Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-107
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 14-21A PRUDHOE BAY UNIT 14-21A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 14-21A 50-029-20756-01-00 205-107-0 W SPT 8763 2051070 2191 888 889 888 891 404 544 548 549 4YRTST P Sully Sullivan 9/8/2025 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 14-21A Inspection Date: Tubing OA Packer Depth 469 2302 2257 2247IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250910173358 BBL Pumped:4 BBL Returned:4.4 Wednesday, October 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg <-R, P.I. Supervisor FROM: Lou Laubenstein Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 8, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC 14-21 A PRUDHOE BAY UNIT 14-21A Src: Inspector Reviewed B P.I. Supry Comm Well Name PRUDHOE BAY UNIT 14-21A API Well Number 50-029-20756-01-00 Inspector Name: Lou Laubenstein Permit Number: 205-107-0 Inspection Date: 9/4/2021 Insp Num: mitLOL210905162232 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 14-21A Type Inj W TVD 8763 Tubing 1647 - 1648 - 1647 1649 - PTD 2051070 ' Type Test SPT Test psi 2191 - IA 90 2411 2369 - 2358 BBL Pumped:1. 6-2 BBL Returned: 6.2 OA 76 112 116 116 Interval 4YRTST P/F P Notes: 4 year MIT -1A i Wednesday, September 8, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,September 21,2017 P.I.Supervisor I\ I(Z'(t 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. 14-2IA FROM: Chuck Scheve PRUDHOE BAY UNIT 14-21A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry j'(a 12- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-21A API Well Number 50-029-20756-01-00 Inspector Name: Chuck Scheve Permit Number: 205-107-0 Inspection Date: 9/15/2017 ✓ Insp Num: mitCS170915124128 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 14-21A - Type Inj W TVD 8763 Tubing 872 • 871 - 881 - 890- PTD 2051070 Type Test SPT Test psi 2191 IA 58 2402 - 2388 ' 2383 - BBL Pumped: 6.3 - BBL Returned: 4.9 OA 77 167 " 164 - 165 Interval 4YRTST P/F P Notes: Thursday,September 21,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Regg P.I.Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 14-21A FROM: Lou Grimaldi PRUDHOE BAY UNIT 14-2IA Petroleum Inspector Src: Inspector Reviewed By��:QQ�� P.I.Supry OIL 1°13It3 NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 14-21A API Well Number 50-029-20756-01-00 Inspector Name: Lou Grimaldi Permit Number: 205-107-0 Inspection Date: 9/13/2013 Insp Num: mitLG130915143605 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well i 14-21A 'Type Inj G •TVD 8763 IA 696 •1 2497 .1 2480 - 2483 -I PTD 2051070 Type sPT psi 2191 yP Test `Test OA 125 137 1ao 141 , Interval rYRTST P/F P -' Tubing 3063 3071 3077 3073 — Notes: 3.8 bbl's methanol pumped,3.8 bbl's returned.Good solid test. . SCANNED OE 2 2013 Wednesday,October 02,2013 Page 1 of 1 Fib( IVlU STATE OF ALASKA l_J L 11 1 2012 • AKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon U Repair Well U Plug Perforations U Perforate U Other L/1 Brightwater Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended WeIiO 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development❑ Exploratory ❑ ` 205 -107 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: • Anchorage, AK 99519 -6612 50- 029 - 20756 -01 -00 7. Property Designation (Lease Number): .. 8. Well Name and Number: ADL0028314 PBU 14 -21A 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 12339 feet Plugs measured None feet true vertical 9036.91 feet Junk measured None feet Effective Depth measured 12253 feet Packer measured See Attachment feet true vertical 9028.78 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 91.5# H-40 29 - 111 29 - 111 1490 470 Surface 2489 13 -3/8" 72# L -80 28 - 2517 28 - 2516.58 4930 2670 Intermediate None None None None None None Production 8498 9 -5/8" 47# L -80 27 - 8525 27 - 6710.87 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11540 - 11570 feet 11810 - 11900 feet 11920 - 12000 feet 12080 - 12140 feet 12160 - 12210 feet True Vertical depth 8884.36 - 8903.94 feet 8982.24 - 8992.59 feet 8994.3 - 9002.05 feet 9009.46 - 9015.87 feet 9018.65 - 9024.56 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 24 -11428 24 - 8804.51 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: ��� Cry Intervals treated (measured): jA 2 8 3 11540' - 11570', 11810' - 11900', 11920' - 12000', 12080' - 12140', 12160' - 12210' Treatment descriptions including volumes used and final pressure: 397 Gallons EC -9360A Surfactant, 2078 Gallons EC -9398A Polymer 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2382 0 649 Subsequent to operation: 0 0 6005 0 1205 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: r Oil ❑ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG 0 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 Gam.Catron(c�BP.Com Printed Name Garry Catron Title PDC PE Signature A 4441 Phone 564 -4424 Date 10/10/2012 D S OCT 15 2Oi2 ^ ` / ° Form 10-404 Revised 10/2012 Submit Original Only Packers and SSV's Attachment ADL0028314 SW Name Type MD TVD Depscription 14 -21A PACKER 8363 6537.96 7" Baker ZXP Packer 14 -21A PACKER 11371 8692.26 4 -1/2" Baker S -3 Packer 14 -21A PACKER 11436 8739.52 4 -1/2" Baker ZXP Packer • • Casing / Tubing Attachment ADL0028314 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 91.5# H-40 29 - 111 29 - 111 1490 470 LINER 3184 7" 26# L -80 8352 - 11536 6601.71 - 8881.59 7240 5410 LINER 915 4 -1/2" 12.6# L -80 11424 - 12339 8801.62 - 9036.91 8430 7500 PRODUCTION 8498 9 -5/8" 47# L -80 27 - 8525 27 - 6710.87 6870 4760 SURFACE 2489 13 -3/8" 72# L -80 28 - 2517 28 - 2516.58 4930 2670 TUBING 11404 4 -1/2" 12.6# L -80 24 - 11428 24 - 8804.51 8430 7500 • • Daily Report of Well Operations ADL0028314 ACTIVITYDAT. _ - °,n T /I /O = 900/40/120 Temp =Hot ( Brghtwater Reservoir Sweep Mod) RU and started pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 164 gal. EC9360A (Surfactant) Average of 27 gph for 6 hrs. Pumped a total of 164 gal. since start of project. Pumped 875 gal. EC9398A ( Polymer) Average of 145 gph for 6 hrs. Pumped a total of 875 gal. since start of project. 9/17/2012 ** *Continued on 09 -18 -2012 WSR * ** 171 /0 = 1191/50/100 ** *Continued WSR -from 09 -17- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 674 gal. EC9360A (Surfactant) Average of 28.08 gph for 24 hrs. Pumped a total of 838 gal. since start of project. Pumped 3804 gal. EC9398A ( Polymer) Average of 158.5 gph for 24 hrs. Pumped a total of 4679 gal. since start of project. ** *Continued on WSR 09 -19- 2012 * ** 9/18/2012 171/0 = 12027507120 ** *Continued WSR from 09 -18- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 731 gal. EC9360A (Surfactant) Average of 30.45 gph for 24 hrs. Pumped a total of 1569 gal. since start of project. Pumped 3572 gal. EC9398A ( Polymer) Average of 148.83 gph for 24 hrs. Pumped a total of 8251 gal. since start of project 9/19/2012 ** *Continued on WSR 09/20/2012 * ** T /I /O = 1234/50/120 ** *Continued WSR from 09 -19- 2012 * ** Temp =Hot (Brightwater Reservoir Sweep Mod) Pumping brightwater chemicals down TBG while on water injection @ 6000 bwpd. Pumped 397 gal. EC9360A (Surfactant) Average of 29.4 gph for 13.5 hrs. Pumped a total of 1966 gal. since start of project. Pumped 2078 gal. EC9398A ( Polymer) Average of 159.84 gph for 13 hrs. Pumped a total of 10329 gal. since start of project Final WHPS 1235/100/200 9/20/2012 TREE =� FMC • +NELLHEAD = GRAY GEN II SAO NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR = BAKER C 14 -21 A WHEN WELL MI. WELL L > REQUIRES @ 6S0 SSSV WHEN ON KB. ELEV= 71' BF ELEV = _.. KOP 2400' ) 25' — 15 - 1/2" X 4 -1/2" XO, ID = 3.958" Max Angle = 86° © 12072' Datum MD = 11521' 2217' —14-1/2" HES X NIP, ID = 3.813" -- . l , Datum TV D = T 8800' SS 5-1/2" TBG- PC, 17 #, L -80 H 25' .0232 bpf, ID = 4.892" 8352' 9 -5/8" X 7" BKR C-2 ZXP LTP 113 -3/8" CSG, 72 #, L -80, ID = 12.347" —1 2517' . �w / 11.4" TIEBK SLV, ID = 6.30 " 8369' - 19 -5/8" X 7" BKR HMC LNR HGR, ID = 6.30" Minimum ID = 3.725" @ 11415' HES XN NIPPLE MILLOUT WINDOW (14 - 21A) 8509' - 8525' 1WHIPSTOCK (08/15/06) 1 - 1 8509' 11350' —14 -1/2 " HES X NIP, ID = 3.813" i k i 1 11371' — 17" X 4 -1 /2" BKR S -3 PKR, ID = 3.875" IEZSV (08/14/05)1 8522' �� ;' , 11394' —{4 -112" HES X NIP, ID = 3.813" l 15-1/2" TBG STUB (08/14/05) 8685' r ��♦�*47 St 4 11415' —14-1/2" HES XN NIP, ID = 3.725" ►40♦� 11424' — 7" X 5" BKR ZXP LTP 9 -5/8" CSG, 47 #, L -80, ID = 8.681" —1 12036' — ► (TIEBACK), ID = 4.440 ►j r tt,. j ��0�0.4 ilk 11428' —14-1/2" WLEG, ID = 3 958" • W -,'.•. , ♦ 11442' — 7" X 5" HMC LNR HGR, � ID = 4.410 4 -1/2" TBG, 12.6 #, L -80, TC-II, --1 11428' 11449' 1 5" x 4 -112" x0, .0152 bpf, ID= 3.958" ID =3.950" PERFORATION SUMMARY ` REF LOG: MWD/ GR/ RES ON 08/22/05 ` ANGLE AT TOP PERF: 47° @ 11540' 7" LNR, 26 #, L -80 BTC-M, —1 11536' 11 Note: Refer to Production DB for historical perf data .0383 bpf, ID = 6.276" SIZE SPF INTERVAL Opn /Sqz DATE ` 2 -7/8" 6 11540 - 11570 0 08/24/05 2 -7/8" 6 11810 - 11900 0 08/24/05 11 2 -7/8" 6 11920 - 12000 0 08/24/05 2 -7/8" 6 12080 - 12140 0 08/24/05 ■ 2 -7/8" 6 12160 - 12210 0 08/24/05 PBTD 12253' 14 4 -1/2" LNR, 12.6 #, L -80, TC-II, .0152 bpf, ID = 3.958" H I 12339' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/13182 ORIGINAL COMPLETION 02/14/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: 14 -21A 01125188 LAST WORKOVER 04/23/11 JC/PJC TREE= (04 /14/11) PERMIT No '2051070 08127105 N2ES SIDETRACK (14 - 21A) 01/17/12 TMN/JMD ADDED H2S SAFETY NOTE AR No 50- 029 - 20756 -01 03/30/07 JMC/PJC DRLG DRAFT CORRECTIONS SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL 06/21/07 PJC CORRECTIONS 06/02/09 JAF /TLH PERF CORRECTIONS BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 07, 2009 • bP ~~C ~. °v ~OJ9 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, y ~ p ~ .., ~ _-, ~ ~d;~..~~~~SiGr~ E a,os- l ~~ d~--a~A Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 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, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-14 Date: 12/05/09 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 14-O1A 1931850 500292031701 Sealed Conductor NA NA 14-02C 2071150 500292031803 Sealed Conductor NA NA 14-03A 1961290 500292031901 Sealed Conductor NA NA 14-04A 1961640 500292032001 Sealed Conductor NA NA 14-05A 1920010 500292032701 Sealed Conductor NA NA 14-06A 2040360 500292032801 Sealed Conductor NA NA 14-07 1780660 500292032900 Sealed Conductor NA NA 14-08A 2022100 500292033001 Sealed Conductor NA NA 14-098 1820340 500292053402 Sealed Conductor NA NA 14-10 1801300 500292052800 Sealed Conductor NA NA 14-11A 2051260 500292052901 Sealed Conductor NA NA 14-12 1811090 500292063100 Sealed Conductor NA NA t4-13 1811010 500292062400 Sealed Conductor NA NA 14-14 1811020 500292062500 Sealed Conductor NA NA 14-15 1810840 500292061100 Sealed Conductor NA NA t4-16A 1971670 500292060801 Sealed Conductor NA NA 14-17A 2030010 500292056201 Sealed Conductor NA NA 14-186 2071290 500292055102 Sealed Conductor NA NA 14-19 1810450 500292057800 Sealed Conductor NA NA 14-20 1810700 500292059800 Sealed Conductor NA NA 14-21A 2051070 500292075601 Sealed Conductor NA NA 14-22A 1921230 500292074701 Sealed Conductor NA NA 14-23A 2090200 500292075701 NA 4 NA 25.50 10/20/2009 14-24 1830910 500292097000 NA 0.6 NA 3.40 10/20/2009 14-25 1831020 500292098100 NA 2.1 NA 15.30 11/16/2009 14-26 1811100 500292063200 Sealed Conductor NA NA 14-27 1831700 500292104600 NA 3 NA 17.00 10/25/2009 14-28 1820120 500292070800 Sealed Conductor NA NA t4-29 1811680 500292068000 Sealed Conductor NA NA 14-30 2050940 500292067901 Sealed Conductor NA NA t4-3i 1831110 500292098900 Sealed Conductor NA NA 14-32 1831220 500292099900 NA 0.6 NA 3.40 10/19/2009 14-33 1831250 500292100200 Sealed Conductor NA NA 14-34 1831330 500292101000 NA 7.3 NA 47.60 10/20/2009 14-35 1831420 500292101800 Sealed Conductor NA NA t4-36 1831630 500292103900 NA 0.7 NA 3.40 10/20/2009 t4-37 1880490 500292181000 NA 1.3 NA 5.10 10/20/2009 14-38 1881030 500292186200 NA 0.8 NA 3.40 10/24/2009 14-40A 2011350 500292187501 Sealed Conductor NA NA 14-41 1920960 500292229000 NA 0.8 NA 6.80 10/18/2009 14-43 1921080 500292229600 NA 1.4 NA 10.20 10/23/2009 14-44A 2021930 500292257301 NA 10 NA 88.40 11/24/2009 ,~ MEMORANDUM TO: Jim Regg ~~ I~'~•(~~ c P.1. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 23, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14-21 A PRUDHOE BAY UNIT 14-21A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.L Suprv~.l~~'~~- Comm Well Name: PRUDHOE BAY UNIT' 14-21A API Well Number: 50-029-20'756-01-00 Inspector Name: Chuck Scheve lnsp Num: mitCS090922135242 Permit Number: 205-107-0 Inspection Date: 9/21/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ' 14-21A (Type Inj. w TVD ~ 8763 j 560 4000 '• 3980 3980 -" __ __ - - - --- -- P.T.D zosio~o'TypeTest SPT Test psi zl9o OA lso zso 2so zso 4YRTST P Tubing 900 900 900 900 Interval __ .. P/F ---- - ----------- -- -- ~~ - ~ -- Notes: ~iN DE+i ~ ~ 2009 Wednesday, September 23, 2009 Page 1 of 1 . ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUM~ilISSION Mechanical Integrity Test Email to: Winton_Aubert~admin.state.ak.us; Bob Fteckesaslein~d~roi~.stale.ak_us; Jic~ Reg$~~nirs.stade.ak.us; Tom_AAaunder~adminstate.ak.us OPERATOR: BP Explaration (Aiaska} lrtc. FIELD / UNIT t PAD: Prudhce Bay / PBU f DS 'E4 DATE: 09/2i/09 OPERATOR REP: Torin Roschinger AOGCC REP: Ghuck Scheve Paciecs t3epki, Psetest hrifinal 'S5 iJ~s~. ~ tJ~in. Well 14-21A Type Inj. W TYD 8,763" Tubing ~ 900 90d 900 Interval 4 P.T.D. 2051070 Type test P Te.st psi 218t Case 56D 4,0~ 3,980 3,98U P/F P Notes: AOGCC witnessed MITIA for 4yr UIC, pre- Alw OA 15Q 25d 250 250 injection Well Type Inj. TVD Tubirag Interval P.T.D. T test T~ ~rsi ~as6r~g P/F Nates: OA Well Type In'. TVQ Tubing Interval P.T.D. Ty~ test Tesi ~i Casing P/F Notes: OA Well Type Inj. TW T~~ Irderval P.T.D. Type test Test psi G~rtg P!F Notes: OA Well Type Inj. ND Tu~ny Interval P.T.D. Type test Test psi C~irg P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Indushial Wastewater N = Not lnjecting W = Water TYPE TEST ~c~des M = Annulus R~fi~tng P = 5'taruland Pnessure 7est R= In[e~nal Rad'onacPive Trac~ Sutvey A = Temperatur~ Anareaky Suevegr D = Difrererttial Tempevatuae Te~ ( " ` ~~l~a"~ ~~~~~°°;~ ~~ . } ,' ~. ~> ~`~,: .