S 33.10 W 5.60 3344.96S 2927.54W S 34.80 W 5.51 3370.67S 2944.85W S 33.20 W 5.36 3395.67S 2961.71W S 33.50 W .96 3422.37S 2979.29W S 33.40 W .34 3448.23S 2996.37W 4431.78 4462.74 4492.86 4524.77 4555.71 11089.07 8962.84 8881.70 89 11119.19 8963.23 8882.09 89 11150.62 8963.92 8882.78 88 11182.06 8964.92 8883.78 88 11212.75 8966.00 8884.86 87 15 15 13 7 52 S 33.30 W .65 3474.83S 3013.88W S 32.70 W 1.99 3500.08S 3030.28W S 34.30 W 6.07 3526.28S 3047.62W S 34.30 W .32 3552.24S 3065.33W S 33.80 W 1.81 3577.66S 3082.50W 4587.49 4617.55 4648.91 4680.31 4710.95 11243.57 8967.26 8886.12 87 25 11275.35 8968.75 8887.61 87 11 11306.95 8970.32 8889.18 87 6 11337.00 8971.84 8890.70 87 4 11367.96 8973.54 8892.40 86 39 S 34.60 W 2.99 3603.12S 3099.81W S 33.60 W 3.22 3629.41S 3117.60W S 33.70 W .42 3655.68S 3135.09W S 34.20 W 1.67 3680.58S 3151.85W S 34.30 W 1.39 3706.13S 3169.25W 4741.71 4773.42 4804.93 4834.91 4865.79 11399.41 8975.41 8894.27 86 33 11430.25 8977.29 8896.15 86 27 11463.00 8979.34 8898.21 86 19 11494.87 8981.40 8900.26 86 16 11526.03 8983.52 8902.38 85 56 S 34.00 W 1.00 3732.11S 3186.88W S 34.00 W .29 3757.63S 3204.09W S 34.60 W 1.87 3784.63S 3222.51W S 33.00 W 5.01 3811.06S 3240.20W S 34.50 W 4.92 3836.90S 3257.47W 4897.15 4927.90 4960.56 4992.31 5023.36 PAGE 3 SD~R,RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai 500292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 MWD SURVEY JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11555.90 8985.65 8904.51 85 51 11586.93 8987.87 8906.73 85 56 11646.99 8991.97 8910.83 86 14 11670.76 8993.52 8912.38 86 16 11708.95 8996.09 8914.95 86 0 S 34.90 W 1.36 3861.40S 3274.43W S 35.40 W 1.63 3886.70S 3292.25W S 35.40 W .50 3935.55S 3326.96W S 34.60 W 3.36 3954.98S 3340.56W S 34.20 W 1.28 3986.42S 3362.09W 5053.13 5084.07 5143.97 5167.68 5205.75 11740.34 8998.26 8917.12 86 4 11774.67 9000.62 8919.48 86 1 11805.83 9002.42 8921.29 87 20 11837.00 9003.50 8922.36 88 40 11866.75 9004.11 8922.97 88 58 S 35.60 W 4.46 4012.10S 3380.00W S 35.40 W .61 4039.98S 3399.89W S 34.10 W, 5.96 4065.54S 3417.62W S 34.20 W 4.28 4091.31S 3435.11W S 35.70 W 5.14 4115.69S 3452.15W 5237.05 5271.29 5302.37 5333.49 5363.22 11898.91 9004.49 8923.35 89 39 11930.38 9004.67 8923.53 89 41 11961.66 9004.54 8923.40 90 48 11993.82 9003.98 8922.84 91 11 12025.34 9003.56 8922.42 90 18 12054.93 9003.52 8922.38 89 50 12085.23 9003.78 8922.64 89 10 12116.81 9004.17 8923.03 89 25 12148~32 9005.09 8923.95 87 13 12179.25 9007.01 8925.87 85 39 S 34.60 W 4.02 4141.98S 3470.66W S 36.30 W 5.40 4167.62S 3488.91W S 35.70 W 4.03 4192.92S 3507.29W S 35.60 W 1.28 4219.05S 3526.03W S 36.40 W 3.80 4244.55S 3544.56W S 34.80 W 5.63 4268.60S 3561.78W S 35.20 W 2.60 4293.42S 3579.16W S 34.30 W 2.96 4319.37S 3597.16W S 34.60 W 7.01 4345.33S 3614.97W S 35.70 W 6.19 4370.57S 3632.74W 5395.36 5426.82 5458.09 5490.24 5521.75 5551.34 5581.62 5613.18 5644.64 5675.50 12210.77 9009.61 8928.47 84 50 12242.02 9012.38 8931.24 85 0 12274.91 9015.14 8934.00 85 22 12304.62 9017.44 8936.30 85 43 12336.00 9019.63 8938.49 86 16 S 35.60 W 2.59 4396.10S 3651.05W S 35.90 W 1.07 4421.36S 3669.23W S 35.40 W 1.90 4447.99S 3688.34W S 34.40 W 3.55 4472.28S 3705.28W S 35.00 W 2.59 4498.02S 3723.10W 5706.90 5738.02 5770.79 5800.40 5831.68 12367.79 9021.65 8940.51 86 27 12399.58 9023.43 8942.29 87 5 12428.91 9024.88 8943.74 87 15 12460.23 9026.52 8945.38 86 44 12492.42 9028.28 8947.14 86 58 S 34.80 W .87 4524.04S 3741.25W S 33.50 W 4.55 4550.30S 3759.07W S 34.30 W 2.78 4574.62S 3775.41W S 34.90 W 2.53 4600.36S 3793.17W S 35.30 W 1.45 4626.66S 3811.65W 5863.39 5895.09 5924.35 5955.60 5987.73 12523.12 9029.75 8948.61 87 32 12554.65 9030.93 8949.79 88 10 12584.43 9031.69 8950.55 88 53 12616.18 9032.27 8951.13 89 0 12647.64 9032.92 8951.78 88 36 S 36.70 W 4.91 4651.46S 3829.67W S 36.60 W 2.05 4676.74S 3848.48W S 36.20 W 2.74 4700.70S 3866.15W S 35.80 W 1.32 4726.39S 3884.81W S 35.80 W 1.27 4751.90S 3903.20W 6018.39 6049.90 6079.67 6111.41 6142.86 S~-MRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai 500292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 MWD SURVEY JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12678.85 9033.78 8952.64 88 14 S 35.70 W 1.23 4777.22S 3921.43W 6174.05 12716.80 9035.05 8953.92 87 54 S 35.90 W 1.02 4807.98S 3943.62W 6211.97 12748.68 9036.54 8955.41 86 43 S 35.90 W 3.70 4833.77S 3962.29W 6243.81 12780.42 9039.20 8958.06 83 39 S 36.70 W 9.99 4859.26S 3981.01W 6275.44 12812.49 9043.64 8962.50 80 25 S 36.50 W 10.09 4884.75S 3999.95W 6307.19 12843.91 9049.75 8968.61 77 8 S 36.50 W 10.47 4909.53S 4018.28W 6338.01 12875.38 9057.59 8976.45 74 0 S 36.20 W 10.02 4934.07S 4036.34W 6368.48 12907.92 9067.48 8986.34 70 36 S 36.10 W 10.42 4959.10S 4054.62W 6399.48 12939.98 9078.95 8997.81 67 27 S 37.10 W 10.25 4983.13S 4072.47W 6429.41 12960.49 9087.15 9006.01 65 24 S 37.50 W 10.20 4998.08S 4083.86W 6448.21 13020.00 9114.70 9033.56 59 25 S 38.74 W 10.22 5039.57S 4116.39W 6500.91 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6507.06 FEET AT SOUTH 39 DEG. 14 MIN. WEST AT MD = 13020 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 216.75 DEG. TIE-IN SURVEY AT 8501.16' MD WINDOW POINT AT 8585.00' MD PROJECTED SURVEY AT 13020.00' MD SZ~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai ~00292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8501.16 7309.71 7228.57 1922.66 S 2483.68 W 9501.16 8115.90 8034.76 2425.77 S 2638.22 W 10501.16 8906.25 8825.11 2998.09 S 2680.21 W 11501.16 8981.81 8900.67 3816.32 S 3243.62 W 12501.16 9028.74 8947.60 4633.78 S 3816.69 W 1191.45 1385.26 193.81 1594.91 209.65 2519.35 924.44 3472.42 953.07 13020.00 9114.70 9033.56 5039.57 S 4116.39 W 3905.30 432.88 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S=qRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING INC. PRUDHOE BAY/A-16Ai 300292052101 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/21/96 DATE OF SURVEY: 072796 JOB NUMBER: AK-MW-60090 KELLY BUSHING ELEV. = 81.14 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 8501.16 7309.71 7228.57 1922.66 S 2483.68 W 1191.45 8603.77 7381.14 7300.00 1965.04 S 2543.93 W 1222.63 31.18 8736.10 7481.14 7400.00 2020.47 S 2610.23 W 1254.96 32.33 8858.23 7581.14 7500.00 2077.07 S 2650.95 W 1277.09 22.13 8978.28 7681.14 7600.00 2139.40 S 2673.36 W 1297.14 20.05 9098.48 7781.14 7700.00 2205.68 S 2678.13 W 1317.34 20.21 9218.99 7881.14 7800.00 2272.13 S 2668.12 W 1337.85 20.51 9339.37 7981.14 7900.00 2337.74 S 2654.45 W 1358.23 20.38 9459.49 8081.14 8000.00 2403.15 S 2642.20 W 1378.35 20.12 9578.72 8181.14 8100.00 2467.29 S 2632.24 W 1397.58 19.23 9696.73 8281.14 8200.00 2529.17 S 2622.35 W 1415.59 18.01 9814.10 8381.14 8300.00 2589.94 S 2613.27 W 1432.96 17.37 9931.20 8481.14 8400.00 2650.43 S 2606.10 W 1450.06 17.10 10048.79 8581.14 8500.00 2711.86 S 2598.91 W 1467.65 17.58 10167.06 8681.14 8600.00 2774.83 S 2595.24 W 1485.92 18.27 10294.97 8781.14 8700.00 2852.98 S 2608.48 W 1513.83 27.91 10449.64 8881.14 8800.00 2959.84 S 2656.70 W 1568.50 54.68 11490.84 8981.14 8900.00 3807.69 S 3238.01 W 2509.71 941.20 12945.49 9081.14 9000.00 4987.15 S 4075.53 W 3864.35 1354.64 13020.00 9114.70 9033.56 5039.57 S 4116.39 W 3905.30 40.95 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS HOWARD OKLAND Attn. A/~ASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 15 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION LDWG TAPE+LIS LDWG TAPE+LIS ECC No. Run # 1 6721.02 Run # 1 6733.01 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 563-7803 Received by: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AX<, 99501. Date: 5 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: 1 ZDL/CN FINAL BL 1 DAC FINAL BL+RF 1 BH PRO FINAL BL+RF 1 SSVD FINAL BL+RF Run ~ 1 Run # 1 Run # 1 Run # 1 Run ~ 1 ECC No. 6733.01 Please sign and return to: Attn. Rodney D.~Paulson~ Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Received bY: Date: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A_K, 99501. Date: 18 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL ~ DESCRIPTION 1 CN FINAL BL+RF 1 CCL FINAL BL+RF Run ~ 1 Ru/1 ~ 1 ~-O~ N-20 (33-8-11-13) 1 CN/GR FINAL BL+RF Run # 1 1 PDK FINAL BL+RF Run # 1 1 CN/GR FINAL BL+RF Run # 1 1 P. FO/PER'F ~FIN~'BL+RF-:. Run ~ 1 1 PLS FINAL BL'+RF''~ . Run ~ 1 1 CN/GR FINAL' BL+RF Run $ 1 1 PFC/PERF FINAL BL+RF 1 CCL FINAL BL+RF Run # 1 Run ~ 1 1 CCL FINAL BL+RF Run # 1 ECC No. 493 05 1531 05 2383 05 5651 04 5801 10 5806 07 6122 06 6224 01 6713 02 6733.00 Please sign and return to: Attn. Rodney D. Paulson Received by:~~ Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, A/< 99518 Or FAX to (907) 563-7803 Date: TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 8, 1996 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit A- 16Ai BP Exploration (Alaska) Inc. Permit No. 96-98 Sur Loc 3016'SNL, 1014'WEL, Sec. 35, TllN, R13E, UM Btmhole Loc 2546'NSL, 5133'WEL, Sec. 02, T10N, R13E, UM Dear Mr. Stoltz: Enclosed is the approved revised application for perm/t to drill the above referenced well. The provisions of the original approved permit dated May 22, 1996 are in effect for this revision. dlf/Enclosures cc: Department ofFish & Game, Habitat Section W/o encl Department of Environmental Conservation w/o encl STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Revised: 06/26/96 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil ila. Typeofwork i_lRe. Entry I-IDeepen~ []Service I-IDevelopment Gas CiSingle Zone f-I Multiple Zone 'r2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE - 80.73' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047472 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3016' SNL, 1014' WEL, SEC. 35, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 4354' NSL, 3782' WEL, SEC. 02, T10N, R13E A-16Ai At total depth 9. Approximate spud date Amount $200,000.00 2546' NSL, 5133' WEL, SEC. 02, T10N, R13E 07/13/96 i12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047471, 147'I No Close Approach 2560 14209' MD / 8931' TVD i16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 8600' Maximum Hole Angle 87.81 o Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig i18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 1959' 8445' 7269' 10404' 8856' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 2741' 10254' 8757' 12995' 9122' 405 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ~ ~ C E IV IF-. D Production Liner JU['I 6 1996 Nask~ 0il & G?,s Cons. C0mmissi0p. Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Pict [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: David Nakamura, 564-5606 Prepared By Name/Number Terrie Hubble, 564-4628 21. I hereby certify that/the~Iore , . correct to the best of my knowledge ~ Signed/ /~' Dan Stoltz/'~"~~.-¢~---~... Title Senior Drilling Engineer Date Commission Use Only Permit Number APl Number Approval Date I See cover letter 96-98 50-029-20521-01 05/22/96I for other requirements Conditions of Approval: Samples Required [] Yes ~No Mud Log Required [] Yes "~No Hydrogen Sulfide Measures ~j'Yes ~.~' No Directional Survey Required /~Yes [] No Required Working Pressure for BOPE [] 2M; []3M; ~_ SM; [] 10M; [] 15M Other: .",(jinal Signed By by order of Approved By "~,~¢;d ~^/ _ln½nefr~n Commissioner the commission Date-/,/, Form 10-401 Rev. 12-01-85 Triplicate I Well Name: J A-16Ai Redrili Plan Summary Type of Well (producer or injector): Gas (MI)Injector Surface Location: 3016' FNL 1014' FEL Sec 35 T11N R13E Start of Horizontal Location: 4354' FSL 3782' FEL Sec 02 T10N R13E End of Horizontal Location: 2546' FSL 5133' FEL Sec 02 T10N R13E I AFE Number: 14P0827 I I Ri,: I Nabors 18-E I Estimated Start Date: I July 13, 1996 I I Operating days to complete: I 30 IuD; 1~2995' I I TVD= 19122' I IRT-GL I KBE: Well Design (conventional, slimhole, etc.) 29.7' 80.73' High Angle Sidetrack Injector I I Objective: I High angle sidetrack to Zone Casin t/Tubing Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/I'VD MD/'rVD 8-1/2" 7" 26# L-80 BTC- 1959' 8445'/7269' 10404'/8856' MOD 6" 4-1/2" 12.6# L-80 BTC- 2741' 10254'/8757' 12995'/9122' MOD Tubing 4-1/2" 12.6# L-80 BTC- 10228' 26'/26' 10254'/8757' MOD Cement Calculations: I Liner Size: I 7" liner IBasis:I 1000' MD of cement above the Sag River with 50% open hole excess, 80' shoe joint, Total Cement Volume: I 180 I sxs of 15.8 ppg Class G Blend @ 1.15 ft3/sx No hydrocarbon zones identified above Sag River I Liner Size: I 4-1/2" liner IBasis:I 40% open hole excess, 80' shoe joint, 150' liner lap and 200' cement on top of liner Total Cement Volume: I 325 I sxs of 15.7 ppg Class G Blend @ 1.17 ft3/sx A-16Ai Revised Permit Information Page 1 Mud Program: Sidetrack drilling fluid will be used as a milling fluid. Special design I considerations 8-1/2" Sidetrack drilling fluid to Sag River Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8595' 9.8 40-50 10-12 4-8 6-10 9.0 <6 to 10404' 10.0 45-50 10-12 6-10 8-12 9.0 <6 Treat mud for Kingak shales with 2 ppb Baratrol, 2 ppb Boreplate and 2 - 4 ppb Baranex Keep HTHP filtration rate at less than 13 cc Special design I considerations New SHEARDRILn mud system will be used to drill 6" high angle interval Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 10404' 8.8-9.1 45-50 20-24 8-10 8-12 8.5 - 9.0 <6 to 12995' 8.8'9.1 45-50 20-24 8-10 8-12 8.5 - 9.0 <6 Directional: I Ko.: 18600, MD Maximum Hole Angle: Close Approach Well: 87.81° No Close Approach Wells Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Shared Services Drilling Contact: Contact David Nakamura at (907) 564-5606 to answer any questions concerning Permit to Drill. A-16Ai Revised Permit Information Page 2 Drilling Hazards: · Maximum anticipated BHP: · Maximum surface pressure: · Planned Completion Fluid: 3750 psi @ 8800' TVDss (8.2 ppg EMW) 2870 psi @ 8800' TVDss 8.5 ppg filtered sea water a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. The most recent H2S level on this well indicated no H2S. Even though no H2S has been detected, proper precautions will be taken as needed. d. Drilling Hazards: · This well is planned to avoid all mapped faults. However, if a fault is crossed in Sag River or Sadlerochit, history indicates faults are highly conductive. · Top of Sag River has a possible hard streak - may take time to kickoff in upper Sag River A-16Ai Revised Permit Information Page 3 A-16Ai Operations Summary Pre-Rig Operations 1. Pull the 7" SSSV. Valve is set at 2067' MD. Test the 9-5/8" mandrel packoff to 5000 psi. . Notify an AOGCC representatiVe prior to commencing plug-back operations. RU CT unit. RIH with coiled tubing to 10910' MD - 100' MD below the bottom perforation (bottom perforation at 10808' MD). Lay a cement plug from 10910' to 10200' MD. This will leave cement about 370' above the top perforation (top perforation at 10570' MD). . With an AOGCC representative on location to witness the operation, R/U slickline and tag the top of the cement. . . . . approximatelyRIH and cut the8845,7" L-80MD.tubing with a jet cutter in the middle of the first full joint ~)~°f tubinCL,_(..~ ,,., ~ ltv E D Displace the tubing and wellbore to 8.5 ppg seawater. JUN ?_ r~ ~995 Freeze protect top 2200' MD with diesel. Alaska Oil & c~.s ConS- Co!-nmission Bleed tubing and annuli pressures to zero. Anchora.~0 8. Set BPV in the tubing hanger and test from below to 1000 psi. Secure well. . Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Please provide total well preparation cost on the handover form. Rig Operations 1. MIRU drilling rig. . . Pull BPV. Circulate out freeze protection from inner and outer annuli and recover for future use. Test 9-5/8" mandrel packoff to 5000 psi. If pack-off fails, change out packoff in Step 5 prior to cutting the section. Install a TWC and test from below to 1000 psi. N/D the production tree. . N/U BOP. Test BOP to 250/5000 psi against TWC. Test annular preventer to 250/2500 psi. Remove TWC. Send adapter flange and tree to DSM for inspection and repair. . Pull and lay down the 7" tubing. (Tubing should be jet cut at 8845' MD. Check the location and exact depth of the cut on production handover form) Inspect for NORM. Label tubing as it is laid down with well name and joint number. Install thread protectors on pipe which upon visual inspection appears to be re-usable. If tubing is salvageable, send tubing to Tuboscpoe for inspection. If 9-5/8" mandrel packoff did not test in Step 2, pull and replace packoff through the BOP stack. . RIH with bridge plug. Set bridge plug at approximately 8800' MD (7" tubing should be cut at 8845' MD). 9. Shut-in well and test casing to 3500 psi for 30 minutes to ensure casing integrity. 10. P/U 9-5/8" section mill on 5" drill pipe. RIH to 8800'. Displace well to milling fluid. Spot 18 ppg mud pill from 8800' to the base of the section at 8645" MD. A-16Ai Revised Permit Information Page 4 11. 12. 13. 14. 18. 19. 20. 21. 22. 23. 24. 25. 26. Cut window from 8595" to 8645'. Keep flowrate between 600 - 700 gpm while milling casing. POOH after ensuring the hole is clean and free of metal cuttings. RIH open ended to 8800' MD and spot a kick-off plug from 100' below the base of the section to -200' above the top of the section (8395' MD). Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. POOH and function rams to clear cavities and test BOP's. RIH with 8-1/2" kickoff assembly. Dress the cement to 5' below the section top. Circulate hole clean. Kickoff and build to a final hole angle of 60° at the to Top Sag River (7" casing point). RIH with 7", 29#, L-80 liner with a 9-5/8" x 7" liner hanger/packer spaced out for a 150' lap. Cement the liner in place with the total cement volume based on 1000' MD above the Sag River with 50% excess in open hole and 80' shoe volume. Set liner hanger/packer. RIH with 6" steerable assembly (MWD/6R/Flesistivity). Clean out liner to float collar. Test liner and liner lap to 3500 psi. Finish cleaning out liner. Kickoff and directionally drill to Zone 4 building and turning at 12°/100'. Displace hole to new FIo-Pro system when kicked off and in new formation. Continue drilling 6" horizontal hole to TD. RIH with hole opener to TD of horizontal section. RIH with 4-1/2", 12.6#, L-80 solid liner 7" x 4-1/2" packer/hanger spaced out for a 150' lap. Cement liner in place with the total cement volume based on 40% excess in open hole, 150' lap, 80' shoe volume and 200' of cement on top of liner in 7" liner. Set liner hanger/packer. RIH with 3.75" cleanout assembly. Cleanout 4-1/2" liner to landing collar. Test liner to 3500 psi. Displace well to seawater. POOH. RIH with 2-3/4" drillpipe conveyed perf guns and perforate 4-1/2" liner. POOH and lay down guns. RIH with 4-1/2", 12.6#, L-80 completion with SSSV and 7"x 4-1/2" packer. Set TWC valve. Test to 1000 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull TWC valve. Freeze protect well. Set packer and test tubing to 40OO psi. Test tubing annulus to 4000 psi. Set BPV. Release rig. Complete appropriate documentation and handover to Production. A-16Ai Revised Permit Information Page 5 AnadrJ ]] Schlumberger A- 1CAi (P 13) In iector VERTICAL SECIION VIEW SHARED SERVZ'CES DRIL~ZN'G' i i i Sect ion at: 216.75 iTVo ............ ' ........ Scale- I inch = 400 feet ~ A 4ADRILL ~ AK~"DPC Ioep Sca]e 1 ~nch= 400 feet ~ ., i , APP ~OV D .................... IOrawn .... 06/24/96 "%. i FOR PE ~MITTIN' I ~,- .... '~:~, ..... -, , ...... ~-~ . .: , ........ :_..O~by: ..... , ........ ~~ - Marker Identification MD BKB SECTN INCLI , ~ ': =: B) TOP OF WINDOW 8595 7375 3099 45. "~ CI K0P / CURVE 8/~00 8600 7379 3~02 45.8: ~ F) 7" CASING PT ~0404 8856 39~7 56.7 ,,~ G) END CURVE lJ/~O0 10718 8951 4209 BT.B '~ ~' i H) BSL ~07~8 8951 4209 87.B I) INTERMEDIATE PT 12679 9026 6J68 87.8 ~ .... j ........ J) DROP 10/~00 ~2679 9026 6168 B7.B .... L) END DROP 10/~00 12974 9110 6447 58.3 i j M) TD 12995 9t22 6465 58.3 ' ~ ' 'T~'-~¢ ...... ~ ........... ;~ ; ,, , :~-~: .............. --. ............ : ,-~,~~- , -~ __. -- : ::::::::::::::::::::: ..... _ ....... :---~~ ~.~:~c:: ............................ v - .o~. ~ ........................... TZ3 9116 ....... JU~ ~.~99G ..., ................. Alask8 0il & Gas ;ohs. commission' I t _ , J ,Anc~ orage j 3OOO 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 Sect ion Departure {znaar~}] (c)96 A]CA¢]3 ).Ob.03 3:25 PM P) ju~-24-96 16:19 Anadrill DPC 90-7 344 2160 P.13_~ ii A-16Ai SHARED 'SERVICES ORILCING" i i ii il i i (P13) In) ector PLAN VIEW ,Ill I mi CLOSURE · 6472 ~eet at Azimuth 2~9.48 DECLINATION.' +28.350 SCALE ' ~ inch = 500 feet DRAWN ' 06/24/96 ~lnadr i ] ] Schlumberger Marker Identification MO N/S A) TIE-IN SURVEY 8501 1933 S 2483 8) Top D) END CURVE 8/100 E) CURVE F) 7" CASING PT 10404 2932 S 2621 G) END CURVE 11/100 10718 3188 S 2765 H) BSL 10718 3t88 S 2765 I) INTERMEDIATE PT t2679 4758 S 3~37 J} DROP 10/i00 12679 4758 S 3937 K) ESL 128i6 4866 S 4018 L) END DROP lO/tO0 12974 4982 S 4104 M) TD 12995 4996 S 4115 J J T ' . 1 ........ ...... ~---...--' .......................... ~ .... .r ~C,, . _... I .... L ~,~ [,',:,"1 - I ..... i .......... i ....... i i / .1 'Z~NADRILL '-..]-' ' i FQR PERMITTING ' i I C~NLY ...... !.. .............. ~ _. ~T.,e _ 5000 4750 4500 4250 4000 3750 3500 3250 3000 ~ 750 2500 2250 2000 1750 1500 <- NEST Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING 4ell ......... : A-16Ai (P13) Injector Field ........ : Prudhoe Bay, A-Pad ~omputation..: Minimum Curvature Jnits ........ : FEET Surface Lat..: 70.26327493 N Surface Long.: 148.75174060 W LOCATIONS - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 2262 FSL 1014 FEL S35 TllN R13E UM 654394 00 5947429.00 Tie-in Survey: 329 FSL 3499 FEL S35 TllN R13E UM 651951 35 5945446.00 BSL .......... : 4354 FSL 3782 FEL S02 T10N R13E UM 651695 00 5944185.00 INTERMEDIATE : 2783 FSL 4955 FEL S02 T10N R13E UM 650555 20 5942591.34 ESL .......... : 2676 FSL 5036 FEL S02 T10N R13E UM 650477 00 5942482.00 BHL .......... : 2546 FSL 5133 FEL S02 T10N R13E UM 650382 64 5942350.07 ANADRiLL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN # Prepared ..... : 06/24/96 Vert sect az.: 216.75 KB elevation.: 80.73 ft Magnetic Dcln: +28.350 (E) Scale Factor.: 0.99992708 Convergence..: +1.17495075 PROPOSED WELL PROFILE STATION IDENTIFICATION TIE-IN SURVEY TOP OF WINDOW KOP / CURVE 8/100 MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIMUTH TVD SUB-S DIST 8501 46.17 8595 45.85 8600 45.83 8700 40.60 8800 36.19 COORDINATES-FROM STATE-PLANE TOOL DL/ WELLHEAD X Y FACE 100 234.69 7310 7229 3034 1932.64 S 2482.98 W 651951.35 5945446.00 128R <TIE 235.26 7375 7295 3099 1971.56 S 2538.50 W 651896.64 5945405.95 128R 0.55 235.29 7379 7298 3102 1973.60 S 2541.45 W 651893.73 5945403.85 134L 0.55 226.43 7452 7371 3168 2016.52 S 2594.60 W 651841.49 5945359.85 128L 8.00 215.65 7530 7450 3230 2063.01 S 2635.45 W 651801.60 5945312.53 l19L 8.00 HRZ , LCU 8828 35.17 8900 32.96 9000 31.27 9100 31.37 9103 31.40 212.30 7553 7472 3246 2076.34 S 2644.44 W 651792.88 5945299.02 l16L 8.00 202.73 7613 7532 3286 2112.17 S 2663.21 W 651774.85 5945262.82 108L 8.00 187.99 7698 7617 3335 2163.04 S 2677.35 W 651761.76 5945211.67 96L 8.00 172.56 7783 7702 3377 2214.64 S 2677.59 W 651762.58 ~945160.09 83L 8.00 ~~. i~~ 7705 3378 2216.18 S 2677.38 W 651762.82 5945158.55 82L 8.00 (Anadrill (c)96 A16AP13 3.0b.03 3:22 PM P) JUN 6 996 Alaska Oil & ~as Cons. Commission Anchorage > 0 k-16Ai (P13) Injector STATION IDENTIFICATION TOP KINGAK END CURVE 8/100 TJD CURVE 11/100 TJB TSGR 7" CASING PT TSHU ENID CURVE 11/100 BSL TSAD / TZ4B COWC 44N INTERMEDIATE PT DROP 10/100 ESL HOT HOT (ESL) OOWC MEAS DEPTH 9103 .~114 ~8:56 15111 15166 1~2 0 0 1(~3 0 0 1~3 9 5 1~4 0 0 10~4 0 4 15435 1~500 1,~600 l J!700 1~.718 1~1718 1~:718 11503 12339 12679 12679 12700 12800 12816 12835 12845 12900 12914 INCLN ANGLE 31.40 31.53 31.53 31.53 35.58 38.30 47.01 55.90 56.37 56.76 59.69 66.08 75.98 85,97 87.81 87.81 87.81 87,81 87.81 87.81 87.81 85.73 75.73 74.16 72.20 71.25 65.73 64.36 (Anadrill (c)96 AI6AP13 3.0b.03 3:22 PM P) DIRECTION AZIMUTH PROPOSED WELL PROFILE VERT-DEPTHS SECT TVD SUB-S DIST 172.11 7786 7705 3378 170.41 7795 7715 3382 170.41 8428 8347 3650 170.41 8645 8564 3742 178.64 8691 8610 3764 182.91 8718 8637 3781 192.87 8791 8711 3840 199.95 8851 8770 3910 200.27 8853 8773 3914 200.54 8856 8775 3917 202.44 8872 8791 3942 206.19 8902 8821 3999 211.27 8934 8853 4092 215,92 8950 8869 4191 216.75 8951 8870 4209 216.75 8951 8870 4209 216.75 8951 8870 4209 216.75 8981 8900 4993 216.75 9013 8932 5829 216.75 9026 8945 6168 216.75 9026 8945 6168 216.75 9027 8946 6189 216.75 9043 8962 6288 216.75 9047 8966 6303 216.75 9053 8972 6322 216.75 9056 8975 6331 216.75 9076 8995 6382 216.75 9082 9001 6394 RECEIVED Alaska Oil & Gas Cons. Commission Apr, horn~e COORDINATES-FROM WELLHEAD 2216.18 S 2677,38 W 2221.97 S 2676.49 W 2604.58 S 2611.82 W 2735.80 S 2589.64 W 2766.16 S 2586.84 W 2786,60 S 2587.14 W 2853,41 S 2596.89 W 2924.54 S 2618.14 W 2928,.35 S 2619.53 W 2931.58 S 2620.74 W 2955.61 S 2630.21 W 3008~66 S 2654.24 W 3091.39 S 2699.73 W 3173.50 S 2754.33 W 3188.20 S 2765.15 W 3188.21 S 2765.15 W 3188.21 S 2765.15 W 3816.24 S 3234.08 W 4486.13 S 3734.27 W 4758.28 S 3937.48 W 4758.29 S 3937.48 W 4774.94 S 3949.91 W 4853.92 S 4008.88 W 4866.00 S 4017.91 W 4881.04 S 4029.14 W 4888.32 S 4034.57 W 4929.46 S 4065.29 4939.38 S 4072.70 06/24/96 Page 2 STATE-PLANE X Y 651762.82 5945158.55 651763.82 5945152.78 651836.32 5944771.61 651861.19 5944640.88 651864.61 5944610.58 651864.73 5944590.15 651856.35 5944523.15 651836.57 5944451.61 651835,25 5944447.77 651834,11 5944444.52 651825,14 5944420.30 651802.20 5944366.77 651758.42 5944283.13 651705.51 5944199.93 651695.01 5944185,01 651695.00 5944185.00 651695.00 5944185.00 651239.08 5943547.54 650752.77 5942867.57 650555.20 5942591.34 650555.19 5942591.33 650543.11 5942574.43 650485.77 5942494.27 650477.00 5942482.00 650466.08 5942466.73 650460.80 5942459.34 TOOL DL/ FACE 100 82L 8.00 8.00 0.00 52R 0.00 45R 11.00 42R 11.00 34R 11.00 30R 11.00 30R 11.00 29R 11.00 28R 11,00 27R 11.00 25R 11.00 24R 11,00 11,00 11.00 11.00 0.00 0.00 LS 0.00 LS 10.00 LS 10.00 LS 10.00 LS 10.00 LS 10.00 LS 10.00 6c, r~4--Ro 93 5942417.59 A~;~-D~.' b FOR PERMITTING ONLY PLAN A-16Ai (P13) Injector STATION MEAS INCLN IDENTIFICATION DEPTH ANGLE END DROP 10/100 12974 58.36 TZ3 12984 58.36 TD 12995 58.36 PROPOSED WELL PROFILE DIRECTION VERT-DEPTHS AZIMUTH TVD SUB-S 216.75 9110 9030 216.75 9116 9035 216.75 9122 9041 SECT COORDINATES-FROM DIST WELLHEAD ---- __ 6447 4981.53 S 4104.17 W 6456 4988.39 S 4109.29 W 6465 4995.98 S 4114.96 W 06/24/96 Page 3 STATE-PLANE TOOL X Y FACE 650393.13 5942364.74 650388.15 5942357.77 650382.64 5942350.07 DL/ 100 10.00 0.00 0.00 (knadrill {c)96 A16AP13 3.0b.03 3:22 PM P) ANADRILL AKA-DPC APPROVED FOR PEI~MITTING ONLY PLAN .~ I~ ~" z~ COMPANY ~)~ ?? GEoL AREA PROGRAM: exp [] dev [] red~'/se~well~re seg .-i ann. disposal pa-a req "": UNIT# ;2"/__.._~.~_~;"'4~ ' ON/OFF SHORE ENGINEERING 1. 2. 3. 4. 5. 7. a. 9. 10. 11. 12. 13. /'~ REMARKS Permit fee attached ........................ ..,Y. ~ .~,; / ,/ ~ Lease number appropdate ................... /Y1 N /¢~'/.._~-. d'"',~,,,~,,c_¢:> /'Of Welt located in a defined pool ................. N ,.~,,,/gT~~ /._F '~-"-~ 'Z~X~/'~ ~ C~ Weii ,ocated proper distance from other wells ........ _,~.. ,-~,, ~ __.- .~.~)~.~. Su~cient acrea.de available in drilling unit .......... N N N i.'y N If Ceviatea, is wellbore plat included .............. Operator only affected party .................. Operator has appropriate bond in force ............ Permit can be issued without conservation order ...... Permit can be issued without administrative approval... Can permit be approved before 15-day wait. ........ APPR D,~,,TE 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor sb'ing provided ................... Y N "~ Surface casing protects all known USDWs .......... Y N CMT vol adequate to circulate on conductor & surf csg .... Y N ,j CMl' vol adequate to tie-in long s~'ing to surf csg ....... Y N CMT will cover all known productive hodzons ......... ( ~' N Casing designs adequate for C, T, B & permafrost. ..... '.N Adequate tankage or reserve pit ................ ( N If a re-drill, has a 10-4.03 for abndnmnt been approved .... ~;N Adequate wellbore separation proposed ............ I N If diverter required, is it adequate ................ '~ "N- "~ Ddlling fluid program schematic & equip list adequate .... .~ ~' N BOPEs adequate ........................ ~. BOPE press rating adequate; test to ~sig. ~ Choke manifold complies w/APl RP-53 (May 84) ....... 'q Work will occur without operation shutdown .......... ~ Is presence of H2S gas probable ............... (~ GEOLOGY ¢' 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N /// ,/ ~ 31. Da~ presented on potential ove ,rpressure zones ....... Y J~ ,,~//, 32. Seismic analysis of shallow gas zones ............. __~N . ,.., ,. ,, 4 33. sea,.~ed condition survey (if off-shore) ........... .~.Y N 34. Comact name/phone for weekl~ progress reports .... /.. Y N lex~oratory on/y] ,/ GEOL~_GY: ENGINEERING: COMMISSION: BEW /,/ rDW JDH ~ JDN TAB.-3t'?~:T ...... Comments/instructions: HOWAb- A:~FC'RMS~ch~kI~ rev 4.~6 . ,--,~' .*,:-;~:;-..~ r-'~:,'-7' ".