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201-235
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC 13-32A PRUDHOE BAY UNIT 13-32A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 13-32A 50-029-20798-01-00 201-235-0 W SPT 8546 2012350 2136 1559 1572 1570 1571 250 443 444 442 4YRTST P Bob Noble 5/17/2025 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 13-32A Inspection Date: Tubing OA Packer Depth 441 2400 2341 2324IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN250518164943 BBL Pumped:6.7 BBL Returned:6.7 Wednesday, July 23, 2025 Page 1 of 1 David Douglas Hilcorp Alaska, LLC Sr. GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 777-8337 E-mail: david.douglas@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By: Date: Date: 08/01/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL Well Name PTD Number API Number 13-32 182-123 50-029-20798-00-00 13-32A 201-235 50-029-20798-01-00 Definitive Directional Surveys (Composited) -Gyrodata Re-Survey 06/20/2024 Main Folder Contents: Please include current contact information if different from above. 13-32A 201-235 50-029-20798-01-00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 18, 2021 TO: Jim Regg " P.I. Supervisor ��-c�(t' `l (� l(Z-r77 j SUBJECT: Mechanical Integrity Tests i Hilcorp North Slope, LLC 13-32A FROM: Guy Cook PRUDHOE BAY UNIT 13-32A Petroleum Inspector Sre: Inspector Reviewed By: PX Supry NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-32A API Well Number 50-029-20798-01-00 Inspector Name: Guy Cook Permit Number: 201-235-0 Inspection Date: 5/13/2021 Insp Num: mitGDC210513062822 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-3'A iTypelnj w 'TVD 8546 'ITubing 1721 1721 1721 1721• ----- PTD 2012350 Type Test sPI "Test psi 2136 IA 542 2480 - 24's - 2410 BBL Pumped: 6 BBL Returned: 6 OA 32 53 - 52 - 52 Interval 4YRTST iP/F I P Notes: Testing completed with a Little Red Services pump truck and calibrated gauges. Tuesday, May 18, 2021 Page I of I • i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ppp' DATE: Wednesday,May 17,2017 P.I.Supervisor � c I �C9G (61ll7 SUBJECT: Mechanical Integrity Tests I t BP EXPLORATION(ALASKA)INC. 13-32A FROM: Matt Herrera PRUDHOE BAY UNIT 13-32A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry y NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT 13-32A API Well Number 50-029-20798-01-00 Inspector Name: Matt Herrera Permit Number: 201-235-0 Inspection Date: 5/16/2017 Insp Num: mitMFH170516172951 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-32A Type Inj W `TVD 8546 Tubing 1759 1760 • 1760 - 1740 - PTD 2012350 Type Test SPT Test psi 2136 - IA 471 2501 2475 - 2466 BBL Pumped: 6.4 ` BBL Returned: 6.4 OA 51 62 63 64 - Interval 4YRTST P/F P Notes: 2500 PSI IA pressure Test Per Operator 17 saws . �� . 1 l0L. Wednesday,May 17,2017 Page 1 of 1 STATE OF ALASKA A KA OIL AND GAS CONSERVATION COMM.—JON REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon❑ Repair Well ❑ Plug Perforations 0 Perforate Other ❑ Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waived] Time Extension❑ Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Dnll Number Name BP Exploration(Alaska),Inc Development ❑ Exploratory I=I 201-235-0 3 Address P O Box 196612 Stratigraphic El Service 0 6.API Number. Anchorage,AK 99519-6612 50-029-20798-01-00 7.Property Designation(Lease Number). 8 Well Name and Number ADL0028315 PBU 13-32A 9 Logs(List logs and submit electronic and printed data per 20AAC25 071) 10 Field/Pool(s) PRUDHOE BAY,PRUDHOE OIL 11 Present Well Condition Summary Total Depth measured 12534 feet Plugs measured 12380feet RECEIVED true vertical 9094 57 feet Junk measured None feet FEB 0 3 2015 Effective Depth measured 12380 feet Packer measured 11191 33 feet y 1Ctrue vertical 8981 44 feet true vertical 8546 3 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"91 5#H-40 39 5-119.5 39 5-119 5 1490 470 Surface 2491 24 13-3/8"72#L-80 39-2530.24 39-2529 78 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12244-12259 feet 12278-12308 feet 12308-12338 feet 12350-12370 feet 12398-12498 feet True Vertical depth 8930 64-8933 35 feet 8937 98-8947 76 feet 8947.76-8960 17 feet 8965.81-8976 feet 8991.83-9064.3 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 5-1/2"BOT PACKER 11191.33 8546.3 Packer None None None SSSV 12 Stimulation or cement squeeze summary' Intervals treated(measured) scop EJ .E. 5 �' rC' Ji S 2.015 Treatment descnptions including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation' 0 0 6248 240 985 Subsequent to operation 0 0 3470 40 1863 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: Oil ❑ Gas ❑ WDSPL ❑ 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 0 Exempt 314-615 Contact Garry Catron Email Garry.Catron(a)BP.Com Printed Name Garry Catron Title PDC PE Signature N �� Phone 564-4424 Date 2/2/2015 It T1.- 2/6/is RBDMSFEB — 4 2015 ,d, `- Y/C-- Form 10-404 Revised 10/2012 Submit Original Only CD Q.0 0 0 0 0 0 0 0 0 co O O co CO N CO OD 0 Ln O_ N N CO N- U S L000cO° ,noo� o 00 O M O) m O 00 co �f t- co I� O) M M I- 00 O) 1"-- LO CO ' CO N- LO d' Ln O) O VO CO V O) V 00 CO V N- O) N Ln O r O CO CO O Ln Ln CO N- CO CO CO O) N CO CO H N- CO Ln O) M O) CO O CO CO N-LO M O (.6N- O fl 00 O) Ln 0.) Lo r 00 CO N- M M to O) in LP) t` CO L) N- CO 00 CO CO CO it = O N CO CO CO V" N a O O) Ln r` r` C) M o 0 f— N M Ln d' Ln CO Ln L0 N r O r r r r N N r r r r r r r r r 41::( O CO VCO CO N (� O a7 Ln .4- r` CO O L1) O V M M r CO M M CV N o C 0.7 O Q Ln o °) o oomooao oo Q I coao 00 °Q a0 CD O J J J J J d 4* o co N N N Ln r *k N �# Co r N_ N- •� fA r` O O) (0 O 00 _ CV _ CO CV CV U O N CA Ln M co co M N r Ln a) Ln N co d' co CO r c o co CO N M � 0) O 4) O r M co CO W W CT)0 Q Q I— 0 0 W FA U W W � D 2 QUU V DcCcCcccEtLiZZ Z W W W W W W m m OF- HZZZZDDD Z Z J J J J Cn I_ \ / � ( 2± \ - c e 0 / @ \% k / � c) u- e/ II / % G \ CD OS \ 0_ / G CN \ 22 _c \ / © © ® % 0001. 4 - (13 II / / / \ \ / D - ® N \ ° - c % - r \ 2 / / C b a = 9 ) c t = --\ \ 7 e % P coo \ / \ :% / / @ o % f _ ■ e# t \ f a \ ® O / + ƒ @ » /f .o * ° = o_ R CD / \ \ \ / f \ 0. c2 ± . � 222 .0 o b • � \ a- IN- oU3 ca c") `v.' c W2 & \ Elco > 2 o q / ' \ 2 co Ix 4) & I e $ m 2 -c = 0 _1 co F3 t \ CDL / CD, ƒ 02 40 » = N / E7c O 10 \k a A o i b \ P.b / � 4- / \ § i _� \ $ CO fes % \ c e/ m o & ö N m = as E o \ 2 = = 2 o £ = r 52 / 8 ot \ \ 7o2 / / 72,- E �� E a o - I .C .