~ ~~~ ~ INTERYAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T =Testduring Workover O = Other (describe in notes) MIT Report Form BFL 9YI t05 RAIT P8U 18-21A 09-21-A9.xls • VY'~LL. f~VV T/"'fA/If5'l t~tl T ~",14L To: AGaGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/ Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 and UT~ ~-/~~ i~iab 1'~l~l ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~ ~, „ 1c-3.0 West International Airport Road - ' ~ b i,,~;~ ' ~~%~`` _ '=~ ~ ~ ~7{.I~.e C .~ s,; Anchorage, AK 99518 Fax; (907) 245-8952 1) Injection Profile 0&May-09 (run 1) 1421 A 2) Injection Profi 1 O-May-09 (run 2) 1421A Signed Print Name: Color Log / EDE 50-029-20756-01 Color Lo 76.01 JUN 0 ~ Z~G9 Date ~ia~k~ qil Gas Cons. ~rruunission gnchora~e PROACTIVE DwriNOS'I'IC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98618 PHONE: (907)246-8961 FAX: (907)245-88952 E-MAIL : pdsanchorage(a~memorvlog.com WEBSITE : vaww.memorvioq com C:\Documents and Settu,gs\Owner\DesktoplTiarismit_BP.docx • WELL LOG TRANSMITTAL To: State of Alaska December 18, 2407 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 14-21A AK-MW-3882536 1 LDWG formatted CD rom with verification listing. API#: 50-029-20756-0 l PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anc . =Ala~ka~ 99 Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~~~~, J AN ~ 2 2008 ~_~ aas-~a~ ~ is~a~- ~~~~~ DATA SUBMITTAL COMPLIANCE REPORT 10/25/2007 Permit to Drill 2051070 Well Name/No. PRUDHOE BAY UNIT 14-21A Operator BP EXPLORATION (ALASKA) INC MD 12339 TVD 9037 Completion Date 8/26/2005 Completion Status WAGIN Current Status WAGIN REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes .~-''° DATA INFORMATION Types Electric or Other Log s Run: MWD DIR / GR / PWD, MWD DIR / GR / RES /AIM, USIT Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No D D Asc Directional Survey D Asc Directional Survey `~'~ Cxw.v~ ~.o~.~' ~ ._. 5 Col 1 f~D C Las 15431 See-Pdotes j,~ 1~,~,,~. ,. Y~. Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 8499 12339 Open 9/26/2005 IIFR 8499 12339 Open 9/26/2005 MWD ` 10500 11500 3/16/2006 USIT/GR/CCL 22-Aug-2005 8120 12339 Open 9/17/2007 LAS GR, ROP w/EMF Graphics Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION {~ Well Cored? Y~ Daily History Received? `u''N Chips Received? Y / N Formation Tops ,~ Analysis .~LL~ Received? Comments: Compliance Reviewed By: API No. 50-029-20756-01-00 Date: 7 Date 09-14-2007 Transmittal Number.92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) [f you have any questions, please contact Douglas Dortch at the YllC at 564-4y /3 u~C Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 06-06B ~ ~~ y2;6 06-06BP61 ~ a~-~~ ~ ~ `~a~- 13-31 A - V~ Cao~ flop ~ ~~2'~ 14-11 A ~~ ~~ ,a6 ~! ~~ 14-11AP61 14-21A u=cao5-ivy ~ ~5 x/31 15-39A aolo-o~~r ~ -Qy3a 16-06Banc,-otil'~ ~sy33 16-14Bc~0(o-0~3 "~5~l3y c-o3B aos- ~s~r ~ ~~s C-10A aas=tam • ~s~a~ J-17C ~ oisa ~ +5`*33 NGI-07A us.eacX.-+a~ j°~ l5~13~f r ji R ~ ^~ lr~ ' Y _~ Please ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 .-s ~, 3~ , 1 °` ,~ rj;e;^~~ ic'tl Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 MEMORANDUM TO: Jim Regg ~~~~ ~~~L~~~ P.I. Supervisor FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Wednesday, September 21, 2005 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 14-21A PRUDHOE BAY UNIT ]4-21A Src: Inspector NON-CONFIDENTIAL .~~d .f Reviewed B~~ P.I. Suprv 'tiIU"n' Comm Well Name: PRUDHOE BAY UNIT 14-21A Insp Num: mitJJ050921085030 Rel Insp Num API Well Number 50-029-20756-O1-00 Permit Number: 205-107-0 Inspector Name: Jeff Jones Inspection Date: 9/20/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 14-21A Type Inj. I TVD 87Cf I IA ~ 1400 2500 2470 ~ 2460 P.T.; 2051070 TypeTest I SPT ~ T2St pSl ', 2191.5 ~~ OA 640 740 j 740 740 ~ Interval INITAL per, P Tubing . 1675 1675 1675 ~ 1675 Notes 1 well house inspected; no exceptions noted. Wednesday, September 21, 2005 Page I of 1 TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR= AXELSON KB. ELEV _ ~~, BF. ELEV - KOP = 2800' Max Angle = Datum MD = Datum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I-I 2517' 8352` -Top of 7" Liner Minimum ID = 3.725" @ 11415' 4-1 /2" XN NIPPLE 4-1/2" TBG, 12.6#, L-80, TGII, ID = 3.958" 11 11428' 8509' 9 5/8" Window 5-1/2" 17#, L-80 tubing cut @ 8700' Top of Cement 11300' 11707' 9-5/8" X 5-112" BKR FB-1 PKR TOP OF 7" LNR 11762' 9-5/8" CSG, 47#, L-80, ID = 8.681" 12036' S~t' NOTES: I 14-21A Final FROM DRLG -DRAFT 12435' 4-1/2" MAGNA PLUG PBTD 13018' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13060' 2217' I~ 4-1/2" X Nipple (3.813" ID} PERFORATION SUMMARY REF LOG ANGLE AT TOP PERF: 47 Degrees Note: Refer to R-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.88 6 11540-11570 Open 08/24/05 2.88 6 11810-11900 Open 08/24/05 2.88 6 11920-12000 Open 08/24!05 2.88 6 12080-12140 Open 08/24/05 2.88 6 12160-12210 Open 08/24/05 DATE REV BY COMMENTS DATE REV 8Y COMMENTS 08/13!82 ORIGINAL COMPLETION 08!25/05 CRM Final Sidetrack Completion 01!25/88 LAST WORKOVER 08/28!05 DMITLH CORRECTIONS 02/22/01 SIS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02/20/03 /TLH WANER SAFETY NOTE 05/26/05 JNC PROPOSED SIDETRACK COMP 11350' ~4 1/2" X Nipple (3.813" ID) 11371' -~x 4 1/2" Baker S3 Packer 11394' 4 1/2" X Nipple (3.813" ID) 11415' 4 1/2" XN Nipple (3.725" ID~ 11426' 4 1/2" Hanger /liner top packer 11428' 4 1/2" WLEG 11536' 7" 26# L-80 BTGM (6.276" ID) _ ., PBTD 12253' 4 1/2" 12.6# L-80 TGII Liner, ID = 3.958" 12339' 11709' S-1/2" BAKERSBEASSY PRUDHOE BAY UNIT WELL: 14-21 A PERMfI' No: 205-107 API No: 50-029-20756-01 SEC 9, T10N, R14E 1562' FEL 2715' FNL BP Exploration (Alaska) U • 22-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 14-21A Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,499.76' MD Window /Kickoff Survey: 8,509.00' MD (if applicable) Projected Survey: 12,339.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~~ Si ned ~atc ~ g Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~vj -to? • U 22-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 14-21A MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,499.76' MD Window /Kickoff Survey: 8,509.00' MD (if applicable) Projected Survey: 12,339.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. ~ / Anchorage, AK 99518 ,~ ~ , Date ~ ~ 5 Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) a~6 ~ -(~~ STATE OF ALASKA ALASIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: x'!/45, .Survey Coron 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Com letions One P Other 1b. Well Class: ^ Development ^ Exploratory ^ Stratigraphic ®Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 8/26/2005 12. Permit to Drill Number 205-107 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 8/16/2005 13. API Number 50-029-20756-01-00 4a. Location of Well (Governmental Section): Surface: 2715' FNL 1562' FEL SEC R 4 7. Date T.D. Reached 8/22/2005 14. WeII Name and Number: PBU 14-21A , , . 09, T10N, 1 E, UM Top of Productive Horizon: 3525' FNL, 1107 FEL, SEC. 16, T10N, R14E, UM g, KB Elevation (ft): 70.76' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 4212' FNL, 795' FEL, SEC. 16, T10N, R14E, UM 9. Plug Back Depth (MD+TVD) 12253 + 9029 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674948 y- 5937618 Zone- ASP4 10. Total Depth (MD+TVD) 12339 + 9037 Ft 16. Property Designation: ADL 028314 _ TPI: x- 675558 y- 5931541 Zone- ASP4 Total Depth: x- 675887 Y- 5930862 Zone- ASP4 11. Depth where SSSV set (Nipple) 2217' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: ~ MWD DIR / GR / PWD, MWD DIR / GR 1 RES /AIM, USIT ~`if/i/L ~%~~ ~~/ ~~~` ~ v'' 2• CASING, LINER AND EMENTING RECORD CASING ETTING EPTH MD ETTING EPTH TVD HOLE OUNT> SIZE WT. PER FT. GRADE OP OTTOM OP ' OTTOM SIZE CEMENTING RECORD PULLED. 20" 91.5# H-40 Surface 111' Surface 111' 30" 350 sx Permafrost II 13-3/8" 72# L-80 Surface 2517' Surface 2517' 17-1/2" 2500 sx Arcticset III, 400 sx AS II 9-5/8" 47# L-80 / S00-9 Surface 8509' Surface 6701' 12-1 /4" 500 sx Class 'G', 300 sx AS I I 7" 26# L-80 8352' 11536' 6602' 8882' 8-1/2" 168 sx Class 'G' 4-1/2" 12.6# L-80 11424' 12339' 8802' 9037' 6-1/8" 144 sx Class 'G' 23. Perforations open to Produc B tt I l Si tion (MD + TV D of Tod and " 24. TusiNG RECORD. o om nterva , ze and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 11428' 11371' MD TVD MD TVD 11540' - 11570' 8884' - 8904' 11810' - 11900' 8982' - 8993' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11920' - 12000' 8994' - 9002' 12080' - 12140' 9009' - 9016' DEPTH INTERVAL MD AMOUNT He KIND OF MATERIAL USED 12160' - 12210' 9019' - 9025' Freeze Protected w/ 151 Bbls of Diesel 26. PRODUCTION TEST Date First Production: September 11, 2005 Method of Operation (Flowing, Gas Lift, etc.): Water Injection Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". S ~Fl~ ~~~~ ~ zoo None Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE ' ~ • 28. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". CM2 8721' 6847' None CM 1 9721' 7569' Top HRZ 10264' 7965' Base HRZ 10500' 8133' LCU /Top JE 10555' 8173' Top JD 10966' 8470' Top JC 11025' 8512' Top JB 11272' 8690' Sag River 11538' 8883' Shublik A 11565' 8901' Shublik B 11595' 8919' Shublik C 11610' 8926' Sadlerochit 11780' 8978' 46P 11810' 8982' 45N 11993' 9001' 45P 12076' 9009' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ Title Technical Assistant Date ~ •p~ • OS PBU 14-21A 205-107 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Jeff Cutler, 564-4134 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only 14-21A, 10-407, BHL Discrepancies Subject: ] ~-? 1:1, 1O-~07, BH I. Discrepancies From: "tiuhble. Ten-ie L" <IIul~bleTL cz BP.com'~ Date: ~~'ed, ~ 1 Sep '00~ 14:07:~7 -i1y00 To: boh t7eckensteinla~.admiri.state.ak.us CC: steti'e d~ivies~r'admin.state.ak.us Hi Bob, I have learned that there was a problem with the loading of the original wells' survey (14-21). Since you brought this to our attention, that problem has been found and corrected. This did cause the Top of Productive, BHL and ND's to calculate incorrectly in our programs for the new sidetrack. The original wells information still seems to be correct. I will recalculate all the locations and ND's for 14-21A and re-submit. Thanks for bringing it to our attention. Terrie Hubble ~r"J ~~ =,~o~ ~_1 1 of 1 9/22/2005 6:45 AM 3 STATE OF ALASKA • ALASKA IL AND GAS CONSERVATION COMM~"SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ®WAG 1b. Well Class: zoAACZS.,os zoAAC2s.,,o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ^ Stratigraphic ®Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 8/26/2005 ~ 205-107 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 8/16/2005 50-029-20756-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 271 ' ' 8/22/2005 PBU 14-21A 5 FNL, 1562 FEL, SEC. 09, T10N, R14E, UM Top of Productive Horizon: g. KB Elevation (ft): 15. Field /Pool(s): 3522' FNL 980' FEL SEC 16 T10N R14E UM 70.76' Prudhoe Bay Field / Prudhoe Bay , , . , , , Pool Total Depth: 9. Plug Back Depth (MD+TVD) 4209' FNL, 669' FEL, SEC. 16, T10N, R14E, UM 12253 + 9033 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) ~c,~`Z' 16. Property Designation: Surface: x- 674948 ~ y- 5937618 'Zone- ASP4 ~ 12339 + "( Ft ADL 028314 TPI: x- 675685 y- 5931547 Zone- ASP4 11. De th where SSSV set t % p q.~' ' 17. Land Use Permit: Total Depth: x- 6 y- 5930868 ~ Zone- ASP4 (Nipple) 2217' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional S e Yes ^ No N/A MSL 1900' (Approx.) ,?.c~ , o 21. Logs Run: ~-~-~~cs~:e~ ~c~9 ~/y)~~ .~7~/' 'TI/~ MWD DIR / GR / PWD, MWD DIR / GR / RES /AIM, USI T //yy +~ y- 2. CASING, LINER AND CEMENTING RECORD CiASING ETTING EPTH MD ETTING D EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE OP _ OTTOM -0P OTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 111' Surface 111' 30" 350 sx Permafrost II 13-3/8" 72# L-80 Surface 2517' Surface 2517' 17-1/2" 2500 sx Arcticset III, 400 sx AS II 9-5/8" 47# L-80 / S00-9 Surface 8509' Surface 6705' 12-1 /4" 500 sx Class 'G', 300 sx AS ll 7" 26# L-80 8352' 11536' 6606' 8886' 8-1 /2" 168 sx Class 'G' 4-1/2" 12.6# L-80 11424' 12339' 8806' 9041' 6-1/8" 144 sx Class 'G' 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter 6 spf 4-1/2", 12.6#, L-80 11428' 11371' MD TVD MD TVD 11540' - 11570' 8889' - 8908' 11810' -11900' 8987 - 8997 2S, ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11920' - 12000' 8999' - 9006' 12080' - 12140' 9014' - 9020' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 12160' - 12210' 9023' - 9029' Freeze Protected w/ 151 Bbls of Diesel 26• PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): September 11, 2005 Water Injection Date of Test Hours Tested PRODUCTION FoR OIL-BBL GAS-McF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED E OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) PreSS. 