~" '-:'.': ' ~. '" :-~ ;C~'. .... TONYKNOWLES, GOVERNOR ..' . PHONE: (~07) 279-~433 , =:'/. ¢cn:~ 275-7542 .... ~, ,, . . , May 22; ·1996 _Dan Stoltz, Senior Drilling E_ngin¢..er. . BP Exploration (Alaska) Inc. P O Box 196612 Anchorage; AK 99519-6612 Re: ' Prudh°e Bay Unit A-16Ai -- BP Exploration (,'Ata-sk~):--Ih¢:".;; :: .. .... ;;-.-: ::::-::---:. O :-,:::5'!!,.:::; ,;,?-i:i .- 'Permit NO': 96-'98:'::':'".' "': '" ':"- '''~ ' .... -: ;'< ?"i" ..... . ' ' . - Sur. Loc 3016'SNL, i014'WEL, Sec, 35,'T1 iN, R13E, UM Btmhole Loc. 2945'·NSL, 4146'WEL, Sec.'02, T10N, R13E. 'UM Dear Mr. Stoltz: __- Enclosed i{ _the _apprOVed application' for~¢m!it tO'redrill the above referenced ,,'ell.- _ - - -- --- ~- ' -" '.:-- :- ?'--:: :':' '":x'":;x:!')%='::-:<~::'-:_-_.'~i~ -._ · -- · "~-. The p-e~it~fq-~g~!l_d-~ ~Ot~;~ NT~tobm~~ionat ~emts 7e~¢ired by. law from -. '- = "'-o~er-go{e~~~g}ncies~ ad:dob~-do[a~bm~ndUfiimg ~Ng operado~ ~{iI ~l'oaer- - required pe~a~g detonations fire made. ~ c--'--'" \ "--L~ David W. J~ston ~ "~ Chalmlan ~ - The blowout prevention equipment (BOPE) must be tested in accordance wihh 20 AAC 25.0_35: and the mechanical integrity. (MI) of the injection wells must be demonstrated under 20 ,~C 25.412 and 20 25.030(g)(3). SuffiCient notice (approxknately 24 hours) of the MI test before operation,, and of the BOPE test performed before drilling below the surface c~ing shoe, must be given so that a reprbsentative of the Commission ma3' vdtness the tests. Notice ma',,' be given by contacting the Commission petroleum field inspector On Ce North Slope pager at 659-3607. '":':"- ' "' '---:-' "~ -~--:i:.:!:._"--:,: : ' ' : ' BY ORDER OF THE COMMISSION _ dlf/Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill 1 lb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] DeepenI [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator !5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 80.73' Prudhoe Bay Field / Prudhoe 3. Address i6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 CADL 047472 4. Location of well at surface !7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3016' SNL, 1014' WEL, SEC. 35, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 5253' NSL, 5036' WEL, SEC. 02, T10N, R13E A-16Ai Attotal depth 9. Approximate spud date Amount $200,000.00 2945' NSL, 4146' WEL, SEC. 02, T10N, R13E 05/22/96 i12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047471, 1134'I No Close Approach 2560 14209' MD / 8931' TVD i16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 8595' Maximum Hole Angle 86.44° Maximum surface 3300 psig, Attotal depth (TVD) 8800' / 4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 2103' 8445' 7269' 10548' 8871' 185 sx Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 3811' 10398' 8783' 14209' 8931' 405 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate R E C E IV E D Production Liner MAY 2 0 1996 Alaska 0ii & Gas Cons. Commission Perforation depth: measured Ancllorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: David Nakamura, 564-5606 Prepared By Name/Number Terrie Hubble, 564-4628 ,21. l hereby certify that,t~fo~going is t~d,c_cr!ect to the best of my knowledge ~ '[~/'~, Signed DanStoltz .("L~-~'~.~ ,..,~~.t~¢' Title Senior Drilling Engineer Date ...5-¢ Zd:~-q~ -' '~'/ - Commission Use Only Permit Number I APl Number I¢'-AIproval D_~ate I See c°ver letter- _ C~(~_C/,~ 50-0,~.¢/..-205",¢.,i-01 ..~ ,.,,).._). )(/~ for other requirements Mud Log Re~luired 'E3 Yes ~ No Conditions of Approval: Samples Required [] Yes I~L No . Hydrogen Sulfide Measures .~fY..es [] No Directional Survey Required J~ Yes [] No RequiredWorkir~a~r~nl~)F~ []2M; I-ISM; ~[.5M; []10M; []15M Other: David W. Johnston by order of j Approved By Commissioner the commission Date ,D ~ ~[~/),~ Form 10-401 Rev. 12-01-85 licate I Well Name: I A-16Ai Redrill Plan Summary Type of Well (producer or injector): I Gas (MI) Injector Surface Location: 3016' FNL 1014' FEL Sec 35 T11N R13E Start of Horizontal Location: 5253' FSL 5036' FEL Sec 02 T10N R13E End of Horizontal Location: 2945' FSL 4146' FEL Sec 02 T10N R13E I AFE Number: 14P0827 I I Rig: I Nabors 18-E Estimated Start Date: I May 22, 1996 I I Operating days to complete: J 30 uD: 1~42°9' I I TVD' 1893~' I IRT-GL I KBE: 29.7' 80.73' I I Well Design (conventional, slimhole, etc.) I High Angle Sidetrack Injector Objective: I High angle sidetrack to Zone Casin¢lfTubinq Proqram: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8-1/2" 7" 26# L-80 BTC- 2103' 8445'/7269' 10548'/8871' MOD 6" 4-1/2" 12.6# L-80 BTC- 3811' 10398'/8783' 14209'/8931' MOD Tubing 3-1/2" 9.2# L-80 TDS 10272' 26'/26' 10298'/8713' Cement Calculations: I Liner Size: I 7" liner IBasis:I 1000' MD of cement above the Sag River with 50% open hole excess, 80' shoe joint, Total Cement Volume: I 185 1 sxs of 15.8 ppg Class G Blend @ 1.15 ft3/sx No hydrocarbon zones identified above Sag River I Liner Size: I 4-1/2" liner IBasis:I 30% open hole excess, 80' shoe joint and 150' liner lap Total Cement Volume: I 405 1 sxs of 15.7 ppg Class G Blend @ 1.17 ft3/sx RECEIVED A-16Ai Permit Information Page 1 Mud Program: Sidetrack drilling fluid will be used as a milling fluid. Special design' I ' considerationsI 8-1/2" Sidetrack drilling fluid to Sag River Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~lel gel Loss 8595' 9.8 40-50 10-12 4-8 6-10 9.0 <6 to 10548' 10.0 45-50 10-12 6-10 8-12 9.0 <6 Treat mud for Kingak shales with 2 ppb Baratrol, 2 ppb Boreplate and 2 - 4 ppb Baranex Keep HTHP filtration rate at less than 13 cc Special design I considerations New FIo-Pro mud system will be used to drill 6" high angle interval Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel ~lel Loss 10548' 9.0-9.2 50-60 30-40 15-20 18-24 8.5 - 9.0 <6 to 41209' 9.0-9.2 50-60 30-40 15-20 18-24 8.5 - 9.0 <6 Directional: I KOP: I 8595'MD Maximum Hole Angle: Close Approach Well: I6.440 No Close Approach Wells Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Shared Services Drilling Contact: Contact David Nakamura at (907) 564-5606 to answer any questions concerning Permit to Drill. A-16Ai Permit Information Page 2 Drilling Hazards: · Maximum anticipated BHP: · Maximum surface pressure: · Planned Completion Fluid: 3750 psi @ 8800' TVDss (8.2 ppg EMW) 2870 psi @ 8800' TVDss 8.5 ppg filtered sea water a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/fi). c. The most recent H2S level on this well indicated no H2S. Even though no H2S has been detected, proper precautions will be taken as needed. d. Drilling Hazards: · This well is planned to avoid all mapped faults. However, if a fault is crossed in Sag River or Sadlerochit, history indicates faults are highly conductive. · Top of Sag River has a possible hard streak - may take time to kickoff in upper Sag River A-16Ai Permit Information Page 3 A-16Ai Operations Summary Pre-Riq Operations 1. Pull the 7" SSSV. Valve is set at 2067' MD. Test the 9-5/8" mandrel packoff to 5000 psi. Notify an AOGCC representative prior to commencing plug-back operations. RU CT unit. RIH with coiled tubing to 10910' MD - 100' MD below the bottom perforation (bottom perforation at 10808' MD). Lay a cement plug from 10910' to 10200' MD. This will leave cement about 370' above the top perforation (top perforation at 10570' MD). With an AOGCC representative on location to witness the operation, R/U slickline and tag the top of the cement. RIH and cut the 7" L-80 tubing with a jet cutter in the middle of the first full joint of tubing at approximately 8845' MD. Displace the tubing and wellbore to 8.5 ppg seawater. Freeze protect top 2200' MD with diesel. Bleed tubing and annuli pressures to zero. Set BPV in the tubing hanger and test from below to 1000 psi. Secure well. Remove the well house and flowlines. If necessary, level the pad and dig out the cellar. Please provide total well preparation cost on the handover form. Rig Operations MIRU drilling rig. Pull BPV. Circulate out freeze protection from inner and outer annuli and recover for future use. Test 9-5/8" mandrel packoff to 5000 psi. If pack-off fails, change out packoff in Step 5 prior to cutting the section. Install a TWC and test from below to 1000 psi. N/D the production tree. N/U BOP. Test BOP to 250/5000 psi against TWC. Test annular preventer to 250/2500 psi. Remove 'I'WC. Send adapter flange and tree to DSM for inspection and repair. Pull and lay down the 7" tubing. (Tubing should be jet cut at 8845' MD. Check the location and exact depth of the cut on production handover form) Inspect for NORM. Label tubing as it is laid down with well name and joint number. Install thread protectors on pipe which upon visual inspection appears to be re-usable. If tubing is salvageable, send tubing to Tuboscpoe for inspection. If 9-5/8" mandrel packoff did not test in Step 2, pull and replace packoff through the BOP stack. RIH with bridge plug. Set bridge plug at approximately 8800' MD (7" tubing should be cut at 8845' MD). Shut-in well and test casing to 3500 psi for 30 minutes to ensure casing integrity. P/U 9-5/8" section mill on 5" drill pipe. RIH to 8800'. Displace well to milling fluid. Spot 18 ppg mud pill from 8800' to the base of the section at 8645" MD. . . . , o . , . , , . . , A-16Ai Permit Information Page 4 11. 12. 13. 14. 18. 19. 20. 21. 22. 23. 24. 25. 