= 0 = \ # m / o / 0 / -o \ 0- ® ® Ow \ CO ® 26 -0 \ - = - f f ± , \ § % - § . E g % % c a» E 2 R 5 \ n o y r % c c f m t t c _ -1f 7 ƒ / -J -0 -0 / D \ ƒ - / / R — a - - R e o o - + - m .- - O2 Ot OmeotO * c£ ; in o in . / \ / ► / \ \ MI » » 2 P TREE= GRAY GEN 3 13-321kWELLHEAD= GRAY S T NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI"*WELL REQUIRES A SSSV WHEN ON MI OR= AXELSON �. 87' I - I ***WELL ANGLE >70°011995'*** BF.ELEV= KOP= 2910' ATO. —? ( 1 2214' H5-1/2"OTIS RQ SSSV IMP,D=4.562" Max Angle= 950 @ 11790' _#, , Datum ND= 11653' D= " Datum ND= 8800'SS 13-3/8"CSG,72#,L-80 BUR,D=12.347" —{ 2530' 9-5/8"CSG,47#,L-80 BTRS,D=8.681" --I 10391' 1—>.< x CM' a 10946'-11000'I—5-12"VVFD TPATCH,13=2.97" (01/21/09) Minimum ID =2.377" @ 11636' s $ 3-3/16" X 2-7/8" XO 1.---------11- KR T ,D=a.0O" 1 11111163' ---1-13B75". BKRACK DEROYSLVSLV,D=3.00' 11169' —{3-12"BX PROFILE XO FN, D=2.813" 5-12"TBG-PC,17#,L-80 AB MOD, H 11171' 11171' —15-1/2^BOT FBR ASSY(BMW CT LNR) .0232 bpf,D=4.892' 11169' H3-1/2"BX NP,D=2.813" A ' L. \ 11191' -�9-5/8"X 5-1/2"BOT RCR,D=??" l 11197' �-{_'CLOUT D(1 SIONt D= ??" BEHIND 11198' H_"x 4-1/2"xo,D=3.958" CT LNR TOP OF 7"LNR H 11244' ® 11244' —9-5/8"X 7"BOT MC HYD HGR,D=??" ' ' 11260' —I4-12"OTIS XN NP,MILLED TO 3.80"(1/24/02) 4-1/2"TBG-PC,12.6#,L-80 AB MOD, H 11273' I / v.......„.....--111272' —14-1/T BOT SHEAROUT SUB 11273' —14-112"WLEG,D=3.958" BEHIND .0152 bpf,D=3.958" CT LNR 11260' H ELM TT LOGGED 01/07/90 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,D=2.992" H 11478' • I 11478' --I3-12"X 3-3/16"XO,D=2.786" 9-5/8"cSG,47#,S0095 BTRS,D=8.681" —I 11662' 1--411 I1 TOP OF VVHPSTOCK(TAG 0124/02) H 11578' w/RA TAG @ 11588' MLLOUT WM COW(13-32A) 11580'-11586' 7"LNR,29#,L-80 BUTT,.0371 bpf,0=6.184' H —11578 PBZFOFiATDN Sl>Mv1ARY 11636' H3-3/16"X 2-7/8'XO,D=2.377" REF LOG:MWD GR/RES 01/27/02 ►•1.1.1.1.1.1.1.1 / ANGLE AT TOP PEI :81*@ 12244' 1..0...1 Note:Refer to Roduction DB for historicalperf data 11111111 111111111 ........4 • 12380' 12-7/8"WED CM3P SIZE SPF INTERVAL Opn/Sg2 SHOT SQZ ►11111/1/1111111 (01/11/15) 2" 6 12244-12259 0 01/12/15 ►•1.1.1.1.1.1.1• 2" 6 12278-12308 0 01/12/15 3-3/16'LNR,6.2#,L-80 TCII, —i 11636' 2" 6 12308-12338 0 01/11/15 2" 6 12350-12370 0 01/11/15 0076 bpf,D=2.800' 2" 6 12398-12498 C 01/29/02 PBTD H 12499' ., 2-7/8"LNR,6.16#,L-80 STL, 12534' .0058 bpf,D=2.440' DATE REV BY COMJB'RS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/26/82 ORIGINAL COMPLETION 01/13/15 JLS/JM3 SET CBRADPERFS(01/11-12/15) WELL: 13-32A 01/30/02t1Ol JC'k CTD SIDETRACK 01/15/15 PJC LNR'CSG/TBG CORRECTIONS REMIT Nb: 2012350 07/12/07 DFWTL H BKR SLV/DEPLOY DEPTH AR No: 50-029-20798-01 02/05/09 SEW/SV SET TBG PATCH(01/21/09) Sec.14,T1ON,R14E,1637'FSL 8 1435'FEL 02/09/11 M3/JM.) ADDED SSSV SAFETY NOTE 01/16/12 T1,WJMl ADDED H2S SAFETY NOTE BP Exploration(Alaska) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2e C�� 3 t DATE: Thursday,June 06,2013 P.I.Supervisor ( ( 3 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC 13-32A FROM: Jeff Jones PRUDHOE BAY UNIT 13-32A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry 1.-6E-- Comm Well Name PRUDHOE BAY UNIT 13-32A API Well Number 50-029-20798-01-00 Inspector Name: JeffJones Permit Number: 201-235-0 Inspection Date: 521/2013 Insp Num: mitJJ130606105059 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 13-PA Type Inj W-TVD 8546 IA 571 2496 - 2460 .l 2452 PTD I 2012350 Type Test SPT'Test psil 2136 OA 340 480 480 480 I - i Interval ''4YRTST P/F P Tubing 732 733 731 733 Notes: 6.1 BBLS methanol pumped.One well inspected,no exceptions noted. ScpNNED FEB 2 0 2014 Thursday,June 06,2013 Page 1 of 1 • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 10, 2012 �, ; Y I , `., RECEIVED Mr. Jim Regg AUG 1 5 2012 Alaska OH and Gas Conservation Commission AOGCC 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -13 QD 1 - Dear Mr. Regg, 3 _ 3 aA. Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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 -13 Date: 10131111 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13-02B 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13 -03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA 13 -04 1780630 50029203260000 Sealed conductor NA NA NA NA NA 13-05 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13-06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 -07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13 -08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13-09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13 -10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13-11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 _ 13 -12 1801420 50029205380000 _ Sealed conductor NA NA NA NA NA 13 -13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13-14 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13-16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 182026.0 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA _ NA NA NA 13 -19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13-20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA NA NA NA NA 13 -22 1820770 50029207490000 Sealed conductor NA NA NA NA NA 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 -24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA - 13 -25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13-26 1820740 50029207460000 Sealed conductor NA NA NA NA NA 13 -27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13-28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA NA NA NA 13 -30C 2080870 50029207680300 Sealed conductor , NA NA NA NA NA 13-31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 �V 13-32A 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10131/2011 13-33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13-34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 10/31/2011 13 -35 1940410 50029224600000 0.9 NA _ 0.9 NA 5.1 11/17/2009 13 -36 1951670 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13-37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 50029208780000 1.0 NA 1.0 NA 5.1 10/6/2009 MEMORANDUM To: Tim Regg ~ P.L Supervisor ~~ C'~~ ~ ~ Z 7~~ R~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, March 24, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-32A PRUDHOE BAY UNIT 13-32A Src: Inspector rlnN _rnNFTiIF NTT A T , Reviewed By: P.I. Suprv ~~ Comm Well Name• PRUDHOE BAY UNIT 13-32A • API Well Number: 50-029-20798-01-00 Inspector Name: Bob Noble mitRCN090317050405 Insp Num• Permit Number: 201-235-0 Inspection Date: 311 512 0 09 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-32A Type Inj. W TVD 8546 J IA 800 2540 ,, 2510 2500 P.T. zolz3so TypeTest SPT Test psi z54o OA 1~ lzo lzo lzo Interval °~R P/F P '' Tubing 9zo mo 920 920 Notes• MIT-IA to 2500 psi post patch a, Tuesday, March 24, 2009 Page 1 of 1 OPERABLE: 13-32A (PTD #1350) MITIA Passed post Injection • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIllntegrityEngineer@BP.com] .