24-HOUR RAT 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, ff necessary). „ Submit core chips; if none, state none". None S 6~~ SEP - ,--~ i ~~ ~ # ~ ~, ~~~5 " ~ .per Form 10-407 Revised 12/2003 CONTINUED ON REVERSE $IDE ~_,~ ~ ~ i~ ~ L t t 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". CM2 8721' 6851' None CM1 9721' 7574' Top HRZ 10264' 7969' Base HRZ 10500' 8138' LCU /Top JE 10555' ~ 817T Top JD 10966' 8474' Top JC 11025' 8517' Top JB 11272' 8695' Sag River 11538' 8887' Shublik A 11565' 8905' Shublik B 11595' 8923' Shublik C 11610' 8931' Sadlerochit 11780' 8982' 46P 11810' 8987' 45N 11993' 9006' 45P 12076' 9014' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. /,Q. Signed Terrie Hubble ~ Title Technical Assistant Date v -t ~''vS PBU 14-21 A 205-107 Prepared ey Name/Number: Terrie Hubble, 564-4628 Well Number Drilling Engineer: JeffCut/er, 564-4134 Permit No. / A royal No. INSTRUCTIONS GeNew-L: This form is designed for submitting a complete and correct well completion report and log on alt types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Irene 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain), IreM 27: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 8/29/2005 7:28:50 AM BP EXPLORATION Operations Summary Report Page 1 of 6 Legal Well Name: 14-21 Common Well Name: 14-21 Spud Date: 8/16/2005 Event Name: REENTER+COMPLETE Start: 8/12/2005 End: 8/26/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/26/2005 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To I Hours ~ Task ~, Code ~ NPT ~ Phase Description of Operations - - - 8/12/2005 12:00 - 00:00 I 12.001 MOB P !PRE Move rig from well # 14-30 to 14-21. Move was around the 8/13/2005 00:00 - 00:30 ~ 0.501 W HSUR P 00:30 - 01:00 I 0.501 WHSUR I P 01:00 - 02:00 1.00 WHSUR' P 02:00 - 02:30 0.50 WHSUR P 02:30 - 05:00 2.50 WHSUR P - 0.00 WHSUR P 05:00 - 06:00 ', 1.001 WHSUR i P 06:00 - 08:30 I 2.501 WHSUR I P 08:30-11:30 3.00 WHSUR P 11:30 - 17:30 6.00 WHSUR P 17:30 - 00:00 I 6.501 W HSUR I N 8/14/2005 00:00 - 00:30 0.50 WHSUR N 00:30 - 03:00 2.50 WHSUR P 03:00 - 04:00 I 1.001 WHSUR I P 04:00 - 04:30 I 0.501 PULL I P 04:30 - 05:00 I 0.501 PULL I P 05:00 - 06:00 I 1.001 PULL . P 06:00 - 08:30 2.50 PULL P 08:30 - 09:00 0.50 PULL P 09:00 - 15:00 6.00 PULL P 15:00 - 17:00 ( 2.001 WHSUR I P reserve pit. Bridle up, lower pipe shed chute, pull pins and UD derrick. Move to next location & spot rig. Raise derrick & pin, unbridal and hang lines. Raise pipe shed chute. Spot shop, camp and pits. R/U floor. Hook up interconnect lines. Rig accepted @ 00:01 hrs, 8/13/2005. Held pre-spud meeting with drill crew, Toolpusher &WSL. DECOMP Rig accepted ~ 00:01 hrs 8/13/2005. Held pre-spud meeting with drill crew, tool pusher &WSL. DECOMP Install secondary annulus valve. Inner and nutter annulus = 0 psi. DECOMP R/U DSM lubricator and pull BPV. DECOMP R/U circ lines & test to 4000 psi. DECOMP Reverse circ 60 bbl seawater and displace diesel from tubing. DECOMP Pump soap pill and hot seawater, pump 590 bbl @ 9 bpm C~ 970 psi to displace well to clean seawater. Verify well is dead. Tubing & annular pressure = 0. DECOMP R/U DSM lubricator & set TWC valve, test to 1000 psi. Check for flow. DECOMP N/D tree and adaptor flange. Function LDS. Verify tubing hanger lift threads are 5 7!8" right hand Acme. Install tree test plug. DECOMP N/U 13 5/8" BOPE. DECOMP Test ROPE to 4000 psi high test & 250 psi low test. Test top drive, choke manifold, and all related valves & Iines.Top pipe rams (3.5" X 6") and annular preventor failed. Witness of test waived by AOGCC Rep. Chuck Scheve. Test witnessed by WSL Bill Decker &Toolpusher Cleve Coyne. DECOMP R/D test equipment, change top rams. Remove bell nipple and replace packing unit in annular preventor. DECOMP Install bell nipple & turn buckets on BOPE. DECOMP R/U & test BOPE, top rams to 250 low pressure & 4000 high. Test annular preventor to 250 low & 3500 psi high using 5.5" landing jt. Witness of test waived by AOGCC Rep. Chuck Scheve. Test witnessed by WSL James Willingham. DECOMP R/U DSM lubricator & pull test dart &TWC valve. R/U Camco control line spooler. DECOMP M/U 5 7/8" RH Acme XO to Jt of 5" DP. BOLDS. Run in and screw into hanger (12 1/2 turns). M/U top drive. Pull 5 1/2" tubing free with 175 K. Pull hanger to floor. String wt 145K w1 TD & blocks. DECOMP CBU @ 12 BPM - 370 psi. Seawater clean. Shut down, monitor well -static. DECOMP Break out & UD tubing hanger. POH w/ 5 1/2" tubing, spooling up control line. DECOMP POH UD 5.5" tubing from 8700' to 6522'. DECOMP R/D control line spooler. UD tools. DECOMP POH UD 5.5" tubing. Retreive 49 SS bands, 4 GLM, 1 SSSV, 208 Jts tubing & 1 cut joint. R/D running tools & clean rig floor. DECOMP M/U test joint, set test plug. Test top rams 3.5" X 6" & bottom rams 2 7/8" x 5" to 250 psi low pressure & 4000 high. Test annular preventor to 250 low & 3500 high with 5 "test joint. Test witnessed by WSL Bill Decker. Install wear bushing. Printed: 8/29/2005 7:28:58 AM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 14-21 14-21 Spud Date: 8/16/2005 REENTER+COMPLETE Start: 8/12/2005 End: 8/26/2005 NABOBS ALASKA DRILLING I Rig Release: 8/26/2005 NABOBS 2ES Rig Number: Date ~ From - To Hours Task ', Code 8/14/2005 ~ 17:00 - 23:00 6.00 DHB P 23:00 - 00:00 I 1.001 PULL I N 8/15/2005 ~ 00:00 - 03:00 ~ 3.00 ~ STW H I P ~ P 03:00 - 04:00 1.00 STWHIP P 04:00 - 06:00 2.00 STWHIP P 06:00 - 14:00 8.00 STWHIP P 14:00 - 14:30 0.50 STWHIP P 14:30 - 15:30 1.00 STWHIP P 15:30 - 16:30 I 1.001 STWHIPI P 16:30 - 22:00 ! 5.501 STWHIPI P 22:00 - 23:00 1.00 STWHIP P 23:00 - 23:30 0.50 STWHIP P 23:30 - 00:00 0.50 STWHIP P 8/16/2005 00:00 - 00:30 0.50 STWHIP P 00:30 - 04:00 3.50 STWHIP P 04:00 - 06:00 2.00 STWHIP P 06:00 - 08:00 2.00 STWHIP P 08:00 - 10:00 2.00 STWHIP P 10:00 - 12:30 2.50 STWHIP P 12:30 - 13:00 0.50 STWHIP P 13:00 - 15:00 2.00 STWHIP P 15:00 - 00:00 I 9.00) DRILL I P 8/17/2005 100:00 - 13:30 I 13.501 DRILL I P 13:30 - 14:30 1.001 DRILL P 14:30 - 15:30 1.00 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 17:00 1.00 DRILL P 17:00 - 21:00 4.00 DRILL P 21:00 - 23:00 I 2.001 DRILL I P NPT ' Phase Description of Operations DECOMP R/U SWS, RIH with GR/JB to top of 5.5" tubing stump @ 8685' WLM. POH logging up. Recovered 1 SS band in JB. M/U EZSV, GR/CCL. RIH. Set EZSV @ 8522'. POH & RID SWS. SFAL DECOMP Test casing to 4000 psi. Leak on inner annulus valve. Call DSM to set V.R. plug & replace valve. ' WEXIT P/U whipstock BHA, orient, upload, shallow test C~ 500 gpm 600 psi. ~ W EXIT Test casing to 4000 psi for 30 min, OK. ' WEXIT P/U BHA, drill collars &HWDP, P/U BHA to 1031 . RIH running speed = 34-40 sec per jt. WEXIT RIH P/U drill pipe. Fill pipe @ 3000' intervals. WEXIT Service top drive. WEXIT Orient whipstock 84 degrees left. Set bottom anchor @ 8531' with 20K down weight. Pull up 10K to check, set 45K down to ~ shear off of whipstock. ; WEXIT Displace well to 9.0 ppg LSND mud. Pump ~ 510 gpm 1330 psi. WEXIT Mill window in 9 5/8" 47#, casing. Window top @ 8509', bottom 8525'. Milled formation to 8,537'. HWT = 195K, SWT = 155K, RWT = 175K. Pump @ 442 gpm @ 1100 psi. Torque off btm = 6-7K, on btm = 7-12K. Recovered 160 # of metal cuttings. WEXIT Pump super sweep, CBU C~ 515 gpm C~3 1340 psi. WEXIT Perform FIT test with 9.0 ppg mud. Leaked off to formation 1120 psi, shut down pump & close in, pressure bled off to 1000 psi and stablized. Pumped 3.8 bbi and got 2 bbl back when bled off. LOT = 12.21 ppg. EMW. Monitor well. Pump dry job. WEXIT Cut & slip drill line. WEXIT Cut & slip drill line. Check brakes. WEXIT Remove top drive blower hose. POH from 8487' to 1031'. WEXIT POH, L/D drill collars & whipstock assy. Mills full gage. WEXIT Service wear ring. Flush out stack and all surface equipment. WEXIT MU Drilling BHA -orient tools. RIH w/ HWDP. Shallow test MWD tools. WEXIT RIH picking up 5" DP. Break circ every 3,000'. WEXIT Service top drive. WEXIT RIH to 8,465'. Base line ECD tests -Orient 85 L -slide through window @ 8,509' to bottom ~ 8,537'. LNR1 Dir. Drill from 8,537' to 9,200'. AST 2.16 hrs, ART 4.44 hrs, UP 200K, DN 150K, RT 175k, TO Off 7.5K, TQ ON 10k, RPM 80. ECD = 10.45 ppg. LNR1 Dir. Drill from 9,200' - 10,169'. UP 220K, DN 160k, RT 190K, TO ON 10K, TO OFF 7K, 504 GPM @ OFF 1,890 psi, ON 2,430 psi. RPM 75, ROP 140 / 240 fph. ECD = 10.2 ppg. LNR1 Pump hi vis sweep around and circ hole clean - 500 gpm - 1600 psi -flow check. LNR1 Short trip to 9 5!8" window @ 8,509'. No problems. Flow check. LNR1 Service top drive. LNR1 RIH f/ 8,509' to 10,t69'. No problems. LNR1 Start raising mud wt. to 11.0 ppg @ 10,169'. Dir. Drill from 10,169' to '. 10,462'. ECD's = 12.25 ppg. LNR1 Condion mud to 11.0 ppg and mix Resinex / soltex. ECD = 11.9 ppg. Printed: 8/29/2005 7:28:58 AM BP EXPLORATION Operations Summary Report Legal Well Name: 14-21 Common Well Name: 14-21 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To -Hours Task ~ Code NPT ~' _ I 8/17/2005 23:00 - 00:00 1.00 DRILL I P Start: 8/12/2005 Rig Release: 8/26/2005 Rig Number: Phase LNR1 8/18/2005 100:00 - 18:00 I 18.001 DRILL I P I I LNR1 18:00 - 19:00 ~ 1.001 DRILL P LNR1 19:00 - 20:30 ~ 1.50 ~ DRILL ~ P ~ ~ LNR1 20:30 - 22:00 1 1.501 DRILL I P I I LNR1 22:00 - 00:00 2.00 DRILL P LNR1 8/19/2005 00:00 - 02:30 2.50 DRILL P LNR1 02:30 - 03:00 0.50 DRILL P LNR1 03:00 - 04:30 1.50 DRILL P LNR1 04:30 - 07:00 I 2.501 DRILL I P 07:00 - 10:30 3.50 DRILL P 10:30 - 12:00 1.50 DRILL P 12:00 - 15:00 3.00 DRILL P 15:00 - 16:00 1.00 CASE P 16:00 - 19:30 3.50 CASE P 19:30 - 20:00 0.50 i CASE P 20:00 - 23:30 3.50 CASE P 23:30 - 00:00 0.50 CASE P 8/20/2005 00:00 - 00:30 0.50 CASE P 00:30 - 02:00 1.50 CASE P 02:00 - 02:30 0.50 CASE P 02:30 - 04:30 I 2.001 CASE I P 04:30 - 07:00 I 2.501 CEMT I P LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 LNR1 07:00 - 08:00 1.00 CEMT P LNR1 08:00 - 08:30 0.50 CEMT P LNR1 08:30 - 10:00 1.50 CEMT P LNR1 10:00 - 14:30 4.50 CEMT P LNR1 14:30 - 15:30 1.00 CEMT P ~ LNR1 15:30 - 16:00 0.50 DRILL P PROD1 16:00 - 19:00 3.00 DRILL P i PROD1 19:00 - 21:30 I 2.501 DRILL I P I I PROD1 Page 3 of 6 Spud Date: 8/16/2005 End: 8/26/2005 Description of Operations Dir. Drlg from 10,462' to 10,520'. AST 2.65 hrs, ART 10.55 hrs, UP 225K, DN 160K, ROT 190K, TO OFF 8k, TO ON tOK, ECD = 11.93 ppg, 550 gpm @ 2,050 psi / 2,300 psi. Dir. Drill from 10,520' to 11496'. UP 245K, DN 170K, RT 200K, TO off 9K, TO ON 11 K, 500 gpm @ 2,320 OFF , 2,530 On, 75 RPM, ECD = 11.75 ppg. POOH to 11,390' -Mad Pass log f/ 11,390' to 11,330'. RIH to 11,496'. Drill from 11,496' to 11,536' TD. UP 255K, DN 170K,RT 205K, TO 11.5K on, TO 9K OFF. ECD = 11.75 ppg. Circ for samples for geologist. Pump hi vis weep aroud and circ clean. Final ECD 11.55 ppg. Monitor well for flow. POOH f/to 8,540'. No problems. Mad pass log f/ 8,540' to 8,150' - 200 fph. Service top drive. RIH to 11, 496'. Stage pumps up to 500 gpm and wash 40' to bottom. No fill. No problems. Pump hi vis sweep around, circ hole clean, and cond mud 500 gpm 2,300 psi, RPM 75. Monitor well. UP 260k, DN 180K - no pumps.Spot liner running pill. Flow check. Slug DP. Drop 2 3/8' O.D. rabbit. POOH to 3,356'. No problems. POOH laying down 5" DP. L.D. 8.5" BHA -Download LWD's. Clear rig floor. PJSM with all personel. RU handling tools for 7" csg. Run 76 jts 7" 26# L80 BTC-M liner. MU Baker liner hanger /packer. RIH w/ 1 stand DP. Liner WT 70k. Circ liner vol. UP 100k , DN 100K. RIH w/ 7" liner on DP to 8,473'.. Fill DP every 10 stds. Circ liner / DP volume @ 5 BPM - 420 psi. UP 170K, DN 140k. Circ and clear liner ~ 8,473'. UP170k, DN 140K. Run 7" liner on DP f/ 8,473' to 11, 516'. Fill on fty. No problems. MU cementing head. Break circ 1 BPM - 360 psi. Tag btm @ 11,536'. PU 1'to 11,535'. Stage pumps up to 5 BPM - 725 psi. PJSM. Circ and cond mud and hole for cement job. Batch up cement. Test lines to 4,500 psi. Dowell cemented -pumped 32 bbls mud push II spacer @ 12.0 ppg, 35 bbls CI "G" cement@ 15.8 ppg. Washed out pump and lines and dropped plug. Displaced w/ 267 bbls 11.0 ppg mud C~? 5 BPM. Plug did not bump. Set liner on btm w/ 80k -Checked floats -held. Released from hanger. Press to 1,000 psi and pulled out of liner. Pumped 550 stks ~ 220 spm. Set liner top packer. CIP @ 0640 hrs. TOL C~3 8,351'. CBU 12 BPM @ 2,000 psi - no cement to surface. Slug DP -blow down suface equipment. Cut drilling line, inspect brakes, service top drive. POOH w! 5° DP - LD pups and running tool. Clear floor. Test 7" liner to 4,000 psi for 30 min. Held. PJSM. P.U. BHA tools to rig floor. M.U. 6 1/8" drilling BHA. Orient. Load MWD tools. RIH to 353'. Shallow test MWD. P/U 4" drill pipe from 353' - 4092'. Change elevators. Printed: 8/29/2005 7:28:58 AM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date '~ From - To I 14-21 14-21 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS2ES Hours , Task (Code' NPT I 8/20/2005 21:30 - 00:00 2.50 DRILL P 8/21/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 01:30 1.00 DRILL P 01:30 - 04:00 V 2.501 DRILL f P 04:00 - 06:30 I 2.501 DRILL I P 06:30 - 07:30 I 1.001 DRILL I P 07:30 - 08:00 I 0.501 DRILL I P 08:00 - 00:00 I 16.001 DRILL I P 8/22/2005 00:00 - 08:00 8.00 ~ DRILL P 08:00 - 10:00 2.00 DRILL P 10:00 - 10:30 0.50 DRILL P 10:30 - 11:00 0.50 DRILL P 11:00 - 11:30 0.50 DRILt P 11:30 - 12:30 1.00 DRILL P 12:30 - 13:00 0.50 DRILL P 13:00 - 14:00 1.00 DRILL P 14:00 - 18:00 4.00 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 19:30 1.00 DRILL N 19:30 - 22:00 2.50 DRILL P 22:00 - 23:00 1.00 EVAL P 23:00 - 00:00 1.00 EVAL P 8/23/2005 00:00 - 03:30 3.50 EVAL P 03:30 - 04:30 1.00 CASE P 04:30 - 07:00 2.50 CASE P 07:00 - 07:30 0.50 CASE P 07:30 - 13:00 5.50 CASE P 13:00 - 14:00 1.00 CASE P 14:00 - 14:30 0.50 CASE P 14:30 - 15:00 0.50 CASE P 15:00 - 16:30 1.50 ~ CASE P 16:30 - 18:00 I 1.501 CEMT I P Start: 8/12/2005 Rig Release: 8/26/2005 Rig Number: Page 4 of 6 Spud Date: 8/16/2005 End: 8/26/2005 Phase I Description of Operations PRODi RIH f/ 4092' - 9292'. Break circ every 3000' PROD1 Service top drive. PROD1 RIH to 11,450'. Break circ and wash down and tag plugs @ 11,479'. UP 215K, DN 160K. PRODi Drill plugs /landing collar @ 11,479', F.C. @ 11,492', and soft cement to 11,535'. 250 gpm - 1900 psi. PROD1 Displace well with 8.4 ppg Flow pro mud -pumped 100 bbls water and 45 bbl hi vis sweep ahead of new mud - 250 / 300 gpm - 1,500 psi. PROD1 Drill out shoe and 20' new hole to 11,556'.Up 210, DN 175k, 300 gpm @ 1,500 psi. Circ 15 min. PROD1 Perform FIT w/ 8.4 ppg mud @ 11,556' to 10.0 ppg EMW. TVD 8,881' - 740 psi. PROD1 Dir. Drill from 11,556' to 12,035 '. AST 8.66 hrs, ART 4.04 hrs.UP 220k, DN 165K, RT 190K. TO OFF 8K, TO ON 10.5 K. 300 gpm @ 1,900 psi. PROD1 Dir. Drill from 12,035' to 12,339 '. UP 220K, DN 165K, RT 190K, TO OFF 9K, TO ON 11 K, RPM 40, 300 gpm @ 1,650 psi / 1,970'. PRODi Circ hi-vis sweep around - 300 gpm@ 1,725 psi. PROD1 POOH to 11,506'. 240K up. No problsems. PROD1 Service top drive. PROD1 RIH to 12,339'. No problems. PROD1 Circ hi-sweep up into 7" csg. Spot 33 bbl liner running pill in open hole. 300 gpm @ 1,750 psi. Monitor well -static. PROD1 POOH to 11,536'. No problems. Monitor well -static. PROD1 Drop dart. Open circ sub. CBU @ 11,536'. 