26. Cut window from 8595" to 8645'. Keep flowrate between 600 - 700 gpm while milling casing. POOH after ensuring the hole is clean and free of metal cuttings. RIH open ended to 8800' MD and spot a kick-off plug from 100' below the base of the section to -200' above the top of the section (8395' MD). Pull 12 stands, shut in and perform hesitation squeeze. Attempt to achieve a 1000-2000 psi squeeze but do not displace TOC below 100' above section top. POOH and function rams to clear cavities and test BOP's. RIH with 8-1/2" kickoff assembly. Dress the cement to 5' below the section top. Circulate hole clean. Kickoff and build to a final hole angle of 60° at the to Top Sag River (7" casing point). RIH with 7", 29#, L-80 liner with a 9-5/8" x 7" liner hanger/packer spaced out for a 150' lap. Cement the liner in place with the total cement volume based on 1000' MD above the Sag River with 50% excess in open hole and 80' shoe volume. Set liner hanger/packer. RIH with 6" steerable assembly (MWD/GP,/Resistivity). Clean out liner to float collar. Test liner and liner lap to 3500 psi. Finish cleaning out liner. Kickoff and directionally drill to Zone 4 building and turning at 12°/100'. Displace hole to new FIo-Pro system when kicked off and in new formation. Continue drilling 6" horizontal hole to TD. RIH with hole opener to TD of horizontal section. RIH with 4-1/2", 12.6#, L-80 solid liner 7"x 4-1/2" packer/hanger spaced out for a 150' lap. Cement liner in place with the total cement volume based on 30% excess in open hole, 150' lap and 80' shoe volume. Set liner hanger/packer. RIH with 3.75" cleanout assembly. Cleanout 4-1/2" liner to landing collar. Test liner to 3500 psi. Displace well to seawater. POOH. RIH with 2-3/4" drillpipe conveyed perf guns and perforate 4-1/2" liner. POOH and lay down guns. RIH with 4-1/2", 12.6#, L-80 completion with SSSV and 7" x 4-1/2" packer. Set TWC valve. Test to 1000 psi. ND BOPs. NU tubing head adapter and tree. Test same to 5000 psi. Pull TWC valve. Freeze protect well. Set packer and test tubing to 4000 psi. Test tubing annulus to 4000 psi. Set BPV. Release rig. Complete appropriate documentation and handover to Production. A-16Ai Permit Information Page 5 May-lO-96 09:49 Anadrill DPC 907,_344 2160 P.13 i ii · i iiiii ii Iniector VIEW A- 6A (P5) PLAN 5561 feet at Azimuth 214.23 +28.383 (E) ! inch = 400 feet 05/09/96 CLOSURE ' DECLINATION ' SCALE. ' DRAWN. ' Aha#ri 1] Schlumberger Harken Identification A) TIE-IN ~RVEY B) TOP OF WINDOW C) KDP / C~VE g/lO0 O) END CURVE g/lO0 E) CURVE 9/100 F) 7' CASING Pl' G) END CURVE g/too H) TARGET t I) CURVE 12/100 J) TARGET 2 K) END CURVE 12/t00 [) CURVE t2/iO0 END CURVE 12/t00 N) TAR6ET 3 O) TAROT 4 P) 4-1/2' CASINO PT HD N/S E/N 8595 ]972 2539 8600 ,974 SS 254, WW BBB2 2029 27,3 10198 2004S 3514N t0548 2076 5 3758 W 10907 2289 S 4020 i0~7 2289 S 4020 117i2 21)05 S 4559 ~1712 2886 S 4559 125i9 3595 S 441)0 13338 4069 S 3B12 i3383 4095 S 3776 13383 4095 S 3776 14025 4486 S 3272 t4209 4598 S 3i28 (~ade))] (c)g6 Ai6Ag5 3.0b.03 3:5t ~ P) 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 <- WEST S'HARED SE'RV' CES DRILLING' ii i i~ iiiii iiiiiii1! ii iii ii i Ariadne] i. Sch]umben#er ii ii i i ii i! ! A-16A (p5) In)ector VERTICAL SECTION VIE~ Section at: 222. IOep Scale.: ] inch = 400 feet ~ API>RO~ ED ora.......: 05/09/96 FC~R PI RM.I rTih~G ,__ , ()ND' ~ Harker Identilication ,D 8KB SECTN INCL ~ ' ' - - BI TOP OF WIDOW 8595 7375 3~65 45 E __ [ ~ '- ...................... ......... C) KOP / ~VE 9/~00 8500 7379 3~6~ ~ D) E~ CURVE 9/100 8882 7592 3325 37.~ ~ E) CURVE 9/100 ~0198 8637 3843 37 ~ Fl 7' CASING PT 10548 887t 4060 59.~ : .... ~. - Ol END CURVE 9/100 10907 8976 4394 86.~ ~ H) TARGET I 10907 8976 4394 86.~ ~ I1 CURVE i2/t00 il7l~ 90~6 5t98 86. ~ J) TARGET Z 11712 9026 5198 ' ~ K) E~ CURVE ~2/~00 ~5~9 9045 567t 9~.t ~ ~ [I C~[ ~/100 ~33~8 ~8~ 5575 ~. ~ HI END C~VE ]2/100 13383 90~1 5570 . ~, N) TARGET 3 13383 9021 5570 96.; · O) TARGET 4 ~aO~5 B95~ 55~2 ~.[ h~' ~%~ .......... x~, P) 4-1/~' CASING PT 14209 8931 5508 ~'~ ........... r .......... ~ ..................... D) TD 1~00 B93~ 5508 ~.~ ~ .... ~ ...... 2~ ............... , ., ~. ~ L . _ ~ ~::~: ~ ~.~ ................... ............ Sect ion Departure [in&dri{] (c)96 AI6AP5 3.0~.03 3:56 PN P) , i ~O O1 0 ~O 0 .... SHARED SERVICES" '¢RILLIN6 ................... Anadri]]-SCh]u¢¢erger i i iiiiii i i i i ii i _ . A-16A (PS) In jectop I' AN~-DRILi AKA-DPC VERTICAL SECTION VIEW i ,__ APPROVED sectson .t: ' FI)R P !RM. ITTI IG ,! TVD Scale.: ~ ~nctl = 400 feet )NL", ~- Oep Scale.: ~ ~nch = 400 feel "- PLAN~~, = ' , ~Orawn .....,: 05/09/96 ~,- . ....... " ......... Marker Identification HO BKB SECTN INCL / A) TIE-IN SURVEY 8501 7310 -778 46. B) lOP OF WINDOW 8595 7375 -798 45.B ~-- j ~ C] KOP / CURVE 9/tO0 8600 7379 -799 45.8 [ [ D} END C~VE 9/100 8882 7592 -90~ 37.5 [ El CURVE 9/100 10198 8637 -~550 37.5 / F) 7" C~SIN~ PT ~0548 8871 -1699 59.4 .. ., ~ 6] END CURVE 9/~00 10907 8976 -1775 86.1 ' H) TARGET t 10907 8976 -~775 86.4 l) CURVE 12/t00 11712 90~6 -1835 86.~ [ J) TARGET 2 lt7~ ~26 -$835 86.~ ' ...... [ " K} END CURVE 12/100 12519 9045 -1338 91.~ [ L) CURVE 12/100 ~3338 9024 -520 [ M} END CffiVE 12/t00 13383 90~$ -475 96.~ ~ N) TARGET 3 13383 9021 -475 96.~ "- - .... ~, .... O) TARGET 4 ~4025 895~ ~63 ~.~ 3~' ~ ....... [ P) 4-t/2" CASING PT 14209 Bg3t 345 g6.~ 2~'~ ~ ..... gl TO 14209 8931 345 ~- ~nr ~ , / , :t~ a ~,: ....... :: ~ :' -' J. -~ ..... . ./ _;-~_ .... f I , ~ I ~ ..... ~ ....... ! .... -2400 )0 -2000 -3800 -1600 -]400 -i200 -I000 -800 -600 -400 -200 0 200 400 600 800 lO00 1200 (Ana~tll (cJCj6 At6.~5 3.0D.03 ~. 47 I~ P) Sect ion Departure i iii i iii :3 0 4~ rg 0 Anadrill Schlumberger Alaska District 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 344-2160 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILL~-NG' ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY PLAN Well ......... : A-16A (PS) Injector Field ........ : Prudhoe Bay, A-Pad Computation,,: Minimum Curvature Units ........ : FEET F Cace Lat..: 70.26327794 N & zace Long.: 148.75174026 W LOCATIoNs - ALASKA Zone: 4 Legal Description X-Coord Y-Coord Surface ...... : 2264 FSL 1014 FEL S35 TllN R13E UM 654394,02 5947430.10 Tie-in Survey: 330 FSL 3499 FEL S35 TllN R13E UM 651951.37 5945447,10 TARGET 1 ..... : 5253 FSL 5036 FEL S02 T10N R13E UM 650422.00 5945059.00 TARGET 2 ..... : 4657 FSL 295 FEL S03 T10N R13E UM 649895.50 5944451.90 TARGET 3 ..... : 3448 FSL 4794 FEL S02 T10N R13E UM 650702.70 5943258.60 TARGET 4 ..... : 3057 FS5 4290 F~L S02 T10N R13E UM 651215.00 5942878,00 BHL .......... : 2945 FSL 4146 FEL S02 T10N R13E UM 651361.37 5942769.26 Prepared ..... : 05/09/96 Vert sect az.: 222..11 KB elevation.: 80.73 ft Magnetic Dcln: +28,383 (E) Scale Factor.: 0,99992708 . Convergence..: +1.17495110 PROPOSED WELL PROFILE STATION IDENTIFICATION TI~-£N SURVEY TOP OF WINDOW KoP / cuRv 9/lOO MEAS INCLN DIRECTION VERT-DEPTHS SECT DEPTH ANGLE AZIMUTH TVD SUB- S DIST 8501 46.17 8595 45.85 8600 45.83 8700 41.58 8800 38.67 COORDINATES-FROM STATE-PLANE TOOL DL/ WELLHEAD X Y FACE 100 234.69 7310 7229 3099 1932.64 S 2482.98 W 651951.37 5945447.10 128R <TIE 235.26 7375 7295 3165 1971.56 S 2538.50 W 651896.66 5945407.05 128R 0.55 235.29 7379 7298 3168 1973.60 S 2541.45 W 651893.75 5945404.95 122R 0.55 246.79 7451 7371 3234 2007.17 S 2601.56 W 651834.35 5945370.15 114R 9.00 260.02 7528 7447 3288 2025.70 S 2662.95 W 651773.36 5945350.37 104R 9.00 ccevz 9/i0o TJD TJA CURVE 9/100 8882 37.50 9957 37.50 10109 37.50 10198 37.50 271,83 7592 7512 3325 2029.34 S 2713.08 W 651723.32 5945345.71 9.00 271.83 8446 8365 3748 2008.48 S 3367.49 W 651068.66 5945353.14 0.00 271.83 8566 8485 3808 2005.55 S 3459.52 W 650976.60 5945354.19 0.00 271.83 8637 8556 3843 2003,81 S 3514.18 W 650921.93 5945354.81 58L 0.00 (Anadrill (c)96 A16AP5 3.0b.03 3:54 PM P) A-16A (P5) Injector 05/09/96 Page 2 PROPOSED WELL PROFILE STATION MEAS INCLN DIRECTION VERT-DEPTHS SECT IDENTIFICATION DEPT~ ANGLE AZIMUTH 10200 37.57 OGOC 10222 38.67 TJB 10295 42.62 10300 42.93 10400 49.18 COORDINATEs-FROM STATE-PI2~NE TOOL DL/ TVD SUB-S DIST WELLHEAD X Y FACE 100 271.63 8638 8557 3844 2003.78 S 3515.12 W 650920.98 5945354.82 58L 9.00 268,91 8656 8575 3853 2003.72 S 3528.85 W 650907.25 5945354.60 56L 9.00 260.94 8711 8630 3887 2008.01 S 3575.76 W 650860.45 5945349.34 50L 9.00 260.41 8715 8634 3890 2008.60 S 3579.31 W 650856,91 5945348.69 49L 9.00 251.38 8784 8703 3950 2026.38 S 3648,89 W 650787.71 5945329.48 43L 9.00 ~. SAG RIVER 7" CASING PT TOP SHUBLIK 10500 56. O0 10529 58.07 10548 59.45 10569 60.91 10600 63.20 243.98 8845 8764 4022 2056.71 S 3722.15 W 650715.10 5945297.66 39L 9.00 242.05 8861 8780 4045 2067.83 S 3743.99 W 650693.49 5945286.09 38L 9.00 240.82 8871 8790 4060 2075.72 S 3758.47 W 650679.18 5945277.91 37L 9.00 239.58 8881 8800 4077 2084.39 S 3773.60 W 650664.22 5945268.93 36L 9.00 237.71 8895 8815 4103 2098.82 S 3797.28 W 650640.85 5945254.02 35L 9.00 END AVE 9/100 TARGET 1 10700 70.64 10800 78.23 10900 85.91 10907 8-6.44 10907 86.44 232.20 8935 8854 4193 2151.68 S 3872.43 W 650566.80 5945199.63 33L 9.00 227.18 8961 8881 4288 2213.99 S 3945.76 W 650494.77 5945135.83 32L 9.00 222.43 8975 8895 4387 2284.22 S 4015.46 W 650426.54 5945064.20 31L 9.00 222.11 8976 8895 4394 2289.32 S 4020.10 W 650422.00 5945059.00 9.00 222.11 8976 8895 4394 2289~32 S 4020.10 W 650422.00 5945059.00 9.00 ~0 0 ee POWC 10987 86.44 CURVE 12/100 11712 86.44 TARGET 2 11712 86.44 ~-- 11800 86.70 ~ 11900 87.13 ~ ~,* ~ 12000 87.68 ~' ~ -< ('~ 12100 88 33 o ~ ~ ~ 12200 89 06 ~ ~ ~ 12300 89 83 o ~ ~ 12~00 90.61 ~ 1~500 91.36 E~ ~ 12/100 12519 91.49 ~ 12/100 11338 91.49 (Anadrill (c)96 A16AP5 3.0b.03 3:54 PM P) 222.11 8981 8900 4474 2348.95 S 4073.99 W 650369.35 5944998.29 0.00 222.11 9026 8945 5198 2885.55 S 4558.98 W 649895.50 5944451.90 89L 0.00 222.11 9026 8945 5198 2885.55 S 4558.98 W 649895.50 5944451.90 89L 0.00 211.55 9031 8950 5285 2955.65 S 4611.48 W 649844.45 5944380.73 88L 12.00 199.54 9036 8956 5380 3045.59 S 4654.45 W 649803.33 5944289,95 88L 12.00 187.54 9041 8960 5468 3142.53 S 4677.79 W 649781.99 5944192.55 87L 12.00 175.55 9044 8964 5544 3242.25 S 4680.48 W 649781.35 5944092.81 87L 12.00 163.57 9047 8966 5604 3340.39 S 4662.39 W 649801.44 5943995.07 86L 12.00 151.59 9048 8967 5647 3432.65 S 4624.32 W 649841.39 5943903.61 86L 12.00 139.62 9047 8967 5671 3515.02 S 4567.93 W 649899.45 5943822.42 86L 12.00 127.64 9046 8965 5673 3583.88 S 4495.69 W 649973.08 5943755.06 87L 12.00 FOR PERMITTING ONLY PLAN # S' :~ _ J _._,_~ ......