--~ Sent: Monday, March 23, 2009 4:36 PM ~ ~~~ ~ ~ ~~ ~~~ 9 To: Regg, James B (DOA); Maunder, Thomas E (DOA); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 13-32A (PTD #2012350) MITIA Passed post Injection Hi all, Well 13-32A (PTD #2012350) passed an AOGCC witnessed MITIA on 03/15/09 after the well was returned to injection post patch. The well has been reclassified as Operable. Please let us know if you have any questions. Thank you, Anna 1~u6e, ~.~'. E. Well Integrity Coordinator ~ },-~~~~J ~~~ _ ~~~~~; GPB Wells Group ~`~~/ Rhone: (907} 659-5102 Pager: (907} 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Monday, February 23, 2009 8:42 PM To: NSU, ADW Well Integrity Engineer; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)'; Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GCl/3/F53); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Ce: Townsend, S. Eliot Subject: UNDER EVALUATION; 13-32A (PTD #2012350) Place on injection of UIC MITIA Hi all, Well 13-32A (PTD #2012350) has been repaired with a tubing Datch. A MITIA passed post patch. The well has now been reclassified as Under Evaluation so that it may be placed on injection. Once on injection and stabilized, an AOGCC MITIA will be conducted for UIC compliance. Please place 13-32A on injection as soon as safely posrs~ib_le. Please be aware of possible thermal expansion as the IA is liquid packed. Please let us know if you have any questions. Thank you, Anna 1~u6e, ~ E. Well Integrity Coordinator GPB Wells Group Phone: (907} 659-5102 Pager: (907) 659-5100 x1154 3/24/2009 ~~ STATE OF ALASKA ALAS~OIL AND GAS CONSER~~O$I ~C~~ON REPORT OF SUNDI~Y,W~~I~.O,~EI~AT~ONS ~9 1.Operations Abandon ~ Repair Well Q Plug Perforations mu a Other ~ tubing patch Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~~OfB~aiver~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 1- 201-2350 - 3. Address: P.O. Box 196612 Stratigraphic r Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20798-01-00- 7. KB Elevation (ft): 9. Well Name and Number: 87 KB ~ PBU 13-32A - 8. Property Designation: ~ y~ 10. Field/Pool(s): , ADLO-028315 SQL O~j~,~~g~ "~ PRUDHOE BAY Field/ PRUDHOE BAY Pool 11. Present Well Condition Summary: Total Depth measured 12534 - feet Plugs (measured) None true vertical 9094.57 - feet Junk (measured) None Effective Depth measured 12499 - feet true vertical 9065.13 _ feet Casing Length Size MD TVD Burst Collapse Conductor 79 20" Surface - 119 Surface - 119 Surface 2490 13-3/8" 72# L-80 Surface - 2530 Surface - 2530 5380 2670 Intermediate 11512 9-5/8" 47# L-80 Surface - 11552 Surface - 8821 6870 4760 Liner 336 7"29# L-80 11244 - 11580 8587 - 8842 8160 7020 Sidetrack liner 1378 3-1/2X3-3/16/2-7/8" 11156 - 12534 8520 - 9095 Perforation depth: Measured depth: O 12398 - 12498 _ _ _ _ True Vertical depth: O 8992 - 9064 _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 35 - 11198 4-1/2" 12.6# L-80 11198 - 11273 Packers and SSSV (type and measured depth) 5-1/2" BOT Packer 11191 ~~ 5-1/2" ER PKR 11000 5-1/2" ER PKR 10946 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ,r Treatment descriptions including volumes used and final pressure: -~ ~ ~ .t''J `--~ "' ~~ ~ ~ r, t°~'` 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory r Development r Service ~- Daily Report of Well Operations X 16. Well Status after proposed work: Oil r Gas r WAG ~ GINJ r WINJ r~ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 2/6/2009 Form 10-404 R~sed 04/2006 ,, , 4 .4~ ~~~- ~ ~ a, ~ ~> ~~~~ Submit Original Only ~/.1.~ APB? ~:: • 13-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY h A~~#.~~.l .l~~~~'Y' f - ~•~ 12 5~ 1/1/2009 T/I/0= 50/20/20 Temp= SI Assist Slickline (Pre Tbg Patch) Pumped 5 bbls meth spear followed by 220 bbls 180*F diesel down Tbg while Slickline brushed. Final WHP's=0/0/0. Valve positions at departure: Swab, Wing, SSV, __.. _..___.__._ Master, IA & OA= Open. Slickline on well upon LRS departure. 1/1/2009 ****CONT JOB FROM 12-31-08**** i BRUSH TUBING W/ 4.0" GAUGE RING, 5 1/2" BRUSH. RUN 5 1/2" DUMMY PATCH DRIFT TO TIEBACK SLV 11156' MD. RIH W/ 4.53" CENT, 5' 1 7/8" STEM, 4.54" CENT, 5' 1 7 8" STEM, 5 1/2" DUMMY PATCH DRIFT, TO TIEBACK SLV @ 11,156' MD. ****WELL LEFT S/I, DSO NOTIFIED**** 1/14/2009 ****WELL SHUT IN ON ARRIVAL*** ~ INITIAL T/I/O: 0/0/0 PSI ELINE TO SET LOWER PACKER FOR WFD PATCH. CCL STOP DEPTH: 10986.5'. CCL TO MID ELEMENT: 13.5'. SET DEPTH: 11000' ~ WELL SHUT IN ON DEPARTURE ~ a ~~ ~~ ***JOB COMPLETE*** 1/20/2009 ~ ***WELL S/I ON ARRIVAL*'"* (patch tbg) ~ R/U SLICKLINE UNIT #4516 CURRENTLY PR SURFACE EQUIPMENT ***CONTINUE WSR ON 01-21-09*** ~~ ~ 1/21/2009 ***CONTINUED WSR FROM 01-20-09*** (patch) SET 5 1/2" TBG PATCH ID = 2.97" ,BOTTOM ELEMENT @ 11,000' MD, TOP ~ ***NOTIFY DSO OF WELL CONDITIONS & VALVE POST I N *** TO S NOTE: LEFT ROOF DOORS OPEN, HINGES BROKE, WORK ORDER HAS E BEEN GENERATED ~ 1/27/2009 T/I/0=100/0/0 Temp=S1 MIT-IA to 2500 psi -Incomplete (Post patch)) W unable to perform MITIA due to leaking stem packing on IA valve. Valve crew , was on location to service. Placed a heater on valve and DSO is aware of ~ condition. SV, SSV, WV= Shut. MV, IA, OA= Open. • ! ~~~~~2/1/2009 T/I/O = SSV/0+/0. Temp=Sl. IA FL Pre MIT-IA AOGCC. IA FL @ 130' (10 i bbls). SV,MV,SSV=C. MV=O. IA,OA=OTG. NOVP. 2/2/2009 T/I/0= 60/0/40.Temp=S1 MIT IA PASSED to 2500 psi (Post patch-Pre AOGCC~ Pumped 13 bbls of neat meoh down IA to reach test pressure. On 2nd attempt. IA had no pressure loss in 30 mins. Bled back (-8 bbls). Final WHP= 60/0/40 DSO notified of valve positions as follows: SV,SSV, Wing= closed. MV,IA and OA= open. __J FLUIDS PUMPED BBLS 13 METH 1 MEOH 220 diesel 234 Total 13-32A 201-235 • Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, February 06, 2009 1:20 PM To: Bommarito, Olivia O; Preble, Gary B (SAIC) Cc: Regg, James B (DOA) Subject: RE: 13-32A 201-235 Thanks Olivia. My comment was not directed personally to you. It just seems that there have been several similar issues within the last year. Tom Maunder, PE AOGCC _ _ __ From: Bommarito, Olivia O [mailto:0livia.Bommarito@bp.com] Sent: Friday, February 06, 2009 1:17 PM To: Maunder, Thomas E (DOA); Preble, Gary B (SAIC) CC: Regg, lames B (DOA) Subject: RE: 13-32A 201-235 Torn, There has been sufficient training at BP about the regulations for PBs. It was an oversight on my part and will not happen again. Olivia Bommarito From: Maunder, Thomas E (DOA) [mailtoaom.maunder@alaska.gov] Sent: Friday, February 06, 2009 1:01 PM To: Preble, Gary B (SAIC) Cc: Bommarito, Olivia O; Regg, James B (DOA) Subject: RE: 13-32A 201-235 Gary, Submit the procedure with the 404. It appears that some training might be in order with regard to actions that need a sundry and those that don't. The rules for injection wells are stricter than those for production wells. The Commission reserves the right to pursue an enforcement action on this matter. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Friday, February 06, 2009 11:39 AM To: Maunder, Thomas E (DOA) Cc: Bommarito, Olivia 0 Subject: 13-32A 201-235 Tom, I just discovered a patch job, in progress, on an injector 13-32A (201-235) that never had a 10-403 submitted. It has passed the initial test and they are waiting on the AOGCC to do its final inspection. The PE was unaware that 4/22/2009 13-32A 201-235 ~ Page 2 of 2 a 10-403 was needed. I explained the consequences that could occur for failing to submit the 10-403 for a patch job. Should I submit a 10-403 for this job? Thanks Gary Preb/e /nformatioe Techno%gy and Services Petrotechnica/ Data Team Cooe9dinator 3A/C 907-564-4944 907-35Q6879 4/22/2009 UNDER EVALUATION: 13-32A (PTD #2012350) Place on injection of UIC MITIA Page 1 of 1 Maunder, Thomas E (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Monday, February 23, 2009 8:42 PM To: NSU, ADW Well Integrity Engineer; Regg, James B (DOA}; Maunder, Thomas E (DOA); Rossberg, R Steven; NSU, ADW Well Operations Supervisor; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; GPB, FS3 DS Operators; Bommarito, Olivia O; GPB, Wells Opt Eng; GPB, EOC Specialists Cc: Townsend, S. Eliot Subject: UNDER EVALUATION: 13-32A (PTD #2012350) Place on injection of UIC MITIA Hi all, Well 13-32A (PTD #2012350) has been repaired with a tubing patch. A MITIA passed post patch. The well has now been reclassified as Under Evaluation so that it may be placed on injection. Once on injection and stabilized, an AOGCC MITIA will be conducted for UIC compliance. Please place 13-32A on injection as soon as safely possible. Please be aware of possible thermal expansion as the IA is liquid packed. Please let us know if you have any questions. Thank you, Annrt e, ~'. ell Integrity Coordinator GP ells Group ~I,ne: (so7) 659-5102 Pager: (907} 659-5100 x1154 2/24/2009 From: Maunder, Thomas E (DOA) Sent: Monday, February 23, 2009 10:10 AM To: 'Bommarito, Olivia O' Cc: Preble, Gary B (SAIC) Subject: RE: 13-32A (201-235) status update Olivia, What you propose is acceptable. The pressure test conducted after the patch was placed verifies that pressure integrity has been returned. This is sufficient to return the well to operation. As discussed, Problem Wells will get the "formal" MIT conducted some time after the well has thermally stabilized. Tam Maunder, PE AOGCC From: Bommarito, Olivia O [mailto:Olivia.Bommarito@bp.com] Sent: Monday, February 23, 2009 10:06 AM To: Maunder, Thomas E (DOA) Cc: Preble, Gary B (SAIC) Subject: 13-32A status update z~~~~ ~~~ ~; ~ ZQ~~ Tom- Gary is going to shoot off the 10-404 in a few minutes for the patch work completed on 13-32A back in January. A 10-403 was not submitted pre-patch. The well passed it's preliminary MIT-IA to 2500 psi on 2/2/09. Once the well is put back on injection, we will perform a AOGCC MIT-IA. Once I get a quick aok email from you, I'll work w/ operations to get the well back online. #~)l~virr ~3e~~xatt~~itr~ C~s:3 e €' ~C1C?LI I)` ~ C1~I11£c%I` £~1 ,~~t~s zZtl~.cts~~~ C~` §. 2/23/2009 • ~S • ~~ ProActive Diagnostic Services, Inc. To: ABC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/men Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTl~ 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 F~cploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka 1:R2-1 900 E Benson Blvd. Anchorage, Alaska 99506 and ~-~ e tot- ~3s ProActive Diagnostic Services, Inc. ~~ /~ ~~~ Attn: Robert A. Richey 130 West International Airport Road suiteC ~~~h~~~ AUG ".~ 200$ Anchorage, AK 99518 Fax (907 245.8952 1) Leak ~tection - WLO 26,1un-08 2) C1S 13-32A Signed Print Name: ~,,,~,~~~kytt.~ ~~u~~ PROACTIVE DIAGNOSTIC SERVICES, INGy 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99618 PHONE: (907)245-8851 Fax: (907)245.88952 E-A9AIL .;' ..j~.;~~: • t`~?_.~~ ..~ _.~ WEBSITE _..~~. p - --. _ . C~ C:lDacumentc and Settings\Ownet\Desktop\Transmit_BP.doc ~~~ L~ ~~;~ ` ProActive Diagnostic Services, Inc. To: AOGCC 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/ MTTj 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 Lastuflca LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services,.lnc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245.8952 1) Leak Detection - WLD 22zJun-08 J-206 2) LeakDetection - WLD 20,Jun-08 DS 13-32A l ~\~ ~! ~ r Signed : ~~ ~~ Print fVame: ~` , ~ ` ~,~ Q _ ~~~ r~.. ~i.~~~ s ~ _ ~~I~N~~ JUL ~ 5 2008 1 BL / EDE 50-029-21716-02 1 BL / EI3= 50-029-2079&01 Date PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL, AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E-MAIL. ~~'.° s~3.~1~:. W~ WEBSITE ~i:'a C:\Documenfs and Settings\Owner\Desktop\Ttansmit BP.doc 13-32A (PTD #2012350) Interna~aiver Cancellation -Not Operable • Page 1 of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, December 12, 2007 3:34 PM ~`~'~Y ~ t ~~~ ~I~ ~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, FS3 OTL; GPB, FS3 DS Ops Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; Gerik, Bob G Cc: NSU, ADW Well Integrity Engineer; NSU, ADW Wt Tech; Roschinger, Torin T. Subject: 13-32A (PTD #2012350) Internal Waiver Cancellation -Not Operable ~: All, An internal waiver was issued for TxIA communication on well 13-32A (PTD #2012350) on 01!06/06. Although this well is allowed to inject under dispensation from the Well Integrity System Policy until 12/31/07, the well is already shut-in with no plans to return the well to injection before the end of the year. Therefore, the waiver and Administrative Approval are being cancelled. The well has been reclassified as Not Operable. Please remove all Waivered well signs and the laminated copy of the waiver and AA from the wellhouse. Paperwork will be sent to the AOGCC cancelling the corresponding AA. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~~~ .JAN ~ 3 2D0$ 12/18/2007 • MEMORANDUM To: Jim Regg P.I. Supervisor ~tj if ~ ~,'t)7 FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas ('onservation Commission DATF,: Wednesday, October 31, 2007 SUBJECT: Mechanical Integrity Tests BP LXPLORATION (ALASKA) INC 13-32A PRUDHOE BAY l1NIT 33-32A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name' PRUDHOE BAY UNIT 13-32A Insp Num: mitRCN071030160248 Rel Insp Num: API Well Number: so-oz9-20798-0 l -oo Inspector Name: Bob Noble Permit Number: 201-23s-o .Inspection Date: 1oi28i2oo7 Packer Depth Pretest Initial 15 Min. 30 Min. 45 MIn 60 Min. Well I 13 32A Type Inj. N 'I``7D 8546 IA 180 2550 ~ 2530 2520 ___ _. ___ I_. _.__ _- 2012350 'i ~ SPT ! p __. - , _ _ _ _ _ _._... ~_ ___ P.T. ;TypeTest .Test s>< 2sso OA n 0 0 0 _Interval_ RBQvAR p/F P ./ Tubing.; 3o zslo zzso 2zs° ! ' NOteS: OMIT-TxIA ',: ~,~ ti ~~~ ~~~ Wednesday, October 31, 2007 Page I of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Kef?' 1(~(ù 7 DATE: Wednesday, September 05, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA) INC 13-32A PRUDHOE BAY UNIT 13-32A FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ::J3rz- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-32A API Well Number: 50-029-20798-01-00 Inspector Name: Jeff Jones Insp Num: mitlJ070831 151200 Permit Number: 20 I -235-0 Inspection Date: 8/30/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-32A Type Inj. w TVD 8546 / IA 1040 1050 1040 1040 P.T. 2012350 TypeTest SPT Test psi 2136.5 ./ OA 600 2500 2400 2360 Interval REQVAR P/F P / Tubing 700 700 700 700 Notes: This well has known T x IA communication. 1.7 BBLS dead crude pumped for the MIT-OA. ~ 4è.. ûC.c¡ fìl. 61.oti æ.j CiA."\wJl.. C;t.ty.,- T ~ -2. ¡"\;:>T -ë Æ ./ SCANNED SEP 1 0 2007 \ Wednesday, September 05, 2007 Page I of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~S~;:~isor('rr ~/3.ì/0 7 DATE: Monday, August 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-32A PRUDHOE BAY UNIT 13-32A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv \íß~ - Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-32A API Well Number: 50-029-20798-01-00 Inspector Name: John Crisp Insp Num: mitlCr070826155400 Permit Number: 201-235-0 Inspection Date: 8/25/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-32A Type Inj. N TVD 8546 v IA 340 340 320 320 P.T. ¿u L'~)U TypeTest ' :>1'1 Test psi 2136.5 OA 0 2490 2290 2180 Interval REQVAR P/F F ../ Tubing I 40 20 20 20 Notes: 1.7 bbl's pumped for test. MIT OA for variance. SCANNED S E P 1 o 2007 kf..o 4 C , 004 reg{ , . t. u"es tl/\Il ~ C JÆ:Þí"T ~.J;4 ~ Ctr¡ '\. L{a...( ,~OA Monday, August 27, 2007 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ?/?-¿¿ 'ß13DIO 7 P.I. Supervisor I ~r DATE: Monday, August 27,2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-32A PRUDHOE BAY UNIT 13-32A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ...'Jb'£- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-32A API Well Number: 50-029-20798-01-00 Inspector Name: John Crisp Insp Num: mitlCr070826161547 Permit Number: 201-235-0 Inspection Date: 8/25/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 13-32A Type Inj. N TVD 8546 ;/ IA 300 300 300 290 P.T. i 2012350 TypeTest SPT Test psi 2136.5 OA 2230 2500 2420 2370 Interval REQVAR P/F F / Tubing 20 20 20 20 Notes: .1 bbl pumped for test. Rigged up to the OA WI two block valves one check valve & shut annulus valve for test except to record pressures. ~:S:04-C.OÛC¡ ÌeÓLLtæS CLvtW SCANNED SEP 1 02007 C ¡l,\.:Vr íJ<.J.t+ q;(J Q/I."l<-WL ¡t,CJ>r D,A. Monday, August 27, 2007 Page I of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Q J'?, ( P.I. Supervisor . )\éJ{ ß~) ·0 7 DATE: Monday, August 27, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-32A PRUDHOE BAY UNIT 13-32A FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: Ii!?./? P.I. Suprv Jyr<- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT 13-32A API Well Number: 50-029-20798-01-00 Inspector Name: John Crisp Insp Num: mitlCr070826160829 Permit Number: 201-235-0 Inspection Date: 8/25/2007 Rei Insp N um: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-32A Type Inj. N TVD 8546 . IA 320 320 300 300 300 P.T. 2012350 TypeTest SPT Test psi 2136.5 OA 2180 2500 2400 2330 2270 Interval REQV AR P/F F ./ Tubing 20 20 20 20 20 Notes: .2 bbl pumped for re test.MIT OA for variance. 4:J;o 4-c. DOl - (LV\tLLVL CLar T§.XANNED S E P 1 0 2007 It/lN.,ú;Jl :c,,\,.:.Pr 0.40 Monday, August 27,2007 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commissl TO: Jim Regg P.I. Supervisor K4í¿/ l¡ (-:>{ Dc' l . DATE: Wednesday, November 01,2006 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-32A PRUDHOE BA Y UNIT 13-32A Src: Inspector 'd-"~ ... ';}-?>S '? /~ f)..O\ \ Reviewed By: P.I. Suprv 5S{2- Comm FROM: Chuck Scheve Petroleum Inspector Well Name: PRUDHOE SAY UNIT 13- 32A API Well Number 50-029-20798-01-00 Inspector Name: Chuck Scheve Insp Num: mitCS061 031 071142 Permit Number: 201-235-0 Inspection Date: 10/29/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. ~-, ¡Type Inj. i , -- Well 13-32A N !TVD 8546 IA 400 ¡ 2490 2460 2460 ! : , I ITypeTest t SPT i Test psi -- ^----~-- P.T. 2012350 2136.5 OA 0 ! 0 0 I 0 i i I '-'--- _--.L.____~_----- Interval REQVAR P/F P i Tubing 300 2310 2280 , 2280 i , v I , -- -..,.---- -~ Notes CMIT T x IA NON-CONFIDENTIAL ~l Wednesday, November 01,2006 Page I of I AI.ASSA OIL A1QD GAS COrTS~IiQATi®1dT C®DiMHSSI®1~T 333 W. 7r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 27fi-7542 AD~IIrISTRATIVE APPROVAL AI® -tC'.009 Mr. Steve Rossberg, Wells Manager ~, BP Exploration (Alaska) Inc. ~~~~ ~A~ ~ ~ 200 900 East Benson Blvd. P.O. Box 196612 Anchorage, AK 99~ 19-6612 RE: PBU 13-32A (PTD 241-23~) Request for Administrative Approval Dear VIr. Rossberg: Per Rule 9 of Area Injection Order 004C.