13 BPM 1,550 psi. Monitor well. Static. Slug DP. PRODi POOH w/ D. P. PROD1 L.D. BHA. PROD1 Repair skate. PROD1 L.D. BHA. Download LWD's. Break bit - L.D. motor. Clear rig floor. RUNPRD PJSM. RU Schlumberger W.L. RUNPRD Run USIT log f/ 11,500' - RUNPRD SWS ran USIT log f/ 11,500' - 8,300'. TOC @ 9,400'. Good cement f/ 10,900' to 9,830'. POOH w/ USIT tool. R.D. Schlumberger. RUNPRD R.U. to run 4.5" liner. PJSM. RUNPRD RIH picking up 21 jts 4.5" 12.6# L80 TCII liner. M.U. liner hanger /packer and 1 std D. P. Up 40K, DN 40K. RUNPRD Pump liner volume @ 3 BPM 120 psi. Clear rig floor. RUNPRD RIH w/ 4.5" liner on DP to 11,536'. Break circ every 10 stds. RUNPRD Circ DP l liner volume 6 BPM @ 660 psi. RUNPRD RIH with liner on DP to 12,321'. No problems. RUNPRD M.U. cementing head, manifold, and hoses. RUNPRD Break circ and wash liner to bottom @ 12,339'. Stage pumps up to 6 BPM @ 950 psi. Circ and cond mud and hole for cement job.Recipicate pipe. PJSM. Batch up cement. UP 225k, DN 165k. RUNPRD Dowell cemented. Pumped 5 bbls water. Tested lines to 4,500 psi. Pumped 5 bbls CW100, 20 bbls Mud push II spacer @ 9.5 ppg, 30 bbls CI "G" cement @ 15.8 ppg. Washed out pump Printed: 8/29/2005 7:28:58 AM BP EXPLORATION Operations Summary Report Page 5 of 6 Legal Well Name: 14-21 Common Well Name: 14-21 Spud Date: 8/16/2005 Event Name: REENTER+COMPLETE Start: 8/12/2005 End: 8/26/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 8/26/2005 Rig Name: NABOBS 2ES Rig Number: Date I From - To ,Hours ' Task I Code NPT ' Phase I~, Description of Operations 8/23/2005 16:30 - 18:00 1.50 CEMT P 18:00 - 19:00 I 1.001 CEMT I P 19:00 - 19:30 0.50 CEMT P 19:30 - 21:00 1.50 CEMT P 21:00 - 22:00 1.00 CEMT P 22:00 - 00:00 2.00 CEMT P 8/24/2005 00:00 - 02:30 2.50 CEMT P 02:30 - 03:30 1.00 CASE P 03:30 - 04:30 1.00 PERFO P 04:30 - 06:00 1.50 ~ PERFO P 06:00 - 11:30 I 5.50 IiI PERFOBI P 11:30 - 12:00 0.50 PERFO~ P 12:00 - 13:00 1.00 PERFO P 13:00 - 20:30 7.50 PERFO P 20:30 - 21:30 1.00 PERFO P 21:30 - 00:00 2.50 PERFO P 8/25/2005 00:00 - 01:30 1.50 PERFO P 01:30 - 02:30 1.00 PERFO P 02:30 - 03:00 0.50 P 03:00 - 04:00 1.00 PERFO P 04:00 - 05:30 1.50 BUNCO 05:30 - 17:30 I 12.00 17:30 - 18:00 0.50 RUN 18:00 - 18:30 0.50 RUN 18:30 - 20:30 2.00 RUN 20:30 - 21:00 0.50 RU 21:00 - 00:00 3.00 RU 8/26/2005 00:00 - 01:00 1.00 BUNCO 01:00 - 02:00 1.00 BOPSU P 02:00 - 04:00 2.00 BOPSU P 04:00 - 06:00 2.00 WHSUR P 06:00 - 07:00 1.00 WHSUR P 07:00 - 08:30 1.50 WHSUR P 08:30 - 10:30 2.00 WHSUR P 10:30 - 12:00 I 1.50! WHSUR I P 12:00 - 13:00 I 1.001 W HSUR I P RUNPRD and lines. Dropped plug. Displaced with 20 bbl pert pill and 160 bbls mud C~3 6 BPM. Recipicated pipe. Full returns. Bumped plug to 3,500 psi. and set liner hanger. CIP C~3 1745 hrs. Floats held. RUNPRD Released running tool and stung out of liner w/ 1,000 psi.Pumped 30 bbls. Set liner top packer. CBU @ 12 BPM 1,850 psi. Circ out 15 bbls cement. RUNPRD L.D. cementing head. Pull 1 stand of DP. RUNPRD Displace well to 8.5 ppg seawater @ 11,330. 12 BPM C~3 1,550 psi. recipicate pipe. RUNPRD Cut drilling line. RUNPRD POOH with running tool. RUNPRD POOH. L.D running tool. Clear floor RUNPRD Close blind rams. Test 4.5" liner to 4,000 psi for 30 min. Held. OTHCMP PJSM. RU handling tools for 2 7/8" DPC pert guns. OTHCMP PU 2 7/8" DPC perf gun and firieing head. PU 7jts 2 7/8" PAC DP. OTHCMP RIH -tag landing collar C~ 12,253'. Pull up and spot btm shot C~ 12,210'. OTHCMP Break circ. Pressure up in segence to 1200 psi -guns fired. OTHCMP POOH to 11,462' - 78' above top shot. Monitor well. Static. Slug DP. OTHCMP POOH w/ pert guns laying down DP. OTHCMP R.U. 2 7/8" handling tools. L.D. 2 7/8" PAC DP. OTHCMP PJSM. L.D. 2 7/8" pert guns. OTHCMP L.D. pert guns. All guns fired. OTHCMP R.D. 2 7/8" handling tools. Clean and clear rig floor. OTHCMP M.U. mule shoe sub. RIH w/ 17 stds 5" DP. OTHCMP POOH laying down DP. Pull wear ring. RUNCMP M.U. landing jt xo's on DP. R.U. to run 4.5" TC II tubing !torque turn. PJSM RUNCMP Run 4.5" completion - M.U. tail pipe assembly /packer -RIH picking up 4.5" 12.6# L80 TC-II tbg to 10,832'. Tq turn connecitons. RUNCMP Lubricate rig. Service top drive. RUNCMP RIH picking up 4.5" tbg. Tagged up @ 11,437'. RUNCMP Space out tubing - M.U. pups and tubing hanger. UP 145K, DN 115K. Land hanger. RILDS. RUNCMP R.U. lines to circ. Test to 1,000 psi. RUNCMP Reverse circ 150 bbls clean sea water, 420 bbls treated sea water C~3 3 BPM 160 psi. RUNCMP Reverse circ treated sea water. RUNCMP Set BPV and dart. Test to 1,000 psi from top. RUNCMP ND BOP's. RUNCMP N.U. 13 5/8" 5M x 7 1/16" 5M tbg head adaptor and 5 1/8" 5M tree. RUNCMP Test adsptor flange and tree to 5,000 psi. RUNCMP Pull test dart. Pull BPV w/ lubricator. RUNCMP R.U. circ Iines.R.U. Hot Oil Truck. Test lines to 4,000 psi. Swab valve pressure locked on test. Bled off. RUNCMP Freeze protect Tbg /Ann. Pumped 151 bbls diesel down annulus C~3 2 BPM 175 psi. RUNCMP U-Tube diesel. Printed: 8/29/2005 7:28:58 AM Printed: 8/29/2005 7:28:58 AM Halliburton Sperry-Sun North Slope Alaska BPXA 14-21A Job No. AKZZ3882536, Surveyed: 22 August 2005 Survey Report 14 September, 2005 Your Ref.• AP1500292075602 Surface Coordinates: 5937618.44 N, 674948.17E (70° 14' 06.9014" N, 148° 35' 14.8639" V-/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 70.76ft above Mean Sea Level Sergi-~r~..SUI'"t ~~~~~-r~~ ~~~'~~~~~ Survey Ref: svy4659 A Hailiburtan Carrspany i Halliburton Sperry-Sun Survey Report for 14-21A Your Ref.• API 500292075602 Job No. AKZZ3882536, Surveyed: 22 August, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 8499.76 51. 230 177.090 6624.23 6694.99 3989.44 S 314.30 E - 8509.00 51. 310 177.110 6630.01 6700.77 - 3996.63 S 314.67 E 8602.47 46. 860 176.520 6691.21 6761.97 4067.14 S 318.58 E 8697.40 42. 590 175.830 6758.64 6829.40 4133.78 S 323.02 E 8792.04 41. 740 175.980 6828.79 6899.55 4197.15 S 327.56 E 8887.42 43. 340 177.070 6899.07 6969.83 4261.51 S 331.46 E 8982.00 44. 380 176.600 6967.26 7038.02 4326.94 S 335.08 E 9076.39 43. 520 177.200 7035.22 7105.98 4392.36 S 338.62 E 9170.90 43. 910 177.890 7103.53 7174.29 4457.61 S 341.42 E 9265.61 44. 660 178.760 7171.33 7242.09 4523.71 S 343.35 E 9359.49 44. 360 176.130 7238.28 7309.04 4589.44 S 346.28 E 9454.78 43. 560 176.310 7306.87 7377.63 4655.45 S 350.64 E 9549.06 43. 800 176.000 7375.06 7445.82 4720.41 S 355.01 E 9643.22 44. 470 175.740 7442.64 7513.40 4785.81 S 359.73 E 9738.60 42. 980 175.460 7511.56 7582.32 4851.54 S 364.78 E Global Coordinates Northings Eastings (ft) (ft) 5933637.37 N 675354.94 E 5933630.18 N 675355.47 E 5933559.78 N 675361.02 E 5933493.27 N 675367.00 E 5933430.02 N 675373.01 E 5933365.77 N 675378.40 E 5933300.43 N 675383.54 E 5933235.12 N 675388.60 E 5933169.95 N 675392.91 E 5933103.92 N 675396.37 E 5933038.27 N 675400.83 E 5932972.38 N 675406.72 E 5932907.54 N 675412.59 E 5932842.26 N 675418.83 E 5932776.67 N 675425.41 E Dogleg Vertical BPXA Rate Section Comment (°I100ft) 3998.83 Tie On Point M W D+I I FR+MS 0.882 4006.03 Window Point 4.785 4076.51 4.527 4143.21 0.904 4206.67 1.847 4271.05 1.152 4336.46 1.012 4401.84 0.652 4466.97 1.019 4532.84 1.990 4598.47 0.850 4664.53 0.341 4729.56 0.737 4795.06 1.575 4860.93 9833. 46 41. 980 174. 490 7581. 52 7652. 28 4915 .35 S 370. 39E 5932713.00 N 675432. 49E 1.260 4924.96 9929. 32 41. 590 174. 760 7653. 00 7723. 76 4978 .95 S 376. 37E 5932649.56 N 675439. 95E 0.448 4988.82 10024. 44 44. 470 173. 910 7722. 53 7793. 29 5043 .53 S 382. 79E 5932585.15 N 675447. 87E 3.088 5053.71 10117. 80 44. 940 174. 210 7788. 88 7859. 64 5108 .85 S 389. 59E 5932520.00 N 675456. 18E 0.552 5119.38 10214. 54 43. 010 173. 050 7858. 50 7929. 26 5175 .60 S 397. 03E 5932453.44 N 675465. 16E 2.162 5186.54 10308. 85 45. 100 174. 580 7926. 27 7997. 03 5240 .79 S 404. 08E 5932388.43 N 675473. 72E 2.487 5252.11 10403. 95 44. 510 173. 990 7993. 75 8064. 51 5307 .48 S 410. 75E 5932321.92 N 675481. 94E 0.759 5319.11 10498. 90 44. 060 173. 580 8061. 72 8132. 48 5373 .38 S 417. 92E 5932256.20 N 675490. 64E 0.562 5385.41 10594. 33 43. 630 174. 120 8130. 54 8201. 30 5439 .11 S 425. 01E 5932190.66 N 675499. 25E 0.597 5451.51 10688. 98 44. 310 175. 640 8198. 67 8269. 43 5504 .55 S 430. 87E 5932125.36 N 675506. 62E 1.326 5517.19 10782. 70 43. 670 175. 510 8266. 09 8336. 85 5569 .45 S 435. 89E 5932060.60 N 675513. 15E 0.690 5582.23 10877. 33 43. 750 176. 290 8334. 50 8405. 26 5634 .67 S 440. 56E 5931995.50 N 675519. 34E 0.576 5647.55 10971. 40 43. 130 176. 690 8402. 80 8473. 56 5699 .23 S 444. 52E 5931931.05 N 675524. 79E 0.721 5712.14 11066. 80 44. 450 176. 340 8471. 67 8542. 43 5765 .13 S 448. 54E 5931865.27 N 675530. 34E 1.407 5778.05 11161. 88 43. 950 177. 090 8539. 83 8610. 59 5831 .30 S 452. 34E 5931799.20 N 675535. 67E 0.761 5844.21 11257. 00 43. 350 176. 640 8608. 66 8679. 42 5896 .86 S 455. 93E 5931733.74 N 675540. 78E 0.710 5909.74 11350. 81 42. 420 176. 560 8677. 39 8748. 15 5960 .59 S 459. 72E 5931670.12 N 675546. 04E 0.993 5973.48 11445. 89 44. 130 176. 020 8746. 62 8817. 38 6025 .63 S 463. 94E 5931605.20 N 675551. 77E 1.840 6038.56 11485. 69 44. 250 176. 020 8775. 15 8845. 91 6053 .30 S 465. 86E 5931577.57 N 675554. 34E 0.302 6066.27 11533. 73 45. 380 175. 160 8809. 23 8879. 99 6087 .06 S 468. 47E 5931543.89 N 675557. 73E 2.669 6100.10 i r~ ~J 14 September, 2005 - 10:27 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 14-21A Your Ref.• API 500292075602 Job No. AKZZ3882536, Surveyed: 22 August, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coord inates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 11565.77 51.210 173.620 8830.54 8901.30 6110.85 S 470.82E 5931520.15 N 675560.63E 18.545 6124.01 11599.90 57.520 173.050 8850.41 8921.17 6138.39 S 474.04E 5931492.70 N 675564.49E 18.538 6151.73 11628.66 62.980 172.230 8864.68 8935.44 6163.14 S 477.25E 5931468.03 N 675568.27E 19.145 6176.69 11661.15 68.260 170.350 8878.09 8948.85 6192.38 S 481.74E 5931438.90 N 675573.44E 17.083 6206.25 11694.63 73.870 171.450 8888.95 8959.71 6223.64 S 486.74E 5931407.77 N 675579.16E 17.042 6237.88 11723.15 77.250 172.040 8896.06 8966.82 6250.97 S 490.70E 5931380.54 N 675583.76E 12.019 6265.49 • 11754.71 79.580 172.430 8902.40 8973.16 6281.60 S 494.88E 5931350.01 N 675588.64E 7.481 6296.40 11789.21 80.830 168.860 8908.27 8979.03 6315.14 S 500.40E 5931316.61 N 675594.95E 10.821 6330.35 11821.01 81.700 165.260 8913.10 8983.86 6345.76 S 507.44E 5931286.16 N 675602.69E 11.519 6361.59 11851.83 83.570 162.850 8917.05 8987.81 6375.15 S 515.84E 5931256.97 N 675611.77E 9.846 6391.76 11884.44 84.620 159.130 8920.41 8991.17 6405.81 S 526.40E 5931226.56 N 675623.04E 11.795 6423.44 11913.64 85.180 156.660 8923.00 8993.76 6432.76 S 537.35E 5931199.88 N 675634.61E 8.641 6451.48 11946.39 85.310 153.670 8925.72 8996.48 6462.37 S 551.05E 5931170.59 N 675649.00E 9.107 6482.49 11979.40 83.450 151.850 8928.95 8999.71 6491.58 S 566.09E 5931141.74 N 675664.71E 7.865 6513.26 12008.15 83.570 149.370 8932.20 9002.96 6516.46 S 580.11E 5931117.19 N 675679.30E 8.581 6539.61 12040.77 84.750 145.730 8935.52 9006.28 6543.84 S 597.52E 5931090.22 N 675697.34E 11.675 6568.84 12071.55 85.800 142.570 8938.06 9008.82 6568.70 S 615.48E 5931065.78 N 675715.88E 10.785 6595.62 12102.32 84.680 139.280 8940.61 9011.37 6592.50 S 634.80E 5931042.44 N 675735.75E 11.260 6621.52 12134.32 82.010 139.350 8944.32 9015.08 6616.60 S 655.52E 5931018.82 N 675757.02E 8.347 6647.88 12168.74 82.010 141.070 8949.10 9019.86 6642.80 S 677.34E 5930993.15 N 675779.43E 4.949 6676.44 12196.81 84.190 141.440 8952.48 9023.24 6664.53 S 694.78E 5930971.82 N 675797.37E 7.876 6700.06 12291.60 84.680 143.460 8961.67 9032.43 6739.32 S 752.27E 5930898.38 N 675856.59E 2.183 6781.06 12304.81 84.560 141.950 8962.91 9033.67 6749.78 S 760.24E 5930888.11 N 675864.80E 11.417 6792.38 • - 12339.00 84.560 141.950 8966.15 9036.91 _ 6776.59 S 781.22 E - 5930861.80 N - 675886.39E 0.000 6821.45 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Refe rence . Northings and Eastings are relative to Well Reference . Global Northi ngs and Eastings are relati ve to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 1 00 feet (US Survey). Vertical Secti on is from Well Reference and calculated along an Azimuth of 173.290° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 12339.OOft., The Bottom Hole Displacement is 6821. 47ft., in the Direction of 17 3.424° (True). 14 September, 2005 - 10:27 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 14-21A Your Ref: API 500292075602 Job No. AKZZ3882536, Surveyed: 22 August 2005 North Slope Alaska Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 8499.76 6694.99 3989.44 S 314.30E Tie On Point 8509.00 6700.77 3996.63 S 314.67E Window Point 12339.00 9036.91 6776.59 S 781.22E Projected Survey Survey tool program for 14-21A From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 8499.76 6694.99 To Measured Vertical Depth Depth (ft) (ft) 8499.76 6694.99 12339.00 9036.91 Survey Tool Description BP High Accuracy Gyro - GYD-CT-CMS (14-21) MWD+IIFR+MS (14-21 A) BPXA • • 14 September, 2005 - 10:27 Page 4 of 4 DrillQuest 3.03.06.008 ~ TREE = GRAY GEN 2 WELLHEAD= GRAY ACTUATOR - AXELSON KB. ELEV_- 71' BF. ELEV..- KOP = 2800' Max Angle = Datum MD = Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID =12.347" ~-1 251T 14-21A Final - ~~ 8352` -Top of 7" Liner Minimum iD = 3.725" @ 11415' 4-1 /2" XN N{PPLE 4-1/2" TBG, 12.6#, L-80, TGII, ID = 3.958" ~-j 11428' 8509' 9 5/8" Window 5-112" 17#, L-80 tubing cut @ 8700' Top of Cement 11300' 11707' 9-5/8" X 5-1/2" BKR FB-1 PKR TOP OF 7" LNR 11762' 9-5/8" CSG, 47#, L-80, ID = 8.681" 12036' 12435' 4-1/2" MAGNA PLUG PBTD 13018' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13060' 11350' ~4 1/2" X Nipple (3.813" ID) 11371' - 7" x 4 1/2" Baker S3 Packer 11394' 4 1/2" X Nipple (3.813" ID) 11415' 4 1/2" XN Nipple (3.725" ID) 11426' 4 1/2" Hanger /liner top packer 11428' 4 1!2" WLEG ~` 11536' 7" 26# L-80 BTGM (6.276" ID) L~~ 12253' ~ 4 1/2" 12.6# L-80 TGII Liner, ID = 3.958" 12339' 11709' 5-1/2"BAKERSBEASSY l S Y NOTES: 2217' (-) 4-1/2" X Nipple {3.813" ID) PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 47 Degrees Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2.88 6 11540-11570 Open 08!24/05 2.88 6 11810-11900 Open 08/24/05 2.88 6 11920-12000 Open 08/24/05 2.88 6 12080-12140 Open 08/24105 2.88 6 12160-12210 Open 08/24!05 DATE REV BY COMMENTS DATE REV BY COMMENTS 08!13/82 ORIGINAL COMPLETION 08/25/05 CRM Final Sidetrack Completion 01(25/88 LAST WORKOVER 08/28/05 DM/TLH CORRECTIONS 02/22101 SIS-LG REVISION 01/08/02 RN/TP CORRECTIONS 02/20!03 /TLH WANERSAFETY NOTE 05/26/05 JNC PROPOSED SIDETRACK COMP PRUDHOE BAY UNIT WELL: 14-21 A PERMfT No: 205-107 API No: 50-029-20756-01 SEC 9, TION, R14E 1562' FEL 2715' FNL BP Exploration {Alaska) ~ z~s - r~7 i Subject: DS~4-21A LOT From: "Smith, Phil G (ASRC)" <SmithPG1@BP.com> Date: Tue, 1 t~~ Aug 2005 OJ:24:52 -0800 To: Winton Aubert <Winton_auber't@admin.state.ak.us> Winton, Last night our attempted FIT to 12.5 ppg turned into a 12.2 LOT. Kick tolerance is still infinite for this sidetrack so it's of little consequence to us and we're planning to drill ahead later this morning. Please let me know if you need any more info on this. Thanks, Phil Smith, Operations Drilling Engineer 564-4897 «FIT.ZIP» Content-Description: FIT.ZIP FIT.ZIP Content-Type: application/x-zip-compressed ', Content-Encoding: base64 ~ ~ JJ ~~~ ~ ~ ~~ ~ ~ ~ ~ ~~, ~~ ~ ~ ~ ~'°A~ ~ FRANK H. MURKOWSKI, GOVERNOR ~It>•-7~ OII/ 0l«1 Vrv~7 333 W. T" AVENUE, SUITE 100 COI~TSER~ATIOI~T CO1fIDTISSIOIQ ~ PHONERA 907)279-1433 5013539 FAX (907) 276-7542 Phil Smith Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 14-21A Bp Exploration (Alaska) Inc. Permit No: 205-107 Surface Location: 2715' FNL, 1562' FEL, SEC. 09, T10N, R14E, UM Bottomhole Location: 4194' FNL, 782' FEL, SEC. 16, T10N, R14E, UM Dear Mr. Smith: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's pet ~ um field inspector at (907) 659- 3607 (pager). ~-°--~ ~ Chairman DATED this~day of July, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION OMMISSION PERMIT TO DRILL 20 AAC 25.005 1a. Type of work ~ Drill ®Redrill ^ Re-Entry 1b. Current Wel! Class ^ Exploratory ^ Development Oil ®~ne ^ Stratigraphic Test ®Service ^ Development Gas ~~jj e 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU 14-21A 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12341 TVD 9037 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2715' FNL 1562' FEL SEC T10N 09 R14E UM 7. Property Designation: ADL 028314 Pool , , . , , , Top of Productive Horizon: 3715' FNL, 1088' FEL, SEC. 16, T10N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: August 5, 2005 Total Depth: 4194' FNL, 782' FEL, SEC. 16, T10N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 8000' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 674948 y- 5937618 Zone- ASP4 10. KB Elevation Planned (Height above GL): 7p.g feet 15. Distance to Nearest Well Within Pool 14-08 is 1497' away at 11678' 16. Deviated Wells: Kickoff Depth: 8500 feet Maximum Hole Angle: 85 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2360 1 asingProgram: Size Spec cations Setting 'Depth To Bottom Quantityo Cement c.f. or sacks. Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 3173' 8350' 6607' 11523' 8881' 169 sx Class 'G' 6-1/8" 4-1/2" 12.6# L-80 TC-II 918' 11423' 8772' 12341' 9037' 134 sx Class 'G' 19. PRESENT W ELL CONDITION SUMM ARY (To be completed for RedrilF ANp Re-entry Operations) Total Depth MD (ft): 13060 Total Depth TVD (ft): 9641 Plugs (measured): 12435 Effective Depth MD (ft): 12435 Effective Depth TVD (ft): 9174 Junk (measured): 13050 Casing Length Size Cement Volume MD TVD t n c r 111' 20" 350 sx Permafrost II 111' 111' 2517' 13-3/8" 500 sx Arcticset III, 400 sx AS I I 2517' 2517' nt i 12036' 9-5/8" 500 sx Class 'G', 300 sx AS I I 12036' 8877' Pr u i n Li 1298' 7" 00 sx Class 'G' 11762' - 13060' 8682' - 9641' Perforation Depth MD (ft): 12091' - 12914' Perforation Depth TVD (ft): 8918' - 9531' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoin is tru nd correct to the best of my knowledge. Contact Jeff Cutler, 564-4134 Printed Name ~n ~;~ ~ ~ '-(f Title Senior Drilling Engineer hit math, 4-4 7 r,.,...--~ -- ~f f Prepared By Name/Number: Si nature Phone 564~-'~ ~ Date //~~~-~ Ten•ie Hubble, 564-4628 Commission Use Only Permit To Drill Number: ,Zp~ API Number: 50- 029-20756-01-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples uired ^ Yes ~No Mud Log Required ^ Yes ,gJ No Hydro n Su~fide Measures 'Yes ^ No DirectionalcS~urvey Required Yes ^ No other: M ~~ CtcM~c. e~vo `~ ~ d ~~ ~il~C`fJps~ 30p ~c 5~ o``s e~c~rrec~`, P\ t ~~rw,'r-c~ S~b~a~+~-~~"~ G Pc ~ct..~s."C.1~S~~ ~`~ . ~ h~`~CC't~O~ cCr'G'Cior~ ~~ t~ VCCO~ W/ ~\~ ~ . '" I `~, ~ ~ ~° ~` ~ APPROVED BY Q ,, ) , t e A roved ~ ~ ~~ ~ THE COMMISSION Date w JUL j ~ 200. l ~ Alaska Oil & Ga ` ~~~~ Form 10-401 evised 0 200A ubm~ In Duplicate ~~ C Well Name: 14-21 A Planned Well Summary Conventional Well 14-21 A Well Sidetrack Target Zone 4 Type In'ector Objective AFE Number: PBD4P2387 API Number: 50-029-20756-01 Surface Northin Eastin Offsets TRS Location 5,937,619 674,948 2715' FNL / 1562' FEL 10 N, 14 E, 9 Target Northin Eastin Offsets TRS Location 5,931,352 675,582 1565' FSL / 1088' FEL 10 N, 14 E, 16 Bottom Northin Eastin Offsets TRS Location 5,930,880 675,900 1085' FSL / 782' FEL 10 N, 14 E, 16 Planned KOP: 8,500' and ! 6,699' tvd P{anned TD: 12,341' and / 9,037' tvd Ri Nabors 2ES CBE: 42.26' RTE: 70.8' Directional Program Approved Well Ian: W 07 Exit oint: 8,500' and / 6,699' sstvd Maximum Hole Inclination: -85° in the tanned 6 1/8" roduction section. There are two close approach issues with this well, 14-09B and 14-22. Gyro Proximity Issues: surveys will be run on 14-21 pre-rig to reduce directional uncertainty with the original wellbore. 14-21A passes all close approaches with major risk with the additional ro surve s. Survey Program: Standard MWD. Nearest Well within ool: Well 14-08, with center-to-center distance of -1497' C~ TSAD, 11,678' md. Nearest Pro ert Line 8,000' to unit bounda to SW. 14-21 A Sidetrack Page 1 • • Logging Program Hole Section: Required Sensors /Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD throu hout the interval 6 1/8" roduction: Real time MWD Dir/GR/Res/Aim throu hout the interval. Two sam le catchers. Cased Hole: USIT to in the 7" intermediate liner O en Hole: None tanned Mud Program Hole Section / o eration: Mill window in the 9 5/8" Casin at -8,500' md. T e Densi Viscosit PV YP API FL H LSND 9.0-9.3 50-60 15-22 30-40 <6.0 9.0-9.5 Hole Section / o eration: Drillin 8 1/2" interval from window to section TD T e Densit Viscosit PV YP API FL H LSND 11.0 42 - 52 18 - 25 22 - 28 <5.0 9.0 - 9.5 Hole Section / o eration: Drillin 6 1/8" roduction interval T e Densit LSRV PV YP API FL H FloPro SF 8.4 - 8.6 >25,000 8 - 15 24 - 30 4 - 6 9.0 - 9. Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 8 1/2" 7" 26.0# L-80 BTC-M 3,173' 8350' / 6,607' 11,523' / 8,881' 6 1/8" 41h" 12.6# L-80 TC-II 918' 11,423'/ 8,772' 12,341' / 9,037' Tubin 4 1/z" 12.6# L-80 TC-II 11,394' Surface 11,423'/ 8,772' NU I ~: I his well is planned with the minimum allowed, 100' liner lap, the 7" shoe will be located near the top of the Sag River, but with the planned completion, the packer to injection zone distance will more than likely exceed the 200' limit as per 20 AAC 25.412 (b) but be less than 300'. A variance to 20 AAC 25.412 (b) is requested allowing a packer to injection zone distance of 300' is requested Cementing Program l~~.QC ~~'~ (~~ Casin Strin 7", 26#, L-80, BTC-M Ion in Slurry Design Basis: Lead slurry: None planned. Tail slurry: 1,000' of 7" X 8-1/2" annulus with 40% excess, plus 85' of 7", 26# shoe track. Pre-Flush None tanned Fl id S l /V S acer 35bbls MudPUSH at 12.0 u s equence ume: o Lead Slur None tanned Tail Slur 35.0 bbl / 197.6 cf / 169 sxs Class `G', 15.8 ; 1.16 cf/sk. Casin Strin 4 1/2", 12.6#, L-80, TC-II solid roduction liner Slurry Design Basis: Lead slurry: none planned Tail slur :818' of 4 i/2" X 6 1J8" annulus with 40% excess, lus 85' of 4 1/2", 14-21 A Sidetrack Page 2 C, • 12.6# shoe track, plus 100' of 7" X 4 ~h" liner lap, plus 200' of 7" X 4" drill pipe annulus. Pre-Flush 25bbls CW 100 id Fl S /V l S acer 35bbls MudPUSH at 9.6 u s equence ume: o Lead Slur None tanned Tail Slur 27.8 bbl / 156 cf ! 134 sx Class `G', 15.8 ; 1.17 cflsk. Casing /Formation Integrity Testing Test Test Point Test Type Test pressure 9 5/8" casin Bride lu to surface 30 min recorded 4,000 si surface 9 5/8" casin window 20' new formation be and FIT 12.5 EMW 7" casin Float a ui ment to surface 30 min recorded 4,000 si surface 7" casin shoe 20' new formation be and FIT 10.0 EMW 4 1h" roduction liner Float a ui ment to surface 30 min recorded 4,000 si surface Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antici ated BHP: 3,100 si at 8,398' TVDss. Maximum surface ressure: 2,260pS1 (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 12.5 EMW FIT Planned ROPE test ressure: 250 si low /4,000 si hi h - 7 da test c cle Pre drillin hase BOPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams drilling liner. while running 3175' of 7" liner. The rig will follow the current, best practice of picking up a joint of drill pipe, crossed over to casing thread, in the event of a kick. This configuration provides two sets of employable rams, rather than one. Well Interval: 6 1/8" roduction interval Maximum antici ated BHP: 3,250 si at 8,895' TVDss. Maximum surface ressure: 2,360 Si (based upon BHP and a full column of gas from TD C~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.0 EMW FIT. Planned BOPE test ressure: 250 si low / 4,000 si hi h - 14 da test c cle Drillin o erations Planned com letion fluid: 8.4 pg seawater / 7.1 pp9 Diesel Disposal Annular Injection: No annular injection in this well. Cuttin s Handlin Cuttings generated from drilling operations are to be hauled to the Grind and Inject 14-21 A Sidetrack Page 3 C; station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 for in'ection. All Class I wastes are to be hauled to Pad 3 for dis osal. Geologic Prognosis ''1`~ ..~ ~--il,'' ~--i Formation MD TVDbkb TVDss Comments CM2 8714 6841 6770 CM1 9705 7561 7490 THRZ 10217 7933 7862 BHRZ 10449 8101 8030 LCU 10511 8146 8075 TJD 10956 8469 8398 TJC 11009 8507 8437 TJB 11310 8726 8655 Sa River 11523 8881 8810 Shublik 11551 8901 8830 TSAD / TZ46 11678 8966 8895 MHO/HOT 9041 8970 Below TD POWC 9076 9005 " 42SB 9136 9065 " TCGL 9237 9166 " BCGL 9293 9222 " TD Criteria: TD as per directional plan to avoid faults • Oaerations Summar Current Condition: / PDS Caliper 10/7/99 shows 70% of joints with 40%+ wall loss. / LDL 9/21/99 shows leak at 5565'MD. 1 BPM LLR Q 2500 psi. / Confirmed TxIA integrity with MITOA to 3000 psi on 5/26/05. / Open perforations from 12,091'to 12,264' / 4-1/2" Magna-Plug set at 12,435' / CMIT passed to 3,000 psi on 6/6/05. Scope Pre-Rig Work: 1. R/U SL and drift tbg, tag up on Magna Plug C~3 12,435' MD 2. RU a-line, run gyro surveys from surface to 12,435' 3. RU SL and set 4-1/2" DPB plug body @ 11,764' SLM. Perform CMIT to 4,000 psi. RIH with SL and pull plug 4. RU CT and RIH and P&A the 14-21 well bore. Pump --194 ft3 (34.5 bbl) 15.8 ppg Class G cement leaving TOC in the tubing tail at -11300'md. 5. Drift the 5'/z" tubing to 8,900' and to confirm clear to the required cut depth of 8,700' md. R/U E-line and RIH with the appropriate jet cutter, cutting the 5'/z" tubing in the center of a full joint at 8,700' md. 14-21 A Sidetrack Page 4 • • 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. 7. Freeze protect to 2,200' MD with diesel. 8. Test the 9 5/8" pack-off and tubing hanger seals to 5,000psi for 30 minutes. Function all Lock Down Screws, repair or replace as needed. 9. Set a BPV. Secure the well. Level the pad as necessary. Riq Operations: ~~ 1. MI ! RU Nabors rig 2ES P ~~ 2. Pull BPV and circulate out diesel freeze protection and displace the well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE to 4,000 psi. 4. R/U. Pull 5'/z" tubing from the cut at --8,700' MD and above. 5. R/U E-line. M/U 8.5" gauge ring /junk basket / CCL. RIH and tag tubing stub .POOH. 6. RlH with HES EZSV on E-line. Set bridge plug at 8,524', as required to avoid cutting a casing collar while milling the window. POOH. R/D E-line. 7. Pressure-test the 9 5/8" casing to 4,000psi for 30 minutes. Record test. 8. P/U and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridae olua. Shear off of whip stock. 9. Displace the well to 11.0 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. 10. Mill window in 9 5/8" casing at ± 8,500' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. ,~(~`~,1. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. ~~ 12. M/U 8'h" Dir/GR/PWD assembly. RIH, kick off and drill the 8'h" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 13. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 14. M/U 6-1l8" Dir/GR/Res assembly. RIH to the landing collar. 15. Test the 9 5/8" casing X 7" liner to 4,000psi for 30 minutes. Record the test. 16. Drill out the 7" liner float equipment and cement to the shoe. 17. Displace the well to 8.4 ppg Flo-Pro drilling fluid. 18. Drill out the 7" shoe plus -20' new formation, pull up into the shoe and conduct an FIT to 10.Oppg EMW. Drill ahead to TD per directional proposal. 19. Circulate well bore clean, short trip to shoe, circulate. POOH. 20. R/U eline and run USIT on 7" liner 21. Run and cement '/2", 12.6#, L-80 solid production liner. POOH. 22. RIH with 2 7/8" pert guns and perforate ±500'. 23. R!U and run a 4Y2", 12.6#, L-80 tubing completion, stinging into the 4'h" liner tie back sleeve. 24. Set packer and individually test the tubing and annulus to 4,000 psi for 30 minutes. Record each test. 25. Set a TWC. 26. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC 27. Freeze protect the well to 2,200' TVD. Set BPV and secure the well. 28. Rig down and move off. Post-Riq Operations: 1. MI / RU slick line. Pull the ball and rod / RHC plug from landing nipple below the production packer. 2. Install well house and instrumentation. 3. Perform static step rate test Phase 1: Move In /Riq Up /Test BOPE 14-21A Sidetrack Page 5 • r: Planned Phase Time Planned Phase Cost 54.8 hours $163,314 Reference RP • "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards - No wells will require shut-in for the rig move onto 14-21 A. However, 14-40 is 35' to the North. This is the closest neighboring well. Care should be taken while moving onto the well. Spotters should be employed at all times. - During M1/RU operations, the 14-21 well bore wiU be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. - Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. - During ND/NU BOPS operations, the 14-21 well bore will be secured with the following barriers: • Tubing: the cement P&A plug, kill weight fluid, and a TWC/blanking plug. • IA: Annulus valves and kill weight fluid. • OA: Annulus valve and kill weight fluid. - t7-14 is desinafed as an hI~S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 14-40A 30 ppm 14-08AL1 20 14-22A 140ppm 14-44A 20 The maximum lave! recorded ofi H2S on the pad was 200ppm in well 14-07 on 0812212004, - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Phase 2: De-complete Well Planned Phase Time Planned Phase Cost 51.0 hours $155,107 Reference RP • "De-completions" RP Issues and Potential Hazards - Monitor the well to ensure the fluid column remains static, prior to pulling the completion. - Have all wellhead and completion equipment NORM-tested, following retrieval. - This wellhead is a Gray Gen 2. Check with Cameron to ensure all replacement parts and required equipment is available. 