· __ ~: ~ _~ ~- ~__ 111, , A-16A (P5) Injector STATION IDENTIFICATION F24D C~VB 12/100 TARGET 3 TARGET 4 4-1/2" CASING PT T ~ 05/09/96 Page 3 PROPOSED WELL PROFILE MEAS INCLN DIRECTION VERT-DEPTHS SECT COORDINATES-FROM ST~FE-PLANE TOOL DL/ DEPTH ANGLE AZIMUTH TVD SUB-S DIST WELLHEAD X Y FACE 100 13383 96.26 13383 96.26 14025 96.26 14209 96.26 14209 96.26 127.78 9021 8940 5570 4095.24 S 3776.36 W 650702.70 5943258.60 12.00 127.78 9021 8940 5570 4095.24 S 3776.36 W 650702.70 5943258.60 12.00 127.78 8951 8870 5522 4486.29 S 3271.93 W 651215.00 5942878.00 0.00 127.78 8931 8850 5508 4598.02 S 3127.81 W 651361.37 5942769.26 0.00 127.78 8931 8850 5508 4598.02 S 3127.81 W 651361.37 5942769.26 0.00 14209 96.26 127.78 8931 8850 5508 4598.02 S 3127.81 W 651361.37 5942769.26 0.00 ,, . ANADRILL AKA-DPC APPROVED FOR PERMITTING ONLY ~-~ PLAN #_. F ~e. o (Anadrill (c) 96 A16AR5 3.0b.0] 3:54 PM P) STATE OF ALASKA ALASKA ~lL AND GAS CONSERVATION COiw~vliSSlON APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 8. 3016' SNL, 1014' WEL, SEC. 35, T11N, R13E 9. At top of productive interval N/A-Water-lnjectionWell ,- ,,-, ,,-,,,,,,~ At effective depth 603' SNL, 164' EWL, SEC. 02, T10N, R13E At total depth 659' SNL, 87' EWL, SEC. 02, T10N, R13E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 11562 feet Plugs (measured) 9640 feet 11415 feet Junk (measured) 9529 feet 6. Datum Elevation (DF or KB) KBE = 79.98 AMSL 7. Unit or Property Name Prudhoe Bay Unit Well Number A-16i Permit Number 80-123 10. APl Number 50-029-20521 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool Fill at 11415' WLM (05/89) Casing Length Size Cemented MD TVD Structural Conductor 110' 20"x30" 8 cu yds 138' 138' Surface 2670' 13-3/8" 3794 cu ft 2698' 2698' Intermediate 10475' 9-5/8" 1720 cu ft 10503' 8794' Production Liner 1551' 7" 456 cu ft 10007' - 11558' 8396' - 9637' Perforation depth: measured true vertical 10570' - 10590' (Sag River) 10687'-10702', 10705'-10758', 10768'-10793', 10797'-10808'(Ivis~ E E subsea 8771'-8787' (Sag River) C 'IV D 8868'- 8969' (four Ivishak intervals) Tubing (size, grade, and measured depth) 7", L-80 to 9281' MAY 2 0 1996 Packers and SSSV (type and measured depth) 9-5/8" Baker SAB packer at 9187'; ISSSV at 2061~lalll(a 0il & Gas 00118. Commis,' Anchorage 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 14. Estimated date for commencing operation May 21, 1996 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water Injection Contact Engineer Name/Number: David Nakamura, 564-5606 Prepared By Name/Number Terrie Hubble, 564-4628 17. I hereby certify that the foregoing~s tru..e arj¢ correct to the best of my knowledge ~ ~'J~,l'l ~ Signed ~,~ ~..~ .... DanStoltz _~- _ Title Senior Drilling Engineer Date ...,%- '/6,-- '¢'(.=. Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- L/O "~ [Approval No. E//(~-//O Approved by order of the Commission Form 10-403 Rev. 06/15/88 Original Signed By David W. Jutu~t0r, Commissioner Date Approved CoPY Returned Submit In Triplicate FIELD &'POOL WELL PERMIT CHECKLIST ADMINISTRATION 1 1 A~,,~ DATE 1 COMPANY ~ ~ WELL NAME PROGRAM: exp [] dev [] reddI,j~'serv~'wellbore seg [] ann. disposal para req [] ON/OFFSHORE ~A/ UNIT# REMARKS INIT CLASS S ~ v' /- G~A! J GEOL AREA 1. Permit fee attached ...................... .~Y~N 2. Lease number appropriate .................. /"~" 3. Unique well name and number ................. ~ ,N, 4. Well located in a defined pool .................. ~., N 5. Well located proper distance from drlg unit boundary ..... .~N 6. Well located proper distance from other wells ......... .~ N 7. Sufficient acreage available in drilling unit ........... (~ N 8. If deviated, is wellbore plat included ............... ~5/N 9. Operator only affected party ................... (~) N 0. Operator has appropriate bond in force ............ ~ N 1. Permit can be issued without conservation order ...... .,,~ N 2. Permit can be issued without administrative approval .... [.~ N 3. Can permit be approved before 15-day walt ......... ~ N ENGINEERING APPR DATE 14. Conductor string provided ................... ~ N~ /) 15. Surface casing protects all known USDWs .......... Y N~, ~/^ 16. CMT vol adequate to circulate on conductor & surf csg .... Y N~) ~'"'-' 17. CMT vol adequate to tie-in long string to surf csg ...... ./Y= N 18. CMT will cover nil known productive horizons ......... Y(~ N ' -- 19. Casing designs adequate for C, T, B & permafrost.. ..... ~,)N 20. Adequate tankage or reserve pit ................ MN ' -- 21. If a re-drill, has a 10-403 for abndnmnt been approved... ~'N 22. Adequate we,bore separation proposed ............ Y~ N ' 23. If diverter required, is it adequate ................ 24. Ddlling fluid program schematic & equip list adequate .... .~ .N, 25. BOPEs adequate ........................ ~ N 26. BOPE press rating adequate; test to ~-~)~x:;~ psig. ~) N 27. Choke manifold complies w/APl RP-53 (May 84) ....... -?'--N-' 28. Work will occur without operation shutdown .......... (~N 29. Is presence of H2S gas probable ................ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide me~ur~.e,.~.---:-~.... Y~ 31. Data presented on potential ov~ ....... Y N 32. Seismic anal~ne, s ............ Y N 33. Seabed con~[JtJefr's'G~ey (if off-shore) ............. Y N AP~R DATE 34. name/phone for weekly progress reports ....... Y N GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN TAB~ Comments/Instructions: HOW/~jb- A:~FORMS~cheklist rev 4796 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. 'rape Subfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPEPJtTOR WITNESS: Date I--~-~6A I 500292052101 MWD RUN 2 AK-MW- 60090 S. NEUBAUER M. WHITELEY BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 28-FEB-97 MWD RUN 4 S ~ NEUBAUER M. WHITELEY MWD RUN 5 T. FLYNN M. WHITELEY JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 T. FLYNN M. WHITELEY MWD RUN 7 T. FLYNN M. WHITELEY MWD RUN 8 T. FLYNN M. WHITELEY MWD RUN 9 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD T. FLYNN J. RALL MWD RUN 10 T. FLYNN J. RALL 35 liN 13E 3016 1014 81.14 79.64 52.14 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 8.500 7.000 10410.0 PRODUCTION STRING 6.000 13020.0 REMARKS: MWD RUN 11 T. FLYNN J. RALL RECEIVED MAR 12 199 AJaska 011 & Co,is. C mmission MWD - GR. ALL DEPTHS ARE MEASURED DEPTHS. ALL GAMMA RAY DATA WAS DOWNHOLE RECORDED. MWD RUN 1 WAS DIRECTIONAL ONLY. NO DATA IS PRESENTED. MWD RUNS 2, AND 4 THROUGH 11 WERE DIRECTIONAL WITH SCINTILLATION TYPE (NGP) GAMMA RAY. MWD RUN 3 WAS DIRECTIONAL WITH GAMMA RAY BUT CONTAINS NO DATA AND SO IS NOT PRESENTED. THIS WELL REACHED A TOTAL DEPTH OF 13020'. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9096.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 9096.0 9093.5 10272.0 10269.5 10274.0 10271.5 10357.5 10354.0 10368.0 10364.5 10406.0 10405.0 10411.0 10410.5 10414.0 10413.0 10439.5 10440.0 10448.0 10446.5 10457.0 10455.0 10464.5 10457.5 10473.0 10466.5 10489.0 . 10484.0 10498.5 10495.0 10502.0 10498.0 10512.0 10507.5 10516.0 10512.5 10520.5 10516.0 10527.5 10523.0 10531.5 10526.5 10538.5 10533.0 10542.5 10537.0 10548.0 10543.5 10552.5 10548.0 10563.5 10559.0 10587.5 10583.5 10598.0 10596.0 10610.0 10607.5 10621.0 10616.5 10665.5 10661.0 10676.0 10670.5 10678.0 10672.5 10715.0 10709.5 10723.0 10718.0 10725.5 10720.0 10731.5 10725.5 10751.5 10746.5 10841.5 10836.0 10860.5 10855.0 10896.0 10890.5 10901.5 10896.5 10926.5 10920.5 11054.5 11047.5 all bit runs merged. STOP DEPTH 12959.0 EQUIVALENT UNSHIFTED DEPTH 11070.0 11107.5 11180.5 11182.0 11185.0 11229.0 11231.0 11241.5 11253.0 11266.5 11284.0 11300.5 11313.5 11322.5 11453.0 11501.0 11628.5 11750.0 11761.0 11772.5 11780.0 11933.0 11953.5 11966.5 11985.5 11990.5 12000.0 12037.0 12077.5 12085.0 12090.5 12102.0 12123.5 12136.5 12164.0 12175.0 12204.0 12223.0 12232.0 12318.5 12338.5 12346.0 12363.5 12404.5 12458.5 12577.5 12580.0 12620.0 12656.5 12668.5 12688.0 12712.5 12829.0 12832.0 12877.5 13022.5 $ MERGED DATA SOURCE PBU TOOL CODE 11( .5 lllu±.0 11175.0 11177.5 11179.5 11223.0 11225.0 11234.5 11246.0 11259.5 11277.5 11293.0 11306.5 11315.0 11447.5 11495.5 11621.5 11746.5 11763.0 11771.5 11779.0 11931.5 11952.0 11969.0 11987.5 11989.0 11998.0 12035.5 12079.5 12084.0 12089.5 12102.5 12122.5 12139.0 12162.5 12173.5 12202.5 12222.0 12230.5 12317.0 12337.5 12343.5 12361.0 12401.5 12459.5 12578.0 12580.5 12619.5 12659.5 12673.0 12692.0 12713.0 12828.0 12831.0 12875.5 13020.5 BIT RUN NO MERGE TOP MERGE BASE s~qXq E9 :MqBusI pxoDs~ mnmTUTH '''spzos~x 965 :X~mmns 5UTPODSp ~pos UOTq~qusss~ds~ $I~ O0000fi'O = 5uTs~dS 000000'0~06 = 000000'0~0CI = 66 966 06 f I0 0I£ O6 f 96 :sp2ooeH ej~G ie~o6 ~ Id~f I 89 GMH H~ poM siO dXi clKL q~Bus% mZTS ~mO AzD 6o% s~Tu~ s~Idmes apoo IOOL smeM :seA-nD E ~ :JI q~dep edei ZdOqS HLHON : V9I-~ : LflO' L,~IH$ & g/ NnOO 'H© HLIM G~L~IHS $~M ZAH~D dOH ZHL 'SS~d NI~ GZ©HZM 0Z0£I 0'S~£~I II fi~£~I 0'S09EI 0I S09~I 0'£6£II 6 £6LII 0'fi~LOI 8 S~£0I 0'9050I L 90~0I 0'9050I 9 90SOI 0'EC~0I fi E£~0I 0'9EIOI ~ 9~IOI 0'~I6 ~ Maximum record length: 1014 bytes Tape Subfile 3 is type: mzS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NO: 2 DEPTH INCREMENT: ,5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9093.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: .DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10064.