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s'~iovember 17, 200 request for administrative approval to inject water in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU 13-32A. The Commission further Inds that, based upon reported results of BPXA-1's di- agnostic procedures, PBU 13-32<4 exhibits two competent barriers to release of well pressure. Accordingly, the Commission believes that the well's condition does not com- promise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to inject water in PBU 13-32A is conditioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tionrates; 3. BPXA shall perform an annual ~IIT - OA to 12 times the maximum anticipated well pressure; 4. BPXA shall perform an annual CNIIT - T x IA to 1.2 times the maximum antici- pated well pressure; ~. BPXA shall limit the well's OA pressure to 1000 psi; FRANK H. MURKOWSKl, GOVERNOR ~Ir. Steve Rossberg December 13, 200 Pale Z of 2 • BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the wen's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good c use shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered timely if it is received by 4:30 P~1 on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. ~ and dated December 13, 200. ~....'~. ~ ~ ~. F l !~/~ r a ~' 1 y~ rr / ,. `~\ r i ~~~ ~ ;~ \ ` i ' •~ ~ ^1 1 a ~ , ~ 7 ~ , 3 __. - /'~ e f ~e ~xkb - , ~ . ~~ 0..P°' ~~ ~ . ,~ Daniel .' eamount, Jr. Commissioner Cathy , . Foerster, Commissioner . . MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc STATUS: 13-32 e e {ì¡i).:#- 'Zð4~:~ " Suhject: STATUS: 13-32A From: "NSU, ADW Well Integrity Engineer" <;"'¡SUADWWclllntegrityEnginccr@BP.com> Bate: Sat 19 No\' 2005 20:32: 14 -0900 -.? I _ To: James Regg <.jim.....regg@admin.state.ak.us> K'1"111 7..7./0':> CC: Winton GAubert <winton..aubcrt@admin.state.ak.us>, "NSU, ADW Well Integrity Enginccr" <NSLADWWclllntcgrityEnginccr@BP.com>, "Luckett, Ely Z. (VECO)" <luckcz@BP.com>, "Holt, Ryan P (VECO)" <Ryan.Holt@BP.com>, "Mielke, Rohert 1..." <rohert.mielke@BP.com>, "Dubc, Anna T" <Anna.Dube(q)BP.com>, "Hughes, Andrea (VECO)" <hugha4@BP.com>, "NSU, ADW Wen Operations Supervisor" <NSUADWWc1l0perationsSupcrvisor@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "Engel, Harry R" <EngeIHR(f/~BP.com> .'. '.~. Hi Jim. An AA requesting continued injection with slow TxIA communication was mailed 11/18/05. The well is currently SI. It is listed on the monthly report. Summary of events: 07/31/05: Bled lAP 1140 > 800, repressured to 940 psi in 30 minutes & 1120 psi overnight 08/01/05: Notified AOGCC of possible TxIA comm 08/04/05: MITIA Failed, 4.2 gpm @ 2500 psi, notified AOGCC of failing MITIA 09/06/05: Bled IA from 950 psi to 250 psi in 2 hours, lAP rose 490 psi overnight 09/24/05: 09/24/05: 09/24/05: 09/24/05: 10/31/05: 11/04/05 : 11/18/05: SL set TTP@ 11169' MD MIT-T to 2500 psi Passed CMIT-TxIA to 2500 psi Passed MIT-OA to 2500 psi Passed CMIT-TxIA Passed to 2500 psi CMIT-TxIA Passed to 2800 psi Mailed AA to AOGCC w/AOGCC Please call with any questions. Joe 1-907-659-5102 f;.:r^~'~'lI:::r·· fi'lEft '1\ I(/! 2'1m: UW"Jrfja~~þi í} ~.."..t. l~cc) ~UUJ -----Original Message----- From: James Regg [mailto:j:Lm regg@aàmin.state.ak.us] Sent: Monday, October 24, 2005 11:02 AM To: NSU, ADW Well Integrity Engineer Cc: Winton GAubert Subject: Status of Injectors w/Failed MITs Need an updated status on the following wells. Also, these wells should be added to the monthly report you provide for injectors unless integrity concerns have been eliminated. PBU 9-25: according to last info we have (email 7/18/05), SI; plan was to take water sample for analysis; any change PBU 13-25: email dated 8/1/05 said this would be added to not showing up in last rpt we received; status? PBU 13-32A: email dated 8/4/05 said would do diagnostics; results? PBU AGI-07: reported failed MIT 8/25; well is not listed in montly rpt; status? PBU AGI-10: status? DIU 1-05/020: well was SI 9/18 after failing MIT; suspect packer leak; well is not listed in montly rpt; status? the well is in status? monthly rpt; reported failed MIT 8/25; well is not listed in montly rpt; Jim Regg AOGCC 1.¢fif. 2- b\~1L- j'ß,e.-- 11/22/20054:37 PM MEMORANDUM ,) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor Kéz1 {l((lloS- DATE: Wednesday, November 09,2005 SUBJECT: Mechanical Integrity Tests SP EXPLORATION (ALASKA) fNC 13-32A PRUDHOE SAY UNIT 13-32A 2P1~~5 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~¡Z- Comm Well Name: PRUDHOE BAY UNIT 13-32A Insp Num: mitCS051l05083116 Rei Insp Num NON-CONFIDENTIAL API Well Number 50-029-20798-01-00 Permit Number: 201-235-0 Inspector Name: Chuck Scheve Inspection Date: 1114/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I 13-32A 1----. 460 '--'r -I ."--.-- Well Type Inj. N TVD 8546 IA 2720 2700 2690 _.._1.......___00_ - I o _·---i--o P.T. ¡ 2012350 TypeTest Test pSi_.__1 2136.5 OA 0 3180_ !- 316~_ 0 Interval OTHER PIF P Tubing 1100 3150 '- Notes CMIT- T x IA Test performed for waiver evaluation. A plug had been set in the tubing tail, pressure was applied to IA with tubing tracking indicating a substantial tubing leak. SCANNEC NO\} 1 71 2005 Wednesday, November 09,2005 Page I of 1 ) ') To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 WELL LOG TRANSMITTAL RECE'~P15, 2003 OCT 2 6 2005 ~". ''1I~mi~sion , I["'!' \ I' \"il~ II hJ Ah~s~(a ~il <~ Am-;hmage RE: MWD Fonnation Evaluation Logs: 13-32A, AK-MW-22009 13-32A: Digital Log Images 50-029-20798-01 ~ J))] ~ 1 CD ROIn PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob K.alish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date:À1 O~r Signed: 1Li ()1;, I SCANNED OC1 3 1 2UU5 ~ F~r~..·W ('fA) - (À.~-}~ It :>... ~ål" ;')~--P¡(L 13-32A (PTD# 2012350) TxIA communication & MIT form ) Subject: 13-32A (PTD# 2012350) TxIA communication & MIT fonn From: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> Date: Thu, 04 Aug 2005 15:09:34 -0800 To: "AOGCC Jim Regg (E-mail)..