14-21 A Sidetrack Page 6 -4-,rr~rc '~`~ ~ ~ ~ - Once the ~k has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. - There is a 5-1/2" Camco BAL-O SSSV at 2156' with a'/a" control line. 53 stainless steel bands were initially run on the control line. - Run GR/CCL Log from the bridge plug setting depth to surface after setting the EZSV. Phase 3: Run Whip Stock Planned Phase Time Planned Phase Cost 31.0 hours $220,349 Reference RP • "Whip stock Sidetracks" RP Issues and Potential Hazards - The 9 518" casing was cemented with 500 sxs Class G cement. Cement i~not expected behind the 9-5/8" csg at the KOP. - Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time Planned Phase Cost 90.0 hours $467,404 Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - Must tie MWD - GR back to GR-CCL run during the de-completion phase. No other shallow logs exist for this well. - For this well, the HRZ will require a mud weight of 11.Oppg. Maintain mud weight at 11.Oppg, minimally, from above the HRZ to the 7" casing point. Follow all shale drilling practices to minimize potential problems. - KICK TOLERANCE: In the worst-case scenario of 7.1 ppg pore pressure at the Sag River depth, a fracture gradient of,12.5 ppg at the 9 5/8" casing window, and 11.0 ppg mud in the hole, the kick tolerance is infinite. - The above kick tolerance is based on an FIT of 12.5 ppg EMW, if this is not reached contact the ODE Phase 6: Run and Cement 7" Intermediate Casing Planned Phase Time Planned Phase Cost 20.0 hours $171,287 14-21 A Sidetrack Page 7 • • Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Freeze Protecting an Outer Annulus" RP • "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards - Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab f surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. Phase 7: Drill 6 1/8" Production Hole Interval __ Planned Phase Time Planned Phase Cost 55.0 hours $282,463 Reference RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards - The geologic polygon is tightly constrained by faults; it is designed to maintain a 200' minimum offset from all faults. ALL POLYGON LINES ARE HARDLINES. - 14-21A is expected to cross a single, small fault at 8480' TVD (-10975' MD). The throw is estimated at <10', losses are not expected. Phase 8: Run USIT Log in 7" Intermediate Liner Planned Phase Time Planned Phase Cost 12 hours $68,209 Reference RP • "Wireline Pressure Control SOP Issues and Potential Hazards - 50' of good cement is required to demonstrate injection fluid isolation. Phase 9: Run 4~/s" Production Liner Planned Phase Time Planned Phase Cost 14-21 A Sidetrack Page 8 • • 14 hours $164,210 Reference RP • "Modified Conventional Liner Cementing" RP Issues and Potential Hazards - The completion design is to run a 4'/i", 12.6#, L-80 solid liner throughout the production interval. - Differentia! sticking is possible. The 8.4ppg Flo-Pro will be ~600psi over balanced to the Ivishak Zone 4 formation. Minimize the time the pipe is left stationary while running the liner. - Sufficient 4'/i" liner will be run to extend -100' back up into the 7" liner shoe. - Ensure the 4'/z" liner top packer is set prior to POOH. Phase 12: Run 41h" L-80 Completion Planned Phase Time Planned Phase Cost 24 hours $446,224 Reference RP • "Completion Design and Running" RP •:- "Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 Asia at 100° F. - The completion, as designed, will be to run a 4~/2", 12.6#, L-80, TC-II production tubing string, stinging into the 4'/z" liner tieback sleeve. Phase 13: ND/NU/Release Rig Planned Phase Time Planned Phase Cost 12.0 hours $38,589 Reference RP • "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards - No wells will require shut-in for the rig move off of 14-21 A. However, 14-40 is 35' to the North. This is the closest neighboring well. Care should be taken while moving off from the well. Spotters should be employed at all times. 14-21 A Sidetrack Page 9 TRFF= t^J7AV !`-FN7 WELLHEAD= GRAY ACTUATOR= AXELSON KB. ~E/ = 71' BF. IiEV = KOP= 2800' Max Angle = 58 ~ 9600' Datum MD = 12027' t7atum N D = 8800' SS =12.3x7" H 251 T Minimum ID = 3.750" cLD 11796' 41/2" CAMCO DB N~PLE 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID =4.892' ~ 11725' TOP OF 41 l2" TBG-PC 11725' TOP OF 7" LNR ~ 11762' PERFORATION SUMMARY REF LOG: BRCS CAJ 08/07/82 ANGLEATTOP P82F: 42 @ 12091' Note: Refer to Roductlon DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE S~ PAGE 2 FOR PERFORATION DATA 9-5/8" CSG, 47#, L-80, ~ = 8.681" 4-1/2" TBG-PC, 12.6#, L-80, .0152 bpf, ~ = 3.958" TOP OF 4-1 /2" TBG 41/2" TBG-PC,12.6#, L-80, .0152 bpf, ID = 3.958" I 41/2" TBG,12.6#, L-80, .0152 bpf, D = 3.958" I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11805' I 12451' 13018' 13060' 14-21 SAFETY NOTES: ""`RAPID T~dA C OM M. OPERATING LM ITS: MAX IAP = 2000 PSI, MAX OAP =1000 PSI (10/22/03 WAIVB2}"'FLOWLNEFRO~ZBd, CORROSION DAMAGE TWINNED WITH 14-17. 2156' S-1 /2" CAM BA L-O SSSV NIP, ~ = 4.562" GAS LIFT MANDRH.S ST MD TVD DE/ TYPE VLV LATCH PORT DATE 1 3562 3513 2& MMH RK 2 5748 5011 52 MMH RK 3 7869 8302 52 MMH RK 4 9928 7530 54 MMH RK 5 11375 8418 49 MMH RK 6 11523 8517 47 MMH RKP 11707' ~ 9-5J8" X 5-1 /2" BKR FB-1 PKR 11709' 5-1/2"BA10=RSBEASSY 11725' S-1/2" X 41/2" XO 11796' I-1 4-1/2" CAMCO DB NIP ID = 3.75" 12395' ~ 7" X 4-1 /2" BKR F$-1 ISO PKR 12435' 4-1/2" MAGNA PLUG 12441' 4-1/2" CAMCO DB NP ID= 3.61 W/BLANKWG PLUG 12449' 13050' 13055' a-u2"Trw/BAI~RWL~ CA-RKED W/0 PRONG 22' PERF GUN & O;L. 3-1/8" DOTE REV BY COMMBdl'S DATE REV BY COMMENTS 08H3l62 ORIGINALCOMPLETION 0125/88 LAST WORI4DVER 02/12101 S6-LG REVISDN 01108/02 RN/TP CORR~TgNS 0220103 /TLH WANES SAFETY NOTE 11/17/03 TJFI'PAG WANERSAFETYNOTE PRUDHOEBAY UNR WELL• 14-21 P92MIT No: 1820860 AR No: 50-0'19-20756-00 SEC 9, TION, R14E 1364.03 FEL 4846.25 FNL BP Exploration (Alaska) TREE = GRAY GEN 2 WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV..- 71' BF. ELEV.- KOP = 2800' Max Angle Datum MD = Datum TV D = m 8800' SS AFETY NOTES: 14-21A Proposed 13-3/8" CSG, 72#, L-80, ID = 12.347" 2517' Minimum ID = 3.725" @ 11467' 4-1/2" XN NIPPLE 8350` -Top of Liner 8500' 9 5/8" Window Q 2200' 4-1/2" X Nipple (3.813" ID) GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2 3 4 5 11407' 4 1/2" X Nipple (3.813" ID) 11417' 7" x 4 1/2" Baker S3 Packer 11437' 4 1/2" X Nipple (3.813" ID) 11457' 4 1/2" XN Nipple (3.725" ID) 11467' 4 1/2" Hanger 1 liner top packer 11467' 4 1/2" WLEG 5-1l2" 17#, L-80 tubing cut @ 8700' Top of Cement 11300' 11707' 9-5/8" X 5-1/2" BKR FB-1 PKR TOP OF 7" LNR 11762' 9-5/8" CSG, 47#, L-80, ID = 8.681" 12036' 12435' 4-1/2" MAGNA PLUG PBTD 13018' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 13060' 11617' 7" 26# L-80 (6.276" ID) 4 1/2" 12.6# L-80 Liner PBTD 12,380' 11709' 5-1/2"BAKERSBEASSY PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: Note: Refer to R-oduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE DATE REV BY COMMENTS DATE REV BY COMMEMS 08/13/82 ORIGINAL COMPLETION 01/25/88 LAST WORKOVER 02/22/01 SIS-LG REVISION 01 /08/02 RN/TP CORRECTIONS 02!20/03 /TLH WANERSAFETY NOTE 05/26/05 JNC PROPOSED SIDETRACK COMP PRUDHOE BAY UNff ~"'~ I WELL: 14-21A r PERMrr No: ~~82"p86U 805^10"'~ API No: 50-029-20756-01 SEC , TION, R14E 1364. 3~L 48 FN lb }ohe ~t'wt~•vtx BP Exploration (Alaska) ,,n,y,"^ ~~.-t COMPM•V DtTA1LS RtFtRF.N('t If:FORMATIDf: auRVCr rRwluat Plan: 14-21A wp117 U4-21/Plan I4-21 A) BP Am°co L_ (rvoNiwte (Kh:) Refettva'e Well Cererc- 14_'1, lrue f:onh \"cnical(NDI Ref re: 0?2E-?N S'I(1 ]M1 Ih7+Ih Fm Degh To Snrvq?Ian Tool ('reaWd By: Digital Business ('limt User Datc: 7/5/2005 ewe LJ(J UkvYlvn McMod' Mmvnmr (l:ne Sa'tim (6'SI Ref r Sbl~ In.110~f1.001.1 NSIMI00 I?1/1 ~0 PYvred: l/'_IA wpO]\20 MWD-I F'R-MS ('hecked: Dale: Ertor Sypem' ISCWSA S M h d T - C li d M h Masuml Dryth Refemrw'e' 4~ ~6 - ~X c ]~ ]M1 ('el lali m MnhnJ M nim m (' `atve can n o : m y n er m F:rtor Sum -. tll~ti:al - Cnang cu i i u ru Reviewed'. Dale: N'emmg Mctlwd' Ruks tlas.d CASMG DETAILS r:ame _n,-s -L,-w nnnnir~ fstmg lao mae t.or~gin,de sbr No. TVD MD Name Size Ian -w]zo2 nr_] 59176184/ h74AtX I] 70°14'06.9018 14X'15'14 B64N' A!A 8880.76 11522.76 7" 7.000 2 9037.47 12341.00 4 I/2" 4.500 TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape f 14-21A TI 8982.76 -6279.37 488.31 5931352.50 675581.99 Circle(Radilu:75) ~ I 14-21A Poly 8982.76 -6279.37 488.31 5931352.50 675581.99 Polygon t T ~ I I -T~- I { I ~ 1 14-21A T2 9037.49 -6759.16 795.59 5930880.00 675900.29 ) Circle (Radius: 75 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 8500.00 51.75 176.00 6698.99 -3987.22 440.05 0.00 0.00 4011.33 2 8520.00 52.00 179.03 6711.34 -4002.94 440.73 12.00 85.00 4027.02 3 8734.51 43.42 178.78 6855.55 -4161.45 443.73 4.00 -178.84 4184.79 4 11528.57 43.42 178.78 8884.98 -6081.48 484.55 0.00 0.00 6096.42 5 11754.02 84.00 179.00 8982.76 -6279.37 488.31 18.00 0.33 6293.40 14-21A TI 6 12026.15 85.00 138.00 9010.01 -6525.91 585.53 15.00 -90.71 6549.61 7 12341.24 85.00 138.00 9037.49 -6759.16 795.59 0.00 0.00 6805.62 14-21A T2 I - I '_ - ~ _ - ~ ~ i I I 4 _ FORMATION TOP DETAILS , -. . No. TVDPath MDPath Formation - - - i -- G - ' - 1 6840.83 8714.10 CM2 2 7560.76 9705.42 CM 1 - ~ ~ `~ ~ f - - - I i 3 7932.76 10217.58 THRZ 4 8100.76 10448.88 BHRZ 750 r ~ 5 8145.76 10510.83 LCU ~ ^ cM1 ~ I - 1 ~ ! i 6 8469.26 10956.22 TJD 7 8507.99 11009.55 TJC { ' 1 I - , - 8 8726.18 11309.94 TJB ~ ~ i 1 ~ 9 8880.76 11522.76 TSGR ' - - - - - ~ 10 8900.76 11551.07 TSHU u - - - ' ' ~ t ' _ -- - - - r _ I1 8965.76 11677.57 TSAD F-, I ~ i ~ - 12 8996.57 11886.08 46P - - - _ 13 9020.76 12149.40 45N 14 9022.76 12172.34 45P 800 ~ ~ [ - }} 15 9031.77 12275.63 45N 6 03 77 12275 6 4 P ~~• ~ ~ 1 -1 l { . 1 9 1. 3 5 6000 6500 7000 7500 Vertical Section at 173.29° [SOONin] c w 0 0 r C 0 s 0 rn by ~ ~a A ~, a C I I Mnhod-. Mi um Ciavarwe F or System' ISCWSA Scan MelMid: Trav Cyhrdcr NOnh I.rmr Surface. fJlipacal+Casing Wmrting Method: Rules Based Co-ordiru 1.1.1 R f rrn W II (rntre- I0.?I, IYVe M1ath Vcrti. I IIVDI R f rera ~ 4 6 28.y 70.76 Sec IS SIR f M' Sb IO qIN (1.001::1 Masured Ikplh Rcf rice 4_._fi 285 ]0.76 Cakulalion Mehad: Mutimum CurvaNre sun V cY r KU;KAM Plan: 14-21 A wp07 (I4-21 /Plan 14 21 AI Depth Fm Depth To SlwryRlsn Tool ('reared By ' Digital Business Clienr User Date: 7/52005 850D W 1234114 PlaiaKd-.19-21A wp07 V20 MWD-IPR~MS Checked: Dale: WELL DETAILS Name -N'-S -IJ-W Natbmg fasting latinde LoegiNde Sbt 14-21 1977.0? 752.27 593761804 67J998.I7 70°IJ'U6.90IN 148°1510864W N/A TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape 14-21A TI 8982.76 -6279.37 488.31 5931352.50 675581.99 Circle (Radius: 75) 14-21A Poly 8982.76 -6279.37 488.31 5931352.50 675581.99 Polygon 14-21 A T2 9037.49 -6759.16 795.59 5930880.00 675900.29 Circle (Radius: 75) FORMATION TOP DETAILS No. TVDPath MDPath Formation . ' ' . _ __ _ _ ~. ' _. . _ _. .. , _. _. _ I 6840.83 8714.10 CM2 2 7560.76 9705.42 CM 1 3 7932.76 !0217.58 THRZ 4 8100.76 10448.88 B}IRZ 5 8145.76 I OS 10.83 LCU 6 8469.26 10956.22 TJD 7 8507.99 11009.55 TJC 8 8726.!8 11309.94 TJB I ~ 9 8880.76 11522.76 TSGR ~ 10 8900.76 11551.07 TSHU ~ Il 8965.76 11677.57 TSAR 12 8996.57 11886.08 46P 13 9020.76 12149.40 45N 14 9022.76 I2L72.34 45P }} ~ 1- i 16 9031.77 12275.63 45P CASING DETAILS No. TVD MD Name Size I 8880.76 11522.76 7" 7.000 2 9037.47 12341.00 4 1/2" 4.500 SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 8500.00 51.75 176.00 6698.99 -3987.22 440.05 0.00 0.00 4011.33 2 8520.00 52.00 179.03 6711.34 -4002.94 440.73 12.00 85.00 4027.02 3 8734.51 43.42 I7R.78 6855.55 -4161.45 443.73 4.00 -178.84 4184.79 4 11528.57 43.42 178.78 8884.98 -6081.48 484.55 0.00 0.00 6096.42 S 11754.02 84.00 179.00 8982.76 -6279.37 488.31 18.00 0.33 6293.40 14-21A TI 6 12026.15 85.00 138.00 9010.01 -6525.91 585.53 15.00 -90.71 6549.61 7 12341.24 85.00 138.00 9037.49 -6759.16 795.59 0.00 0.00 6805.82 t4-21A T2 0 1000 West(-)/East(+) [500fUin] Sperry-Sun BP Planning Report Company: BP Amoco Date: 7/5!2005 Time: 11:37:22 Page: 1 Field: Pnrdhce Bay Co-ordinate(NE) Reference: Wetl: 14-21, True North Site: PB DS 14 Vertical (TVD) Reference: 42.26 + 28.5 70.8 Well: 14-21 Section (VS) Reference: WeII (O.OON,O.OOE,173.29Azi) Wellpath: Plan 14-21A Sarvey Calculation Method: Minimum Curvature Db: Oracle Plan: 14-21A wp07 Date Composed: 5/19/2005 Version: 20 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB DS 14 TR-10-14 UNITED STATES :North Sbpe Site Position: Northing: 5939577.43 ft Latitude: 70 14 26.346 N From: Map Easting: 674150.48 ft Longitude: 148 35 36.726 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.32 deg Well: 14-21 Slot Name: 14-21 Well Position: +N7-S -1977.02 ft Northing: 5937618.44 ft Latitude: 70 14 6.901 N +E/-W 752.27 ft Easting : 674948.17 ft Longitude: 148 35 14.864 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 11522.76 8880.76 7.000 8.500 7" 12341.00 9037.47 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 UG1 0.00 0.00 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 8714.10 6840.83 CM2 0.00 0.00 9705.42 7560.76 CM1 0.00 0.00 10217.58 7932.76 THRZ 0.00 0.00 10448.88 8100.76 BHRZ 0.00 0.00 10510.83 8145.76 LCU 0.00 0.00 10956.22 8469.26 TJD 0.00 0.00 11009.55 8507.99 TJC 0.00 0.00 11309.94 8726.18 TJB 0.00 0.00 11522.76 8880.76 TSGR 0.00 0.00 11551.07 8900.76 TSHU 0.00 0.00 11677.57 8965.76 TSAR 0.00 0.00 11886.08 8996.57 46P 0.00 0.00 12149.40 9020.76 45N 0.00 0.00 12172.34 9022.76 45P 0.00 0.00 12275.63 9031.77 45N 0.00 0.00 12275.63 9031.77 45P 0.00 0.00 0.00 HOT 0.00 0.00 0.00 45SB 0.00 0.00 0.00 OWC 0.00 0.00 0.00 42SB 0.00 0.00 0.00 42N 0.00 0.00 0.00 42P 0.00 0.00 0.00 41 N 0.00 0.00 0.00 41 P 0.00 0.00 0.00 TCGL 0.00 0.00 0.00 BCGL 0.00 0.00 • Sperry-Sun BP Planning Report • Company: BP Amoco Date: 7/5/2005 Time: 11:37:22 Page: 2 FieM: Pnrdhoe Bay Co-ordinst~NE) Reference: Well: 14-21, True North Site: PB DS 14 Vertical (TVD) Reference: 42.26 + 2g.5 70.8 Well: 94-21 Section (VS)Reference: Well (O.OON,O.OOE,173.29Azi) Wellpath: Plan 1421A Survey CaMalation Method: Mininum Curvature Dh: Orade Targets Map Map ~--- Ladtude --,> <-- Longitude -> Name Description TVD +N!