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 2, 16-JUL-96 1,32 2.o41/5.74 MEMORY 10126,0 9155,0 10126,0 0 31,3 34,1 TOOL NUMBER NGP 188 8,500 ,0 LSND HT 9,90 49,0 10,9 1300 5,0 ,000 ,000 ,000 .000 ,0 72,6 ,0 ,0 ,00 ,000 ,0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE% 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 2 ROP MWD 68 1 AAPI 4 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 27 Tape File Start Depth = 10150.000000 Tape File End Depth = 9050.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6604 datums Tape Subfile: 3 90 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 4 is type: FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10058.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10377.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: MWD RUN 4. 18-JUL-96 1.32 2.041/5.74 MEMORY 10432.0 10126.0 10432.0 0 33 .7 50.2 TOOL NUMBER NGP 188 8.500 .0 LSND HT 9.80 46.0 9.2 1000 4.8 .000 .000 .000 .000 .0 72.6 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 11 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 Tape File Start Depth = 10450.000000 Tape Pile End Depth = 10000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 26708 datums Tape Subfile: 4 74 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes o O' 6'Cc5 O' 0 O' 000 ' 00' 000 ' 000 ' 000 ' 000 ' 8-c5 O000I £'6 0'£q 00'6 HC[H~f,WH~ O' OI$,0I 000':9 88T HZ~NflL'¢ ~00~ ['8c5 L'~zS 0 0'90SOI 0'~£~0I 0'9050I ~£'T 96-%QD-I~ · S NflH (IMM : SMHYN,~ : (I~I) ~,~O(IN-~,T,$ ~IOOJ, : (MI) ~OILDZ~HOD ZqOH (~©ZG) ZHQLV~{ZdNZL L~ (NNHO) X£IAILSISZ~ : (ED) S$Oq GI~q~ :Hd GQN : (©/~) XLISMZ~ ann gNOILI~O0 : (HI) ZZIS LI~ ZqOH NZdO ~g,TAfG ©NIS~fO GhY~ ZqOHZHO~ ZffO~{d tfMHtfO ~i~t{flLtfN dON ZdX£ ~IOOJ, ZGOO ~IO0,L HOGNZA (MOLLO~{ Od] dOL) DNI~{LS ~IO0,1, O' 99~0I H,I, dZ{I dOLS :HZ~HQN ZqI~ HZGIfZH ZqI~ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE% 0) 1014 BYTES * Total Data Records: 5 Tape File Start Depth = 10550.000000 Tape File End Depth = 10350.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7808 datums Tape Subfile: 5 68 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 is type: LiS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10429.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10482.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL ST/~qDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: MWD RUN 6. 21-JUL-96 1.32 2.o41/5.74 MEMORY 10506.0 10506.0 10506.0 0 58.2 62.6 TOOL NUMBER NGP 188 6.000 10410.0 SHEARDRILN 9.00 53.0 9.3 10000 5.8 .000 .000 .000 .000 .0 56.2 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT :BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 10550.000000 Tape File End Depth = 10400.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 27612 datums Tape Subfile: 6 67 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 7 is type: ~S FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10467.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10706.0 22-JUL-96 1.32 2.041/5.74 MEMORY 10745.0 10506.0 10745.0 0 63.1 87.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 181 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 10410.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SHEARDRI LN 9.00 53.0 9.3 10000 5.8 .000 .000 .000 .000 .0 53.9 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) · .0 0 REMARKS: MWD RUN 7. s~Xq ~TOT :M~6u~I p~oo~ mnmTxeM s~Aq ~9 :M~Bu~I p~oo~ mnmTuTM · --sp~oo~ IL L :~IT~qns ~deL smn~p ~I96 89 :~poo d~ :X~emmns Bu~poo~p ~poo uo~e~u~s~d~ SI~ 000005'0 = BUToeds I~ ~ITZ adeL 000000'0S~0I = qqd~ puz ~IT~ ~de£ 000000'0~LOI = qqd~ q~mqS ~IT~ ~deL :sp~oo~H e~e~ Ie~O£ 66 966 06 ~ I0 0I£ 06 f ~ HHdg I 89 GMM dOH ~ ~ Id~f I 89 GMM HO I pon sIO clXL clXL q~Bu~q ~zys A~D ~O Boq s~Tu~ s~Idmes ~poo IOOL ~meM ~DMS~ : ZdOqS HLHOM : XV~ ZOHCK1Hd : ~ggI-~f : (~rMS~gqV) MOILYHOq~XZ c]~ : NflOO N.M 0 O' : (ZH) itOhI,~QOglg~t ~tM~ : (HI) .~.~O~NlfJlS qOO,T, 000 ' 00' : (HI) MOILDZHHOD ZqOH :XLISHZG XIHL~H :XIHL~ ~OOL HOHLQZH . O' £'OL O' 000 ' 000 ' 000 ' 000 ' 9'S 0008 0'IS 06'8 Hq IH{IH~fZHS : (LH) ZHQ~ttZdHZ~ ~ZHQS~ZH L~ (~©ZG) ZHQLYHZdHZL £~ (HMHO) XLIAILSISZH : (ED) SSOq ~I~q~ : (Hdd) SZGIHOqHD 0'0I~0I 000'9 : (HI) ~ZIS LIE ZqOH HZdO ~fL~fG OKI g~fD GN-~ ZqOHZHO~ 88I d©M HZ~HI1N qOOL ZdXJ, qOO£ Z~OD qoOJ, HOGi{ZA (HOLLO~ O,I, dOL) Di{IHLS qOOJ, £'68 6'S8 0 0'£6LII 0'S~LOI 0'£6AII ~£'I 96-qQP-~E 0'6~LII :Zq©kltf MflHIXtfM :Zq©kltf (©Z~) HOIL~NIqDNI ZqOH : (Hd~) ~ZZdS : (IL) q~AHZLNI DOq HOLLO~ :(~) :~OISHZA Z~NfML~OS ZqOHNIMOG 0'18901 HLdZG L~LS ZGO~ qOOL ~OG~ZA X~~S ZqI~ 000S' :~NZHZ~I H~dZ~ 8 :O~ ~ ~I~ · Sells e~exedes uT un~ ~lq qoee xo~ e~ep xepeeq 6oi pue seAxn0 GMM MtfH L :HZ~HQI~ ZqI~ ~ZGtfZH ZqI~ SI~ :ectX~ sT 8 eIT~qns ede~ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 28 Tape File Start Depth = 11800.000000 Tape File End Depth = 10650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 34516 datums Tape Subfile: 8 91 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes o 0' 0'S/. 0' 0 0' 000 ' 00' 000 ' 000 ' 000 ' 000 ' 0008 S'6 0'9S 06'8 ~Iq IHCIH~f,~HS O'OT~OT 000'9 181 4©~ HZ~HflH qoo& g'I6 0 0'909gI 0'£6£1I 0'909gT XHONZN ~L'S/Z~O'~ ~C'I 96-qgP-Sg : (7, H) io~tnO~ta : (Mi) ddOQNtf&S :(MI) HOILDZHHOO ZqOH :A&ISMZ~ XIHL~fl4 :XIHL~ qO0£ HOH£DZM (d©ZG) Z~L~t~ZdHZL L~ (HHHO) XLIAILSISZH : (ED) SSOq ~IDqd : (Hdd) SZGIHOqHD GDH :Hd GDH : (S) XIISODSIA : (©/gq) XLISHZ~ SHOILI~HO~ : (LZ) HLdZG ©HIS~O S,HZqqIHG : (MI) ZZIS LI~ ZqOH HZ40 ~£~G ©MI$~O GNIf ZqOHZHO~ Z~OHd ~1~© q~l,lafM dOM ZdXJ. qOOJ, ZGOO qO0,1, HO~MZA (HO.I,LO~ O,I. dOL) DHIHJ,S qOOL 0'6~9gI HLdZ~ dOLS 'sails e~e~edes u~ un~ ~lq Moee ~oj e~mp xepeeq BoI pue saA~no 8 :HZ~MSt{ ZqI~ HZGt~ZH ZqlZ STq :eCLK% ST 6 eI!jqns edeL CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 O1 1 4 90 995 99 1 * DATA RECORD (TYPE% 0) 1014 BYTES * Total Data Records: 23 Tape File Start Depth = 12650.000000 Tape File End Depth = 11700.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 15316 datums Tape Subfile: 9 86 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 10 is type: miS FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12554.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMIIM ANGLE: STOP DEPTH 12699.0 26-JUL-96 1.32 2.041/5.74 MEMORY 12745.0 12605.0 12745.0 0 88.2 89.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 6.000 10410.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SHEARDRILN 9.00 56.0 9.4 7000 4.6 .000 .000 .000 .000 .0 70.3 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 10. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: Tape File Start Depth = 12800.000000 Tape File End Depth = 12550.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36020 datums Tape Subfile: 10 69 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 11 is type: ~IS FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12684.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12957.0 28-JUL-96 1.32 2.041/5.74 MEMORY 13020.0 12745.0 13020.0 0 65.4 87.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 188 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 6.000 10410.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SHEARDRILN 9.00 61.0 8.8 8000 4.0 .000 .000 .000 .000 .0 86.7 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 11. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE% 0) 1014 BYTES * Total Data Records: 10 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 995 99 1 Tape File Start Depth = 13050.000000 Tape File End Depth = 12650.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 17720 datums Tape Subfile: 11 73 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes -spuooss EO'£ = smy~ uoy~no~xs pssd~IZ dL~:8 L6 ~Z~ 8~ ~ :uoy~nosx~ ~o puz s~Jq ~£I :q~u~I p~oo~ mnm~x~M s@qJq ~£T :qqBu~I p~oo~ mnmT~TH · ''sp~oo~ ~ ~I :~I~qns ~deL IO IO Tape S~bfile 2 is type: TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: A - 16A 500292052101 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 14-AUG-96 RUN 1 6733.01 J. DAHL COPEN/HEIM RUN 2 RUN 3 35 liN 13E 3016 1014 81.14 81.14 52.14 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 10410.0 6.000 13020.0 DIFL/DAC/ZDL/CN/GR. CIRCULATION STOPPED @ 19:15, 27-JLrL-96. PIPE CONVEYED LOGGING OPERATION. PER E-MAIL NOTE FROM DONNA MESSER (BP), THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. GAMMA RAY SPIKE AT 12852' ON REPEAT AND MAIN PASS DUE TO NEUTRON ACTIVATION. TD NOT TAGGED. RB (RELATIVE BEARING) ORIENTATION WAS 180 DEGREES = DENSITY PAD IS DOWN. PER CLIENT'S REQUEST, BOREHOLE & TORNADO CHART CORREC- TIONS WERE APPLIED TO THE DIL DATA. THE DIL DATA WAS CALIPER CORRECTED. THE CORRECTED DATA WAS THEN USED IN THE ATLAS TORNADO CHART TO GET "RT" & "DI" CURVES. RT = TRUE FORMATION RESISTIVITY. DI = DEPTH OF INVASION. NEUTRON LOG PARAMETERS: SANDSTONE MATRIX, CALIPER CORRECTED, CASING CORRECTIONS OFF, FILE HEADER FILE NUMBER: 1. EDITED OPEN HOLE MAIN PASS Ail tool strings; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DAS depth shifted and clipped curves; .5000 DIL SDN 2446 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 10420.0 12912.0 10420.0 12968.0 10420.0 13006.0 10420.0 12938.0 10420.0 12918.0 BASELINE DEPTH LL8 10430.0 10432.5 10442.5 10443.5 10446.0 10446.5 10446.5 10452.0 10452.0 10453.5 10456.0 10457.0 10458.0 10458.5 10461.0 10464.0 10464.5 10464.5 10470.5 10475.0 10475.5 10479.0 10480.5 10481.0 10482.5 10484.0 10490.0 10490.5 10494.5 10494.5 10496.0 10498.5 10499.0 10502.0 10501.5 10503.5 10509.5 10512.5 10516.0 10517.5 10522.5 10527.5 10532.0 10563.5 10567.5 10574.0 EQUIVALENT UNSHIFTED DEPTH ILD DT RHOB 10430.0 10432.5 10442.5 10442.0 10446.5 10446.0 10453.0 10455.0 10457.5 10458.0 10461.0 10464.0 10464.0 10463.5 10471.0 10475.5 10479.5 10479.0 10481.5 10484.5 10484.0 10489.5 10494.5 10494.5 10499.0 