<jitn_regg@admin.state~ak.us>. "AOGCC Winton Aubert (E~mail)" <winton_aubert@admin.state.ak.us>, Bob Fleckenstein <bob _ fleckenstein@.admin.state.ak.us> CC: "Gerik, Bob 0" <GerikBG@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWW ellOperationsSupervisor@BP.com>, "Engel, Harry R" <EngelHR@BP.com>, "Rossberg, R Steven" <RossbeRS@BP.com>, "GPB, FS3 Area Mgr" <GPBFS3TL@BP~com>, "GPB, FS3 DS Ops Lead" <GPBFS3DSOpsLead@BP.com>, "GPB,WellsOptEng" <GPBWellsOptEng@BP.com?, "Hµghes, Andrea (VECQ)" <hugha4@BP.com>, "NSU, ADWWell Integrity Engineer" <NSUADWWellIntegrityEngineer@BP .com> ) Hello Jim & Winton, --K6f1 51 sl06 Water injection well 13-32A (PTD# 2012350) has confirmed TxlA communication as evidenced by a failing MITIA today. An MITIA to 2500 psi was attempted 08/04/05 and failed with a liquid leak rate of 4.2 / gpm @ 2500 psi. Please find the attached MIT form for wells 13-32A and 13-25 (13-25 to be discussed in separate e-mail). The current plan forward for 13-32A is to perform a pack-off test on the tubing hanger (PPPOT-T) to evaluate if TxlA communication is thru the wellhead. Re-torquing the lock screws could repair the TxlA comm if it is thru the wellhead. Should the tubing hanger prove to have integrity, we will either submit an ./ AA for continued injection on Produced Water only or perform diagnostic work for a potential tubing repair solution jf MI is necessary. Please call if you have any questions. Donald Reeves c~~'.. 6¡.~\.~~\~C SEP 7¿ 1 2005 ~;;)~\~ }"'\nnb .. «MIT PBU 13-25 & 13-32 08-03-05.xls» «13-32A.pdf» From: NSU, ADW Well Integrity Engineer Sent: Monday, August 01, 2005 8: 12 PM To: 'AOGCC Jim Regg (E-mail)'; 'AOGCC Winton Aubert (E-mail)' Cc: Gerik, Bob G; NSU, ADW Well Operations Supervisor; Engel, Harry R; Rossberg, R Steven; GPB, FS3 Area Mgr; GPB, FS3 DS Ops Lead; NSU, ADW Well Integrity Engineer; GPB, Wells Opt Eng; Hughes, Andrea (VECQ); NSU, ADW Well Integrity Engineer Subject: 13-32A (PTD# 2012350) Possible TxIA communication Hello Jim & Winton, Water injection well 13-32A (PTO# 2012350) is exhibiting signs of TxlA communication. The IA was observed to repressure from 800 psi to 940 psi in 30 minutes on 7/31/05 and to 1120 psi overnight. T/I/O pressures on 08/01/05 were 920/1120/220 psi. Recent events: > 07/28/05: lAP tracking Tbg on UIC report > 07/31/05: Bled lAP 1140> 800, repressured to 940 psi in 30 minutes & 1120 psi overnight. The current plan is to conduct an MITIA to 2500 psi. Per AOGCC Area Injection Order No. 4C, Rule 7, 1 of2 8/5/2005 9:22 AM 13-32A (PTD# 2012350) TxIA communication & MIT form please advise as to weather VIiI.;; ~hOUld shut in the well. ) The well has been added to the monthly injection well report. Attached is a wellbore schematic. Please call if you have any questions. « File: 13-32A. pdf » Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907 -659-51 02 907 -659-5100 #1923 pgr .. MIT PBU 13-25 & 13-32 Content-DescrIption: 08-03-05.xls content- Type: Content-Encoding: app lication/vnd.ms-excel base64 Content-Description: 13-32A.pdf Content-Type: application/octet-stream Content-Encoding: base64 20f2 8/5/2005 9:22 AM ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us 1-rf1 øl.;/oS OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / DS 13 08/03/05 Donald Reeves Packer Depth Well 13-25 Type Inj. S TVD 8,388' Tubing P.T.D. 1820910 Type test P Test psi 2,500 Casing Notes: MITIA failed, LLR = 2.7 gpm @ 2500 psi (test was stopped at 15 min) Well 13-32A Type Inj. S TVD 8,546' Tubing P.T.D. 2012350 Type test P Test psi 2,500 Casing Notes: MITIA failed, LLR = 4.2 gpm @ 2500 psi (test was stopped at 15 min) Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test T est psi Casing Notes: Well Type Inj. TVD Tubing P.T.D. Type test Test psi Casing Notes: Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test Notes: If the test was not AOGCC witnessed, leave the "AOGCC REP:" box blank. MIT Report Form Revised: 06/19/02 dJJ \-- :J-.?:5 Pretest Initial 15 Min. 30 Min. 850 850 850 NA Interval 0 600 2,500 1,940 NA P/F F 1,000 1,000 1,000 NA Interval 0 1,060 2,500 2,000 NA P/F F Interval P/F Interval P/F Interval P/F "j6" },i¡. b'tJhíi r.:'[ì"¡ (~E:~'1I) ~,~.:,~ ~li')~L\ \'1 ¡) ~ [~'.'¡ 1...._1 'l,.V :1 J 20n~~~ INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU 13-25 & 13-32 08-03-05.xls Re: 13-32A (PTD# 2012350) Possible TxIA communication ) ) Subject: Re: 13-32A (PTD# 2012350) Possible TxIA communication ("') (f)! ( \<:" 'ß¡jCi, vz, 1)ç From: James Regg <jim_regg@admin.state.ak.us> 'C.\ (, Date: Tue, 02 Aug 2005 15:48:52 -0800 To: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@BP.com> CC: Winton GAubert <\vinton_aubert@admin.state.ak.us> You may continue injecting water only; please forward results of MITs when completed. If repairs are not proposed, an administrative approval will be necessary for the continued operation of this well. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim & Winton, Water injection well 13-32A (PTD# 2012350) is exhibiting signs of TxIA communication. The IA was observed to repressure from 800 psi to 940 psi in 30 minutes on 7/31/05 and to 1120 psi overnight. T/I/O pressures on 08/01/05 were 920/1120/220 psi. Recent events: > 07/28/05: IAP tracking Tbg on UIC report > 07/31/05: Bled IAP 1140 > 800, repressured to 940 psi in 30 minutes & 1120 psi overnight. The current plan is to conduct an MITrA to 2500 psi. Per AOGCC Area Injection Order No. 4C, Rule 7, please advise as to weather we should shut in the well. The well has been added to the monthly injection well report. Attached is a wellbore schematic. Please call if you have any questions. «13-32A.pdf» Thanks, Donald Reeves - Filling in for Joe Anders Well Integrity Engineer 907-659-5102 907-659-5100 #1923 pgr SCANNED AUc.; 0 9 2005 1 of 1 8/2/2005 3 :50 PM '\ ) ) TREE = GRA Y GEN 3 WB..LHEAD = GRA Y ACTUATOR = ··..·"A5(î3::sÖi;;f KB. ELEV = 87' "s Þ: ËLË\Y'; ............. ............... ¡(Ój:> ;';;'" . .... ........ ..... ····2!i1 Oi Max Ang ':~....?~.~.~f!?..~.: Oatum MD = 11653' OatumNO= 8800' SS 13-32A I SAFETY NOTES e 2214' 1-15-1/2" Otis RQ SSSV NIP, D =4.562" I 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2530' ~ ~ Min imum ID = 2.377" @ 11636' 3-3/16" X 2-7/8" XO 11163' 1-13-1/2" BKR DER.OYMENTSLV, 10= 3.00" I l J 11166' - 5-1/2" BOT PBRASSY (BB-iINO CT LNR) I I I 11169' -3-112" BX NIP, 10=2.813" I :g ~ 11191' 1~9-5/8" X 5-112" BOTPKR (BEHINOCTLNR) 13-112" lBG, 9.2#, L-80, .0087bpf, 10=2.992" 1-1 11181' 15-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" 1--1 11198' ITOPOF4-1/2"TBG-FC l-i 11198' \ / 11198' 1--15-1/2" X4-112" XO (BEHINOCTLNR) 1 ITOPOF7"LNR H 11244' t-jI I I I 1 11256' 1--14-1/2" OllS XN NIP, 10 = 3.80" (BB-iINO CT LNR) I .