-S +E/-W Northing Easti ag Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 14-21A T1 8982.76 -6279.37 488.31 5931352.50 67558 1.99 70 13 5.143 N 148 35 0.684 W -Circle (Radius: 75) -Plan hit target 1421A Poy 8982.76 -6279.37 488.31 5931352.50 67558 1.99 70 13 5.143 N 148 35 0.684 W -Polygon 1 8982.76 -5963.91 537.75 5931669.00 675624.09 70 13 8.246 N 148 34 59.248 W -Polygon 2 8982.76 -6032.84 361.29 59315.00 675449.29 70 13 7.568 N 148 35 4.372 W -Polygon 3 8982.76 -6485.80 266.85 5931141.00 675365.39 70 13 3.113 N 148 35 7.115 W -Polygon 4 8982.76 -7007.88 758.40 5930630.50 675868.89 70 12 57.978 N 148 34 52.844 W -Polygon 5 8982.76 -6710.01 1048.61 5930935.00 676152.09 70 13 0.908 N 148 34 44.417 W -Polygon 6 8982.76 -5971.07 544.58 5931662.00 67563 1.09 70 13 8.176 N 148 34 59.050 W -Plan hit target 14-21A T2 9037.49 -6759.16 795.59 5930880.00 675900.29 70 13 0.424 N 148 34 51.763 W -Circle (Radius: 75 ) -Plan hit target Plan Section Information MD lnel Aam TVD +N/-S +E/-R' DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8500.00 51.75 176.00 6698.99 -3987.22 440.05 0.00 0.00 0.00 0.00 8520.00 52.00 179.03 6711.34 ~W02.94 440.73 12.00 1.24 15.17 85.00 8734.51 43.42 178.78 6855.55 -4161.45 443.73 4.00 -4.00 -0.12 -178.84 11528.57 43.42 178.78 8884.98 -6081.48 484.55 0.00 0.00 0.00 0.00 11754.02 84.00 179.00 8982.76 -6279.37 488.31 18.00 18.00 0.10 0.33 14-21A T1 12026.15 85.00 138.00 9010.01 -6525.91 585.53 15.00 0.37 -15.07 -90.71 12341.24 85.00 138.00 9037.49 -6759.16 795.59 0.00 0.00 0.00 0.00 14-21A T2 Survey MD Incl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 8500.00 51.75 176.00 6698.99 6628.23 -3987.22 440.05 0.00 5933642.76 675480.57 Start Dir 12/10 8520.00 52.00 179.03 6711.34 6640.58 -4002.94 440.73 12.00 5933627.06 675481.61 Start Dir 4/100 8600.00 48.80 178.95 6762.33 6691.57 -4064.56 441.81 4.00 5933565.49 675484.13 MWD+IFR+MS 8700.00 44.80 178.83 6830.77 6760.01 -4137.43 443.22 4.00 5933492.68 675487.23 MWD+IFR+MS 8714.10 44.24 178.81 6840.83 6770.07 -4147.31 443.43 4.00 5933482.80 675487.66 CM2 8734.51 43.42 178.78 6855.55 6784.79 X161.45 443.73 4.00 5933468.68 675488.29 End Dir :8734 8800.00 43.42 178.78 6903.12 6832.36 -4206.45 444.68 0.00 5933423.71 675490.29 MWD+IFR+MS 8900.00 43.42 178.78 6975.75 6904.99 -4275.17 446.14 0.00 5933355.05 675493.34 MWD+IFR+MS 9000.00 43.42 178.78 7048.39 6977.63 -4343.88 447.60 0.00 5933286.39 675496.40 MWD+IFR+MS 9100.00 43.42 178.78 7121.02 7050.26 -4412.60 449.07 0.00 5933217.73 675499.45 MWD+IFR+MS 9200.00 43.42 178.78 7193.65 7122.89 -4481.32 450.53 0.00 5933149.07 675502.51 MWD+IFR+MS 9300.00 43.42 178.78 7266.29 7195.53 -4550.04 451.99 0.00 5933080.41 675505.56 MWD+IFR+MS 9400.00 43.42 178.78 7338.92 7268.16 -4618.76 453.45 0.00 5933011.75 675508.62 MWD+IFR+MS 9500.00 43.42 178.78 7411.55 7340.79 -4687.48 454.91 0.00 5932943.08 675511.67 MWD+IFR+MS 9600.00 43.42 178.78 7484.19 7413.43 -4756.19 456.37 0.00 5932874.42 675514.73 MWD+IFR+MS 9700.00 43.42 178.78 7556.82 7486.06 -4824.91 457.83 0.00 5932805.76 675517.78 MWD+IFR+MS 9705.42 43.42 178.78 7560.76 7490.00 -4828.64 457.91 0.00 5932802.04 675517.95 CM1 9800.00 43.42 178.78 7629.45 7558.69 -4893.63 459.29 0.00 5932737.10 675520.84 MWD+IFR+MS 9900.00 43.42 178.78 7702.09 7631.33 -4962.35 460.76 0.00 5932668.44 675523.89 MWD+IFR+MS 10000.00 43.42 178.78 7774.72 7703.96 -5031.07 462.22 0.00 5932599.78 675526.94 MWD+IFR+MS 10100.00 43.42 178.78 7847.36 7776.60 -5099.79 463.68 0.00 5932531.12 675530.00 MWD+IFR+MS 10200.00 43.42 178.78 7919.99 7849.23 -5168.50 465.14 0.00 5932462.45 675533.05 MWD+IFR+MS 10217.58 43.42 178.78 7932.76 7862.00 -5180.59 465.40 0.00 5932450.38 675533.59 THRZ 10300.00 43.42 178.78 7992.62 7921.86 -5237.22 466.60 0.00 5932393.79 675536.11 MWD+IFR+MS 10400.00 43.42 178.78 8065.26 7994.50 -5305.94 468.06 0.00 5932325.13 675539.16 MWD+IFR+MS 10448.88 43.42 178.78 8100.76 8030.00 -5339.53 468.78 0.00 5932291.57 675540.66 BHRZ 10500.00 43.42 178.78 8137.89 8067.13 -5374.66 469.52 0.00 5932256.47 675542.22 MWD+IFR+MS s ~ Sperry-Sun BP Planning Report Company: BP Amoco Date: 7/5/2005 Time: 11:37:22 Page: 3 Field: Prudhoe Bay Co•ordinate(NE) Reference: Well: 1427; True North Site: PB DS 14 Vertical ('I'VD) Reference: 42.26 + 28.5 70.8 Well: 1421 Section (VS) Reference: Well (O.OON,O. OOE,173.29Azi) Wellpath: Plan 1421A Survey Cakalation Mekl;od: Minimum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E!W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft ft ft 10510.83 43.42 178.78 8145.76 8075.00 -5382.11 469.68 0.00 5932249.03 675542.55 LCU 10600.00 43.42 178.78 8210.52 8139.76 -5443.38 470.98 0.00 5932187.81 675545.27 MWD+IFR+MS 10700.00 43.42 178.78 8283.16 8212.40 -5512.10 472.44 0.00 5932119.15 675548.33 MWD+IFR+MS 10800.00 43.42 178.78 8355.79 8285.03 -5580.81 473.91 0.00 5932050.49 675551.38 MWD+IFR+MS 10900.00 43.42 178.78 8428.43 8357.67 -5649.53 475.37 0.00 5931981.82 675554.44 MWD+IFR+MS 10956.22 43.42 178.78 8469.26 8398.50 -5688.16 476.19 0.00 5931943.22 675556.16 TJD 11000.00 43.42 178.78 8501.06 8430.30 -5718.25 476.83 0.00 5931913.16 675557.49 MWD+IFR+MS 11009.55 43.42 178.78 8507.99 8437.23 -5724.81 476.97 0.00 5931906.61 675557.78 TJC 11100.00 43.42 178.78 8573.69 8502.93 -5786.97 478.29 0.00 5931844.50 675560.55 MWD+IFR+MS 11200.00 43.42 178.78 8646.33 8575.57 -5855.69 479.75 0.00 5931775.84 675563.60 MWD+IFR+MS 11300.00 43.42 178.78 8718.96 8648.20 -5924.41 481.21 0.00 5931707.18 675566.66 MWD+IFR+MS 11309.94 43.42 178.78 8726.18 8655.42 -5931.23 481.36 0.00 5931700.36 675566.96 TJB 11400.00 43.42 178.78 8791.59 8720.83 -5993.12 482.67 0.00 5931638.52 675569.71 MWD+IFR+MS 11500.00 43.42 178.78 8864.23 8793.47 X061.84 484.13 0.00 5931569.85 675572.77 MWD+IFR+MS 11522.76 43.42 178.78 8880.76 8810.00 -6077.48 484.47 0.00 5931554.23 675573.46 7" 11528.57 43.42 178.78 8884.98 8814.22 -6081.48 484.55 0.00 5931550.24 675573.64 Start Dir 18/10 11551.07 47.47 178.81 8900.76 8830.00 X097.50 4$4.89 18.00 5931534.23 675574.35 TSHU 11600.00 56.28 178.87 8930.94 8860.18 -6135.95 485.66 18.00 5931495.81 675576.02 MWD+IFR+MS 11677.57 70.24 178.94 8965.76 8895.00 -6205.04 486.98 18.00 5931426.77 675578.93 TSAD 11700.00 74.28 178.96 8972.59 8901.83 -6226.39 487.37 18.00 5931405.44 675579.82 MWD+IFR+MS 11754.02 84.00 179.00 8982.76 8912.00 -6279.37 488.31 18.00 5931352.50 675581.99 1421AT1 11800.00 83.96 172.06 8987.59 8916.83 -6324.93 491.87 15.00 5931307.03 675586.61 MWD+IFR+MS 11886.08 84.11 159.08 8996.57 8925.81 -6407.67 513.16 15.00 5931224.82 675609.81 46P 11900.00 84.17 156.98 8997.99 8927.23 -6420.51 518.34 15.00 5931212.11 675615.28 MWD+IFR+MS 12000.00 84.78 141.93 9007.68 8936.92 -6505.97 568.78 15.00 5931127.84 675667.69 MWD+IFR+MS 12026.15 85.00 138.00 9010.01 8939.25 -6525.91 585.53 15.00 5931108.30 675684.89 End Dir :1202 12100.00 85.00 138.00 9016.45 8945.69 -6580.58 634.76 0.00 5931054.79 675735.38 MWD+IFR+MS 12149.40 85.00 138.00 9020.76 8950.00 -6617.15 667.70 0.00 5931018.99 675769.15 45N 12172.34 85.00 138.00 9022.76 8952.00 -6634.13 682.99 0.00 5931002.38 675784.83 45P 12200.00 85.00 138.00 9025.17 8954.41 -6654.60 701.43 0.00 5930982.33 675803.74 MWD+IFR+MS 12275.63 85.00 138.00 9031.77 8961.01 -6710.59 751.84 0.00 5930927.54 675855.44 45P 12300.00 85.00 138.00 9033.89 8963.13 -6728.63 768.09 0.00 5930909.88 675872.10 MWD+IFR+MS 12341.00 85.00 138.00 9037.47 8966.71 -6758.98 795.42 0.00 5930880.17 675900.13 41/2" 12341.24 85.00 138.00 9037.49 8966.73 -6759.16 795.59 0.00 5930880.00 675900.29 1421 A T2 FW: 14-21A wp07 offset wells ( • Subject: FW: 14-21A wp07 offset wells From: "Smith, Phil G (ASRC)" <SmithPGl@BP.com> Date: Thu, 14 Jul 2005 10:52:10 -0800 To: "Tom Maunder (Tom Maunder)" <tom maunder@admin.state.ak.us>, bob_crandall@admin.state.ak.us Bob & Tom, Here's what we came up with on the scan at the planned 7" casing point and TD. See attached anti-collision of the closest ctr-ctr distances: still we have only variations of 14-08A within the 1320' radius. Let me know if there's anything else we can provide. Thanks, Phil «14-21A wp07 Anti-Collision Major Risk and original tool codes.pdf» From: Jakabosky, Troy (SPERRY SUN DRILLING SERVICES) Sent: Thursday, July 14, 2005 10:03 AM To: Smith, Phil G (ASRC) Subject: 14-21A wp07 offset wells A~CrC~N~.Y~~ O'~l Phil -here is a spider plot of 14-21 A. 1 checked all exploration and random wells first, and none showed up. I then checked pads A-Z and 1-18. The only pads that showed up were, 14, 13, and X. « 4-21A wp07 Spider plot.ZlP» 14-21A Depth of 8870 TVD RKB 14-08APB2 2900 ft. 14-09B 1582 ft. 14-22 2133 ft. 14-10 2382 ft. 14-21A at TD and closest point to offset well 14-08A 788 ft. 14-08APB1 823 ft. 14-08AP62 1418 ft. 14-08AL1 1200 ft. 14-08ALP61 1200 ft. 14-09B 1801 ft. 14-22 1796 ft. 14-22A 2035 ft. 14-40A 2473 ft. 14-40 2336 ft. Thanks, Troy. Troy Jakabosky Sperry Drilling (907) 564-5045 BP (907) 632-2609 Cell 1 of 2 7/18/2005 8:25 AM FW: 14-21A wp07 offset wells • • I ~° Sperry Email troy,iakaboskvCo?halliburton.com 14-21A wp07 Content-Description: Anti-Collision Ma Risk and original t 14-21A wp07 Anti-Collision Major Risk and original tool codes.pdf codes.pdf Content-Type: application/octet-s Content-Encoding: base64 _ __ _. Content-Description: 14-21A wp07 Spider plot.Z1P 14-21A wp07 Spider p1ot.ZIP Content-Type: application/x-zip-compressed ', Content-Encoding: base64 2 of 2 7/18/2005 8:25 AM 0 I ~. ~ ~ r 'o COMPANY UI_TAII,S kF.FF:kF:NCF: MFORMATION SURVfV PROGRAM WELL OF"fAII.S IiP Amur C ~Jioare (N 1.)k 1 mw. Wdl Centre: IJ-21. Tmc Nosh Ikgh Fm Ik7Nh Ts Survny~Plwr Tool Nnme -N--S ~E-W Noshing Famng Lnliludc Lwgilmk 51m ' Vcniwl f FVn) k f mu: J22fi - 28.5 ]0 ]6 Cehvlalim Marti: Minimum Cunvurc Sicrim (VS)R I muu Sla (O OON.O.OOF) 8500.00 123JI 2J Annal: 1121A wpD7 Y20 MWn~IFk-Mti 1121 -19]7.02 ]5227 59J7618 JJ 67JW8.17 70'M'06.901N IJ8.35'IJ.&HW NA Frtor Svmem'. ISCWSA Mwwsdlbph kclimnc: J22fi ~IB.S ]076 S Mah d l' C li J N rk C l l u M l d i i wi a . mv y n a a a w n rn a u : M n mum Cunawn: 14_26 (I 4-z(l~p Fn«Surliw. F:IIiryiW «Cesing o06 \ wnming Mala,v: awns n..aa LEGEND 132 - 13-02 (13-02) 141$C>fUl (1p~84_1 13-02A (13-02A) 6A 94-II(4 4~3 13-026(13-02B) \ 13-02BL1 (13-02BL1) 8870-- ~ 13-02BP61 (13-02BPB1) 870,% 13-02BPB2 (13-02BPB2) ~ 8870 I3-02BPB3 (13-028PB3) ~1D ~ 8870 8870 13-03 (13-03) 14-39 (14- - 13-04 (13-04) 164 __ _ _ - 14-38(14- ~~~ 1427 (I4- 4 - - 96 2 ` 1a-30(14-3C ~ 13-05(13-OS) 13-06(13-06) 13 06 3 975 - A (I -06A) 13-06AP61 (13-O6APB1) -- I3-066(13-066) ~X-09 (X-09L1) 6 96 13-07(13-07) 14-09 (I -09) 13-08 (13-OS) / ~ 13-08A (13-08A) 8870 ,I 13-08AP62(13-O8APB2) 8 70 13-09(13-09) 196 9634 ~ X-09 (X-09) ~~7~ ~ / I '' - 870 14-3 (Plan 14-30A) 13-10(13-10) 13-11(13-I I) ~ 13-12(13-12) 14-17 (14 mo 14.10 4-~~1~ 8870 i I3-32(13-32P I3-12A 13- ( 12A) 9078 13-I3 (13-13) 13 13 13 13A 887 / t4-08(14-OS) - ( - ) - 13-14 (13-14) 9412 592 13-IS(13-IS) - 13-16(13-16) 14-09 (14-096) 9185 13-17 (13-17) 13-18 (13-18) Q8 14-17 (14 I~e~78 13-32( 3-32) 13-19(13-19) ~ 14-40 (14-~ 13-20 (13-20) ~ 8981 ~ ~ / 13-21 (13-21) 13 22 13 22 j 14-08 (14-0 ~ P82) 1 2A (14-22A) - ( - ) 13-23 (13-23) 870 ~ 9 ~ 13-23A (13-23A) 8870 8870 - 13-24 (13-24) 13-24(13-24A) ~ 93 870 13-31 (Plan 13-3 13-25(13-25) 6i 13-26(13-26) 14-44 (14-44P gam,, ~8'/0 8870 9037 9202 979 14-22 14-22) 13-27(13-27) _'7 _ 14-08( 4-OSA I) 13-28(13-28) 1408(14-0 ALI BI) 13-28 (Plan 13-28A) - - 14-21 A 40 0 14-09A (14 0'~~Q6~ 13-29(13-29) 13-29 (13- 13-29 (13-29L I ) 13-30(13-30) 8370 14-21 14-21 909ffi ~- 13-31 (13-31) 13-30(13-30A) I3-31 (13-31) 13-31 (Plan 13-31A) '92 - - 13-32(13-32) 13-32(13-32A) 6 ~Q¢6i 9071 \ 14-44 ( 4-44APB I) - ~ 14-OS (14-0 9008 A) 14- 8 (I OSAPB I) -- 13-33(13-33) -- 13-34 (1 3-34) 29~9Q0~ 13-35 (13-35) 29 13 13 I4-44 (14- ~~ / 9026 ( - - -- 13-36 (13- 36) 13-98(13-98 906 ~ 14-44 (14-44 A) ) - 14-01(14-01) ~ 14-01 A (14-01 A) - - ~ - . - 14-02(14-02) 14-02A (14-02A) 24 -- 14-026(14-028) - 14-03(14-03) - 14-03A(14-03A) _ _ i 1 - 14-04(14-04) - 14-04A (14-04A) 14-OS (14-OS) 14-OSA (14-OSA) 14-05 B (14-056) _,-. __ 14-06(14-06) 14-06 (14-06A) 56 14-07 (14-07) -JLBV -JYOV -G04U -I JLV U 1lLU L04U lYbU West(-)/East(+) [1320Win] 14-Vbll4-VEJ - - 14-08 (14-OSA) J - 14-08(14-O8AL1) Re: Proposed 14-21A • • Subject: Re: Proposed 14-21A From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Wed, 13 Ju12005 14:39:08 -0800 To: Phil Smith <smithpgl@bp.com> Phil, Further to my earlier email. It appears that the listing on the wellbore drawing in the application is not correct. The footages are correct, however the section is not correct. went back further in the 14-21 well file and confirmed that the old BHL is in section 16 as is the new BHL. Look forward to what you all will have with regard to "wells within 1/4 mile". The scan should begin at the top of the zone (essentially the 7" liner point) and continue to TD and determine what wellbores or segments lie within 1/4 mile of that planned path. This should include any plugback and "lost" hole sections. Based on the statements in the permit application, there are few proximate well sections. 14-08 is listed, however I think that should be 14-08 A. Most identified wells "drop" out since the penetration (where the well actually enters the SAD) is fairly remote from the area of interest. Call or message with questions. Tom Maunder, PE AOGCC Thomas Maunder wrote: Phil, Further to our conversation. I was looking at the nearby well issue as well. While doing that work, I have not been able to reconcile the top of formation and BHL "footages" listed in block 4a on form 401. Looking at the well profile it appears that the redrill will exit the low side and then come in underneath the old wellbore. On that basis, I believe the section listed for top of formation and BHL are not correct. Based on the directional plots attached to the application I believe that the correct section should be 9 rather than 16. Would you look into this and get back to me. I have also left a message with Jeff, but I don't have his email. One further question regarding "not employing 7" rams". You state that an XO to DP will be available. Is the XO already made up to the joint of DP?? Tom Maunder, PE AOGCC 1 of 1 7/13/2005 2:39 PM RE: Proposed 14-21A • • Subject: RE: Proposed 14-21A From: "Smith, Phil G (ASRC)" <SmithPGl@BP.com> Date: Wed, 13 Ju12005 14:32:08 -0800 To: Thomas Maunder <tom maunder@admin.state.ak.us> I have the original well surface location in section 9, original and new BHLs in section 16. Does that check out on your end too? The XO to drillpipe has a 1/4-turn valve and ready for a joint of DP; much easier to make up that way. Phil -----Original Message----- From: Thomas Maunder [mailto:tom maundere~admin.state.ak.us Sent: Wednesday, July 13, 2005 1:38 PM To: Smith, Phil G (ASRC) Subject: Proposed 14-21A Phil, Further to our conversation. I was looking at the nearby well issue as well. While doing that work, I have not been able to reconcile the top of formation and BHL "footages" listed in block 4a on form 401. Looking at the well profile it appears that the redrill will exit the low side and then come in underneath the old wellbore. On that basis, I believe the section listed for top of formation and BHL are not correct. Based on the directional plots attached to the application I believe that the correct section should be 9 rather than 16. Would you look into this and get back to me. I have also left a message with Jeff, but I don't have his email. One further question regarding "not employing 7" rams". You state that an XO to DP will be available. Is the XO already made up to the joint of DP?? Tom Maunder, PE AOGCC 1 of 1 7/13/2005 2:50 PM ~~ s961.z 6979.1 ~~ a-~~c~ 1~ -c~$ ~1~ -~~ - ~~~.