10502.5 10509.5 10517.0 10567.0 10522.5 10527.5 10564.5 10574.0 all runs merged; NPHI 10442.5 10458.5 10463.5 10475.5 10480.5 10483.5 10490.0 10498.5 10503.5 10512.0 10516.0 10532.5 10564.0 no case 1057~.5 10582.0 10589.0 10589.5 10603.0 10605.5 10610.0 10611.5 10612.0 10612.5 10614.5 10617.5 10619.5 10622.0 10622.5 10627.0 10631.0 10635.0 10636.5 10637.0 10638.0 10645.5 10648.5 10654.5 10664.0 10666.5 10676.0 10676.5 10679.5 10720.5 10725.5 10736.0 10736.5 10738.0 10740.0 10752.5 10764.5 10765.5 10767.5 10771.0 10774.0 10774.5 10793.5 10844.5 10845.0 10847.0 10847.5 10859.0 10892.0 10897.0 10897.5 10902.5 10915.0 10929.5 10944.5 11054.0 11054.5 11062.0 11068.5 11106.0 10581.5 10612.5 10618.5 10636.5 10675.5 10736.5 10753.0 10764.5 10897.5 10581.5 10588.0 10602.5 10613.0 10622.5 10627.5 10631.0 10638.5 10646.5 10652.0 10660.5 10679.5 10738.0 10892.0 10897.5 10902.5 10589.5 10610.0 10614.5 10622.0 10736.0 10752.0 10774.5 10845.0 10897.0 10929.5 11054.0 11062.5 11068.5 .576.5 10582.0 10588.5 10605.0 10611.0 10619.5 10634.5 10636.5 10677.0 10721.0 10725.5 10735.5 10739.5 10767.5 10771.5 10774.5 10844.5 10848.0 10859.0 10896.0 10914.0 10943.5 11054.0 11066.5 11106.0 10612.0 10622.0 10648.0 10666.0 10676.5 10766.0 10793.5 10846.5 ili~4.5 11115.0 11146.0 11152.5 11169.0 11169.5 11182.5 11185.5 11189.0 11189.5 11230.5 11231.0 11239.0 11240.0 11254.5 11268.5 11323.5 11442.5 11459.0 11460.5 11625.5 11629.5 11630.0 11687.0 11687.5 11725.0 11725.5 11727.5 11729.5 11731.0 11737.0 11748.0 11758.5 11778.5 11783.0 11793.0 11827.0 11830.5 11930.0 11934.0 11955.0 11957.0 11959.5 11969.5 11998.5 12023.5 12031.0 12078.5 12079.5 12085.0 12091.5 12102.5 12103.5 12105.5 12118.0 12168.0 12172.5 12215.0 12224.5 12227.5 11629.5 11955.0 11783.0 11152.5 11185.0 11238.5 11254.0 11323.5 11460.0 11629.0 11726.0 11737.5 11779.0 11930.0 11934.5 11957.0 12079.5 12085.0 12102.5 12117.5 _114.0 11169.0 11183.0 11189.5 11230.0 11240.0 11254.5 11269.0 11323.0 11442.0 11459.0 11625.5 11628.5 11687.0 11725.0 11730.5 11747.5 11778.0 11793.5 11826.5 11830.5 11933.5 11959.5 11969.5 11998.5 12023.5 12031.0 12077.5 12084.0 12090.5 12103.5 12105.0 12117.5 12168.0 12173.0 12214.0 12223.5 11115.0 11146.5 11169.0 11183.0 11189.0 11230.5 11442.0 11629.5 11687.5 11727.0 11728.5 11759.0 12228.0 12230.0 12323.0 12334.5 12336.5 12340.0 12340.5 12342.5 12364.5 12381.0 12392.0 12405.0 12429.5 12471.5 12472.0 12474.0 12486.5 12520.5 12557.5 12568.0 12646.5 12664.5 12667.0 12681.0 12720.5 12723.0 12775.5 12796.0 12811.0 12818.5 12829.5 12830.0 12849.0 12849.5 12853.5 12857.0 12877.5 12878.0 12891.0 12915.5 12917.5 12981.5 $ MERGED DATA SOURCE PBU TOOL CODE GR DAS DIL SDN 2446 $ REMARKS: 12342.5 12364.5 12667.0 12877.5 12520.5 12981.5 12230.0 12335.0 12341.0 12405.0 12471.5 12664.5 12667.0 12818.5 12830.0 12849.0 12878.0 12323.0 12336.5 12339.5 12391.5 12429.5 12471.5 12487.0 12558.0 12646.5 12667.0 12681.5 12721.0 12724.0 12775.5 12795.5 12810.5 12818.5 12830.0 12849.0 12853.0 12856.5 12877.0 12891.0 12915.0 12917.5 RUN NO. PASS NO. MERGE TOP 1 5 10420.0 1 5 10420.0 1 5 10420.0 1 5 10420.0 1 5 10420.0 OPEN HOLE portion of MAIN PASS. MTEM, SP, TEND, & TENS WERE SHIFTED WITH LL8. ILM, RT, & DI WERE SHIFTED WITH ILD. DRHO, PEF, CALl, & RB1 WERE SHIFTED WITH RHOB. FUCT & NUCT WERE SHIFTED WITH NPHI. 12336.5 12340.5 12380.5 12472.0 12473.5 12567.5 12849.5 MERGE BASE 12912.0 12968.0 13006.0 12938.0 12918.0 / ? ?MATCH1. OUT :X~mmns Bu!poo~p ~pom uoy~u~s~xd~x SI~ O0000S'O = BuID~dS I~A~ ~I!~ 000000'0~0I = q~d~ pu~ ~IT~ ~d~ 000000'SE0£I = q~d~G ~e~S ~I~ ~£f :sp~oo~%I ~G I~O~L 996 (0 #~dAi) ~MOD~]{ ~~ · 9L I I I I I I I I I I I I I I I I I I I 66 S66 L~ 9 66 S66 LP ~ 66 S66 L~ ~ 66 S66 6P ~ 66 ~66 6P 9 66 ~66 6~ ~ 66 S66 65 ~ 66 S66 6~ ~ 66 S66 80 ~ 66 S66 80 ~ 66 S66 80 9 66 S66 80 ~ 66 S66 80 ~ 66 S66 80 9 66 S66 80 ~ 66 S66 6S 9 66 ~66 6~ 9 9I 0£S 6g ~ I0 0I£ 6S 9 pon sIO ~ clXi q~Su~q az!s AID A~D 50% S~TUfl s~Idm~s spoD IOOl ~m~N :ssA~nD 6I ~ :~I q~dap ad~i ~~ : MdO%S HAHON : A~M MOHfIflHd : ~9I-W : (~S~I~) NOII~fMO%dXM dM : .~AffLS NflOD N.~ NM ND Rep Code: 68 104~_~1 datums Tape Subfile: 2 746 records... Minimum record length: 62 bytes Maximum record length: 966 bytes ~ S~J~t~ ~IO'E (0 #~cIX,T.) Cl~IO3.~I '¢'.T.MCI ~ I 66 966 AP P I 66 ~66 LP P I 66 ~66 LP P 66 966 LP P I 66 966 LP P I I0 0IC L~ ~ ~ ~q I 89 99~E SNSi 9 ~ ~q I 89 95~E ON~i S 9 SdD I 89 99~E ~D~ ~ S-~d I 89 9~5~ IHdN 9 Idtf~ I 89 99~E HDH~ pON slo clX£ d/kL q~Sus~ sz~s A~D A~D 5Oq Id~ Id~ Id~ Id]f s~!u~ saIdm~s ~poD IOOl ~m~M : s~A~no 9 .4 :~I q~d~p ~d~j, MNIr~4 %{.~d HJ~.~(I ZNO (59 #MdAi) OngODMM Ikqa-~OM ~ kr)t~ : MdO~S HiMON : X~ MOHGIIMd : V9I-~ : (¥~~) NOI~lf~O~dXH d~ : 'IHdM HiIM OMAMIHS MM~t iDflg ~ 6DO~ 'SStfd NIYN go UOTq~od H~OH GMSWD 0'IIP0I 0'80P0I IHdN 0'0g~0I 0'0g~0I HIdHG ~O~S 0 'iI~0I 0 '80~0I PLLd ZG MNI~f,~Stf~ · 6UlSWm oquT un~ s5oI elOq u~do ~og ssm~n3 p~ddTIm pue p~Tqs qqdso SS~d NIIfN ~OH O~SlfD G~iIO~ :~Z~IN Z~I~ ~Z~fZH Z~I~ SI% :gclX~ sT £ 9IT~qns sdei Total Data Records, 8 Tape File Start Depth = 10420.000000 Tape File End Depth = 10290.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1828 datums Tape Subfile: 3 40 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 0'0~0I 0'0I~0I 000'9 :(In) HIdZG DNIS~D S,HZDDO% :(NI)ZZIS II~ Z%OH N~dO ~iWG DNISTfD ~ ~r~IS ND ~NOD iHS AIMS ZdXi TOOL Z~OD TOOL ~OGNZA (MOLiO~ Oi dOi) DNI~iS TOOL 0'00SI 0'8005I 0'0EP0I 0'010£I 0'0g0£I 96-TD_g-SE E£PI 96-~iftg-£g SI6I g'g SdIqDZ 96-qD_g-Sg : NOIS%{~IA 0'£E6EI 0'00£0I 0'8~6EI 0'00£0I TGZ 0'II0£I 0'8150I TIG 0'0t6EI 0'00£0I D~G 0'LI6EI 0'00£0I HLdZ~ dOiS HL~ZG i%5fiS Z~OD ~OOi HOGNZA 00SE' I I · un~ ~d s6uIx~s IOO~ ss~d uy~m ~o~ s~II~ Aq paaoIIO~ (I~n-~s~u! ~7qooxaIp~S aq~ ~7qs q~d~p o~ p~sn iox~uoo q~d~p X_~wm!~d) ~sxy~ ps~u~s~d unx ~!qoox~iP~S xo~ I# 6uy~S ~s~I~~ a~d~s u7 6u~l~s ioo~ pu~ uni qD~ IO~ ~Pp ~apPaq 6oi pu~ s~AxnD SS~d NI~4 ~qOH NZdO :H~WflN ONIHIS qOOi SIq :adX~ s! 5 ~I7~qns BOR~-qOLE COND I T IONS MiID TYPE: ~JqD DENSITY (LB/G): M-JD VISCOSITY (S) : M~JD PH: FLUID LOSS (C3) : MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MI/D FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN): REMARKS: MAIN PASS. $ WN FN COUN STAT : BP EXPLORATION (ALASKA) : A-16A : PRUDHOE BAY : NORTH SLOPE SHEARDRILN 9.00 61.0 4.0 8.8 223.0 .200 .070 .195 .000 .409 .000 THERMAL SANDSTONE 2.65 .000 1.0 78.0 223.0 78.0 .0 77.0 .0 * FORMAT RECORD (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 23 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 GR DAC 68 1 GAPI DT24 DAC 68 1 US/F CHT DAC 68 1 LB TTEN DAC 68 1 LB TEN DAC 68 1 LB SPD DAC 68 1 F/MN RFOC DIFL 68 1 OHMM RILM DIFL 68 1 OHMM RILD DIFL 68 1 OHMM RT DIFL 68 1 OHMM DI DIFL 68 1 IN SP DIFL 68 1 MV WTBH DIFL 68 1 DEGF ZDEN ZDL 68 1 G/C3 ZCOR ZDL 68 1 G/C3 PE ZDL 68 1 BN/E 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 56 310 01 1 4 56 995 99 1 4 56 635 99 1 4 56 635 99 1 4 56 635 99 1 4 56 636 99 1 4 07 220 06 1 4 07 120 44 1 4 07 120 46 1 4 07 120 46 1 4 07 120 44 1 4 07 010 01 1 4 07 995 99 1 4 46 350 01 1 4 46 356 99 1 4 46 358 01 1 17' CAL ZDL 66 1 18 RB ZDL 68 1 19 CNC 2446 68 1 20 CNCF 2446 68 1 21 CN 2446 68 1 22 LSN 2446. 68 1 23 SSN 2446 68 1 * DATA RECORD (TYPE# 0 ) Total Data Records: 1136 IN 4 DEG 4 PU-S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 966 BYTES * 46 280 99 4 46 631 01 4 47 995 99 4 47 995 99 4 47 890 01 4 47 334 31 4 47 334 30 92 Tape File Start Depth = 13025.000000 Tape File End Depth = 10187.000000 Tape File Level Spacin9 = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decodin9 summary: Rep Code': 68 376694 datums Tape Subfile: 4 1224 records... Minimum record length: 62 bytes Maximum record length: · 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12470.0 DAC 12470.0 DIFL ZDL 2446 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): 12470.0 12470.0 12470.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SWIVEL SUB CABLEHEAD TENSION COMMON REMOTE KNUCKLE JOINT GAMMA RAY COMPENSATED NEUTRON KNUCKLE JOINT 'Z-DENSITY KNUCKLE JOINT DIGITAL ORIENTATION KNUCKLE JOINT DIGITAL ACOUSTILOG KNUCKLE JOINT SLAM ADAPTER KNUCKLE JOINT DUAL INDUCTION SWIV CHT COMR KNJT GR CN KNJT ZDL KNJT ORIT KNJT DAC KNJT SLAM KNJT DIFL $ BORE~{OLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER' S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: STOP DEPTH 12919.0 12972.0 13013.0 12950.0 12925.0 28-JUL-96 ECLIPS 2.2 1915 1332 13020.0 13010.0 10420.0 13008.0 1500.0 27-JUL-96 28-JUL-96 TOOL NUMBER 3944XA 3981XA 3510XA 3923XA 1329XA 2446XA 3923XA 2228XA 3923XA 4401XA 3923XA 1680MA/1667EA 3923XA 3516XA 3921NA 1503XA 6.000 10410.0 10420.0 SHEARDRILN pon s;~ufl SaldmeS apoo IOO~ amen :saA~nD GE ~ :GI q;dap adel ( ~9 #.gdX.T.) Cr~OO,g~ 3.~0~I ~ . O'LL O' 0'gL O' GEE 0'gL 0'I 000' S9'E ~NOiSGN~S ~~Hi 000 ' 609' 000 ' ~6I ' 0L0 ' 00E ' 0'GEE 8'8 0'~ 0'I9 0' ~ S~i~ : .gdO~IS H.T.%{ON : A~f~ ,gOHGII%fd : %f9I-%f : (~~) NOI.T,¥~O~IdX.~ d~ : : (NI) ,~,~OClN~.T.S ~O0.T. : (NI) NOI,T,D.g%{%IOD ~IOH : X.T. ISN~Q XI%I,T.~5~ : : (~i~.gH,T. gO T~kr~.~H.T. Id,g) ~dX.T. ~IOO£ ~IO0.T, NO%{.T.G,gN 19~ CNC 2446 68 1 20 CNCF 2446 68 1 21 CN 2446 68 1 22 LSN 2446 68 1 23 SSN 2446 68 1 * DATA RECORD (TYPE# 0) Total Data Records: 276 PU- S 4 PU-S 4 PU-L 4 CPS 4 CPS 4 966 BYTES * 47 995 99 4 47 995 99 4 47 890 01 4 47 334 31 4 47 334 30 92 Tape File Start Depth = 13025.000000 TaPe File End Depth = 12337.000000 Tape File Level Spacin9 = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decodin9 summary: Rep Code: 68 67901 datums Tape Subfile: 5 362 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 6 is type: LIS 96/ 8/14 01 **** REEL TRAILER **** 96/ 8/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 14 AUG 96 5:17p Elapsed execution time = 6.76 seconds. SYSTEM RETURN CODE = 0