`~, a oa-a~~ I I 1~-l-D~i ~~6a1 obi - c~S Q ts~v-, ~ 3`1 c~~2~~ ~~~ - ~~ - o5i3 ~ssa-o3y 9007.3 9640.7 ~ i• 2~~ :89'61252 ~~~~ Check,... j'~~~ pp?E V UBB`E K INC "Masteroard ~ 1.N N A Bp EXp1066 2, M9 5~g.6g12 ~ $ ~~ o~~~ARS P NCH Rp,GE, PK C A Y TO THE ~ ORpEF of I Bank Alaska at~o^a, g95~~ y L ~2 Fp,~chora9er PK 62.2?nr~'556u MEp^o 6o1.gq Ly..r ~ L ~5 20~~ • • • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITT/CAL LETTQER WELL NAME ,~.T_I T7 CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2} digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (pig records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PIT) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 04/01/05 C\jody\transmittal_checkfist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL-640150 Well Name: PRUDHOE BAY UNIT 14-21A Program SER Well bare seg ^ PTD#:2051070 Company BP EXPLORATION (ALASKA~NC Initial ClasslType SER / 1 WINJ GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal ^ Administration 1 Permit fee attached Yes 2 Lease number appropriat_e_ _ , - _ Yes _ _ _ - _ _ _ 3 Uniquewell_nameandnumber_________________________ _____________Yes_ ____-_-__-_________---.-_---_---_- --------------------------------------- 4 Well located in a_definedpool__,___ ________--_ --__ _-____--__,Yes_ _-___--__ - - 5 Well located proper distance from drilling unitboundary_ . - - Yes -------------------------------------------------------------------- 6 Well located properdistance-f[omotherwells________________ ____________Yes_ __--__ - - 7 Sufficient acreage available in_drillingun~____--__--__ -__-,__--Yes_ -_____-.________--____-._ -- 8 If deviated,is_wellboreplat_included_____________________ ________.,_ Yes__ ___.-_-___--_____.__, ---__--_ - 9 O erator onl _ affected a p y pdy - - - - Yes - - - - - 10 Opetatorhas_appropriate_bondinfprce-------------------- --------_---Yes-- ----------------------------------------------------- ------------------- 11 Permit can be issued without conservation order_______________ _______ ____Yes__ ____-_____--_____--_---__ __--__------_-_--_-_---__----__ -- Appr Date 12 Pe[mit_canbeissuedwjthoutadminist[ative_approval____________ _____________Yes__ -____--._________--_,____._ - - RPC 711412005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by_ Injection Order # (putlQ# in_comments)_(F4r_ Yes - - - AIO.4C- - . _ _ _ _ - - _ - - -- 15 All wells within 114-mile area_of review identified (For service well only)- - - - - - - - - - - - - - -Yes - - - - - - .14-08,14-08Apb1,14-0$Apb2,-14-08A414-08AL1pb1, and 14-08AL1 - - _ _ _ - _ - _ - - _ _ - _ _ _ _ _ - - - - - - - - 16 Pre-produced injector: duration of pre production Less than, 3 months_(F4r service well only) NA. - _ _ - _ _ , _ - - - - - 17 ACMP_Finding of Consistency-has been issued_for this project- _ , _ - _ NA_ _ - _ _ Engineering 18 Conductorst[ing_provided____________________________ ____--, _-.__N_A_-_ ____-C4n_ductorwassetinoriginalwell,D$1.4-21-(182-086),___--______-__---____-_-___-.--_ 19 Surface casing-protects allknpwnUSDWs_________________ ,____--.___--NA__- --__NOaquifers present perAiO4,ConGlusio_n3:.__ ----__ -____----_ ----___--.-___-_-_ 20 CMT_vol_adeguate,tocircu1ate-on conductor_& surf.csg - - _ NA_ Surface casing set in_originalwelL- - _ - - 21 CMT-vol_ adequate,to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ N_A_ _ - _ _ _ _ -Production-casing set in original well ,Planned 7"liner to have 1000' of cement., - - - _ _ _ _ - - _ _ _ _ _ _ - . _ _ _ 22 CMT will cover all known-productive horizons, _ _ _ _ _ Yes - - ... Production, liner_planned_to be fully cemented.- - . - - - - - 23 Casing designs adequateforC,-T,B&_pe[mafcost------- ----- ------------Yes-- ---------.--------- ------------- ---------------- ------------- --- 24 Adequate tankage-or reserve pit _ _ Yes - - - - Rig is_equippedwith steel-pits. No reserve_pitplanned, All waste to approved disposal wells., - - - - - - . 25 If a_re-drill, has_a 10-403 for abandonment been approved _ - _ - _ - . - Yes - - - - 3Q5-182,-move to Commissioners 7/13105._ _ - 26 Adequate wellboreseparation_proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -Yes - - - _ - - -Proximity analysis performed, Close approaches identified.- No wells really proximate except 14-21.- _ - _ _ - _ _ 27 If_diveder required, does it meet regulations, _ - . NA_ - BOP stack_will already_b_e in place, - - _ ------------------------------------- Appr Date 28 Dulling fluid, program schematic.$ equip listadequate_ _ Yes . - Maximum expected formation pressure 7,1_EMW._ Planned MW 11.4 ppg in $,5" hole and 8.6 ppgin Ivishak, TEM 7!1812005 29 BOPEs,-do they meetregulation - - - - - -Yes - 30 BOPS-press rating appropriate; test to-(put psig in comments), - - - - - Yes - - - - - - - - - - - MASP calculatedai 2360psi, 4000-psi_BOP t_estproposed- - - - - - - - - - - - - - - - - - - - - - 31 Choke-manifold complies w/API-RP-53 (,May $4)_ - Yes _ Exceptioq planned to employing 7"_linerrams Re_r 20 AAC 25.435(e)(B)(i)._ BP proposes to-hare a joint of DP_ 32 Work will occur without operation shutdown, Yes . equipped_with a crossoverto the liner.- Per_25,035 (h) (1) this is equally effective. , - - . 33 Is pre&ence-of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - - - H2$ is reported_at DS 14._ Mud should preclude-H2$on_rig.- Rig_is equipped with sensors-and alarms, . - - _ _ _ _ 34 Mechanical-condition of wells within AOR verified (Forservice well only) - _ _ Yes - - . - Although_well sections,ateproximate,-penetrations ace-not. No AOR issues., - - - . Geology 35 Permit_canbeissuedwlohydrogen_sulfidemeasures____________ _________ _-N_o__- -____-____,__-____--____-._ - - 36 Data.presentedon_polentialoverpressurezones_.__---___--__ _____________ NA___ ______--__-_-.__.- --.__ - - Appr Date 37 Seismic analysis. ofshallowgaszones--------------_-_--- _--_-- ___.._ NA_- - __--__________-_____- ___ RPC 7113/2005 38 Seabed condition survey_(ifgff-shore) - _ _ _ _ _ _ _ _ _ _ . _ _ - - . _ _ _ _ _ _ _ . - - _ - NA. _ _ - --__,-_- - _ _ , - - , 39 -Contact namelphone for weekly prggress_reports [exploratory only] _ _ _ _ _ - NA_ _ - _ Geologic Engineering Commissioner: D te Date: Commissioner: mis ' e Date a { / ~~~~ 7''J ~'w ~ r/~ ~/~ ' -V • • Well History File APPENDIX • ~l~~ Jet f~~~ ~y ~ 2Q~~' 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 Weli History file and to simplify trading infom~ation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made 1o chronologically . organize this category of information. • 14-21a.tapx Sperry-Sun Drillin Services LIS Scan Uti~ity $Revision: 3 $ LisLib $Revision: 4 $ Tue Dec 18 08:43:17 2007 Reel Header Service name .............LISTPE Date . ...................07/12/18 Ori gin ...................STS Reel Name...... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/12/18 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF TAPEeHEADEROrd ~L,~t~~~ ~~~ ~ ~ 2a~~ Prudhoe Bay MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003882536 A. SHANAHAN B. DECKER SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • scientific Technical Services scientific Technical services 14-21A 500292075601 BP Exploration Alaska Sperry Drilling Services 18-DEC-07 MWD RUN 2 MW0003882536 A. SHANAHAN J. RALL 9 lON 14E 2715 1562 70.76 42.26 Page 1 MWD RUN 3 MW0003882536 D. RICHARDSO J. RALL 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: • 14-21a.tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8509.0 6.125 7.000 11535.0 C 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK IN THE 14-21 WELLBORE. THE TOP OF THE WHIPSTOCK WAS AT 8509'MD/6700'TVD. 4. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. ONLY SROP DATA ARE PRESENTED FOR RUN 1. 5. MWD RUNS 2,3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUN 2 ALSO INCLUDED PRESSURE WHILE DRILLING (PWD). MWD RUN 3 ALSO INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY -PHASE 4 (EWR4). TIE-IN SGRC DATA OVER THE INTERVAL 8540'MD-8150'MD WERE ACQUIRED DURING A MAD PASS WHILE POOH AFTER REACHING TD ON RUN 2. THESE MAD DATA ARE MERGED WITH RUN 2 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA ONLY (LDWG) WERE SHIFTED TO THE DRESSER-ATLAS CNL GAMMA RAY LOG RUN IN 14-21 ON 7 AUGUST 1982. ALL LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. THESE PDC DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 17 AUGUST 2007, AS AUTHORIZED BY COLE ABEL(BP). 7. MWD RUNS 1-3 REPRESENT WELL 14-21A WITH API#: 50-029-20756-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12339'MD/9037'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 • File Header Service name... .......STSLIB.001 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPM RPD FET 1 14-21a.tapx and clipped curves; all bit runs merged. .5000 START DEPTH 8112.5 8503.0 11512.5 11512.5 11512.5 11512.5 11512.5 STOP DEPTH 12279.5 12331.5 12286.5 12286.5 12286.5 12286.5 12286.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8112.5 8120.5 8120.5 8128.5 8127.5 8136.0 8138.5 8147.5 8166.5 8177.0 8179.0 8190.0 8185.0 8194.5 8198.0 $207.0 8223.0 8230.0 8239.0 $245.0 8279.0 8286.0 8280.5 8288.5 8285.5 8293.0 8356.5 8364.5 8365.0 8374.0 8379.0 8386.5 8391.0 8398.0 8404.5 8413.5 8410.0 8420.0 8429.5 8438.0 8442.5 8452.5 8452.5 8463.5 8470.5 8482.5 8474.5 8486.0 8486.5 8496.0 8495.5 8504.0 8500.5 8507.5 8502.0 8509.5 12331.5 12339.0 Page 3 r~ U MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 1 MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. 14-21a.tapx MERGE TOP 8510.5 8537.0 11536.0 MERGE BASE 8537.0 11536.0 12339.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units .. .. .. ..... Datum Specification Block sub-type...0 • Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8112.5 12331.5 10222 8439 8112.5 12331.5 RPD MWD OHMM 1.14 2000 110.583 1549 11512.5 12286.5 RPM MWD OHMM 2.78 2000 102.554 1549 11512.5 12286.5 RPS MWD OHMM 2.45 2000 78.0477 1549 11512.5 12286.5 RPX MWD OHMM 1.66 2000 72.0288 1549 11512.5 12286.5 FET MWD HOUR 0.49 60.91 2.69642 1549 11512.5 12286.5 GR MWD API 19.73 493.11 124.111 8335 8112.5 12279.5 ROP MWD FT/H 0.09 303.44 94.7234 7658 8503 12331.5 First Reading For Entire File..........8112.5 Last Reading For Entire File...........12331.5 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF Page 4 • • 14-21a.tapx File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RoP 8510.5 8537.0 LOG HEADER DATA DATE LOGGED: 15-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8537.0 TOP LOG INTERVAL (FT): 8509.0 BOTTOM LOG INTERVAL (FT): 8537.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8509.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): .00 MUD VISCOSITY (S): .O MUD PH: .O MUD CHLORIDES (PPM): 0 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 131.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 5 • • 14-21a.tapx TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8510.5 8537 8523.75 54 8510.5 8537 ROP MWDO10 FT/H 2.01 44.92 12.4243 54 8510.5 8537 First Reading For Entire File..........8510.5 Last Reading For Entire File...........8537 File Trailer Service name... .......sTSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......5T5LI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 Page 6 • 14-21a.tapx FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8120.5 11504.5 RoP 8537.5 11536.0 LOG HEADER DATA DATE LOGGED: 19-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11536.0 TOP LOG INTERVAL (FT): 8537.0 BOTTOM LOG INTERVAL (FT): 11536.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 41.6 MAXIMUM ANGLE: 51.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 126027 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8509.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 11.00 MUD VISCOSITY (S): 45.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3): 3.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 147.2 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 7 • • 14-21a.tapx Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 GR MwD020 API 4 1 68 4 2 ROP MwD020 FT/H 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8120.5 11536 9828.25 6832 8120.5 11536 GR MWD020 API 33.24 407.62 134.772 6769 8120.5 11504.5 ROP MWD020 FT/H 2.84 303.44 104.314 5998 8537.5 11536 First Reading For Entire File..........8120.5 Last Reading For Entire File...........11536 File Trailer Service name... .......STSLiB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSL26.004 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11505.0 12287.0 FET 11520.0 12294.0 RPM 11520.0 12294.0 RPS 11520.0 12294.0 RPX 11520.0 12294.0 RPD 11520.0 12294.0 oP 11536.5 12339.0 $ LOG HEADER DATA Page 8 • 14-21a.tapx DATE LOGGED: 22-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12339.0 TOP LOG INTERVAL (FT): 11536.0 BOTTOM LOG INTERVAL (FT): 12339.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.4 MAXIMUM ANGLE: $5,$ TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY $7224 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 11535.0 BOREHOLE CONDITIONS MUD TYPE: Other MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 43.0 MUD PH: $,5 MUD CHLORIDES (PPM): 750 FLUID LOSS (C3): 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .910 78.0 MUD AT MAX CIRCULATING TERMPERATURE: .530 140.0 MUD FILTRATE AT MT: .650 82.0 MUD CAKE AT MT: 1.000 82.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units .. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 Page 9 • • 14-21a.tapx RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MwD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11505 12339 11922 1669 11505 12339 RPD MwD030 OHMM 1.14 2000 110.583 1549 11520 12294 RPM MWD030 OHMM 2.78 2000 102.554 1549 11520 12294 RPS MWD030 OHMM 2.45 2000 78.0477 1549 11520 12294 RPX MWD030 OHMM 1.66 2000 72.0288 1549 11520 12294 FET MWD030 HOUR 0.49 60.91 2.69642 1549 11520 12294 GR MWD030 API 19.73 493.11 78.0244 1565 11505 12287 ROP MWD030 FT/H 0.09 267.87 61.6716 1606 11536.5 12339 First Reading For Entire File.........,11505 Last Reading For Entire File...........12339 File Trailer service name... .......STSLI6.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/12/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........sTSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/12/18 Origin ...................sTS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................sTS LIS Writing Reel Trailer Library. scientific Technical services Service name .............LISTPE Date . ...................07/12/18 Ori 9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number...,..01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF scientific Technical services Page 10 Physical EOF End Of LIS File • 14-21a.tapx Page 11 L`