---1 11272' 1--14-1/2" BOT SHEA ROUT SUB (BEHINOCTLNR) ,-- I 1--1 11273' 4-1/2" TUBING TAIL (BB-IINO CT LNR) 1 1 11260' 1--1 ELM TT LOGGEO 01/07/90 1 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, 10= 3.958" H 11273' 1 19-5/8" CSG,47#, L-80/S0095, 10= 8.681" H 11552' µ TOP OF WHIPSTOCK l-i 11578' I 1 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" H 12048' 111 ,I' Jl 11478' 1-13-1/2" X 3-3/16" XO, 10 = 2.786" I 11636' 1-13-3/16" X 2-7/8" XO, D = 2.377" 1 ÆRFORA llON SUMI'v\<\ RY REF LOG: 1VW0GRlRES 01/27102 ANGLEATTOPPERF:55 @ 12398' Note: Refer to Production DB for historical perf data SIZE SPF INTffiVAL Opn/Sqz OATE 2" 6 12398 - 12498 0 01/29/02 3-3/16"TBG,6.2#, L-80, .0076bpf, 10=2.800"1-111479'1 12-7/8" TBG, 6.16#, L-80, .0058 bpf, 10 = 2.440" 1--111638' 12533' l-i PBTO I [)6. TE REV BY COMv'lENTS 08/26/82 ORGINA.L COMPLETION 01/30102 OAC/KK CTO SIDE1RACK OA TE REV BY COMI'v£NTS PRUDHOE BA Y UNIT WELL: 13-32A PERMIT No: 201-235 A A No: 50-029-20798-01 Sec. 14, T10N, R14E. 2513.96 FEL 2583.45 FNL BP Exploration (Alas ka) ! I~J-LYj-i DATA SUBMITTAL COMPLIANCE REPORT 2/26/2004 ---/T Permit to Drill 2012350 Well Name/No. PRUDHOE BAY UNIT 13-32A Operator BP EXPLORATION (ALASKA) INC )~ ~)-j~Mt1~ API No. 50-029-20798-01-00 MD 12534:" REQUIRED INFORMATION TVD 9095 F Completion Date 1/30/2002 -- Completion Status WAGIN Current Status WAGlN L)-/ Mud Log No Samples No Directional Survey ~ DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~"'t- Logl Electr Data Digital Dataset Log Log Run Interval OH I Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments !~t £41385 US\léfjfiØåtløii 1 11569 12488 Case 12/13/2002 I {D D .-r(385i:;J$'Yérificatiòri: 1 11569 12488 Case 12/13/2002 ! -€D C Asc err 969 us\j~rifihå#Qrt>- ; 1,3 11569 12534 Open 6/2/2003 ~ C Pdf 41969 IqqJjçti()ØLRe$i$Ìiÿftý: 25 Final 11594 12534 Open 6/2/2003 MWD - ROP, NGP, DGR, i .. " '.' .. EWR-MD lÞo C Pdf L, 1969 25 Final 11594 9007 Open 6/2/2003 MWD - NGP. DGR, EWR - i MD ¡ Well Cores/Samples Information: Name Interval Start S~p &~ Received Sample Set Number Comments r-""'. ADDITIONAL INFORMATION Y/t) Daily History Received? ~N ~ Well Cored? Chips Received? ~ ~~~n~~ Analysis Received? ..r.L!:!-- Comments: d ~ Date: t/ f1Il~ Æ~ (' (' ê}O / .-&35 -# 1/9&9 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 January 15, 2003 RE: MWD Formation Evaluation Logs: 13-32A, AK-MW-22009 13-32A: Digital Log Images 50-029-20798-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 RECE\VED D~N 02. 2003 Ala.' Oi\ & GasCon&. ~ And\CØ98 ó1-0 r -Jot) BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed~~ ~,(J ~ K~~fý\.~ ( (' aOI-a35 / 1365 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 Anchorage, Alaska December 12, 2002 RE: MWD Formation Evaluation Logs 13-32A, AK-MW-22009 1 LDWG formatted Disc with verification listing. API#: 50-029-20798-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson 'Blvd. Anchorage, Alaska 99508 ~ /"" -. . Si~/--'~~ Date: ECEIV [) DEC 1 3 2002 ,Alaska Œ~ 8; Gas Cons C^m . , A,,¡,. . ..n,¡; misSIOn ,l"1nCllorage ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy 0 Taylor cÞf Chairman DATE: May 20, 2002 SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~ 1)1\ BPX P.I. Superviso,)'J'Y ~( /Û)' OS 13 1-, PBU FROM: Chuck Scheve Prudhoe Bay Petroleum Inspector NON- CONFIDENTIAL Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I traveled to BPXs Drill Site 13 and witnessed the 4-year MIT on wells 13-06A, 13-16, 13-35 and thi initial MIT on well 13-32A. The pretest tubing and casing pressures were observed and found to be stable. The casings were then pressured up and observed for 30 minutes with all 4 wells demonstrating good mechanical integrity. M.I.T.ls performed: ~ Attachments: Number of Failures: Q Total Time during tests: 3 hours cc: M IT report form 5/12/00 L.G. MIT PBU OS 13 5-20-02 CS.xls 4 V P 4 / p I V P 4 V P 6/3/02 } ./~ ., 1 (' ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: MUD ACID STIM 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface Effective depth: measured true vertical Casing Conductor Length 79' 2490' Surface Intermediate 11512' 336' 1378' Liner Sidetrack Liner Perforation depth: Operation shutdown- Pull tubing - Stimulate _X Alter casing - 5. Type of Well: Development - Exploratory- Stratigraphic- Service_X (asp's 685789,5931669) (asp's 679447,5932862) (asp's 679488,5933134) (asp's 679499, 5933158) Plugging - Perforate - Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 87 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-32A 9. Permit number / approval number 201-235 10. API number 50-029-20798-01 11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 12534 feet 9095 feet Plugs (measured) Tagged TD @ 12487 (CTM) (04/04/2002) 12487 feet 9055 feet Junk (measured) 3643'FNL, 1435'FEL, Sec. 14,T10N, R14E,UM At top of productive interval 2296'FNL,2465'FEL,Sec. 15, T10N,R14E,UM At effective depth 2026' FNL, 2417' FEL, Sec. 15, T10N, R14E, UM At total depth 2002' FNL,2406'FEL, Sec. 15, T10N, R14E,UM 12. Present well condition summary Total depth: measured true vertical Size Cemented Measured Depth 20" 2202# Poleset 119' 13-3/8" 1413 sx Fondu, 2032 sx 2530' PF'C' 9-5/8" 500 sx Class 'G', 300 sx 11552' PF'C' 7" 287 sx Class 'G' 11244' - 11580' 3-1/2" X 3-3/16" 69 sx Class 'G' 11156' - 12534' X 2-7/8" measured Open Perfs 12398' - 12498' true vertical Open Perfs 8992' - 9064' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PC- TBG @ 11198' MD. 5-1/2" X 4-1/2" @ 11198'. 4-1/2" 12.6#, L-80 PC-TBG @ 11273' (Behind CT Liner). Alaslca Oil & Gas Cons. Commission Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" BOT PKR @ 11191'. Anchorage 5-1/2" Otis RQ SSSV Nipple @ 2214' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mct Water-Bbl 28670 Prior to well operation 03/28/2002 Subsequent to operation 04/18/2002 15. Attachments Copies of Logs and Surveys run- Daily Report of Well Operations Oil Gas 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¿~ø&P~ Form 1 0-404 Rev 06/15/88 . 16. Status of well classification as: 3958 Title: Technical Assistant O'~'~) '\"") ~ ,,,,\1 II , '\ ~ Suspended ~~\~ '\L ~ ~\!J-\ . True Vertical Depth 119' 25301 8821' 8587' - 8842' 8520' - 9095' ~~: ..~,::,:: "~, \,i1,:'!!'": ~'''>\ ~~'" 'b.".~, [, R) .~ n ?£l()? J 'I,) ~..11 ,. ~.. Casing Pressure Tubing Pressure ? 1219 Service WAG Iniector Date Aoril 30. 2002 Prepared bv DeWavne R. Schnorr 564.5174 SUBMIT IN DUPLICATE ~ " ( (' 13-32A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 03/08/2002 WAIVER COMPLIANCE: AC-MITIA 03/29/2002 ACID: DRIFT/TAG 04/04/2002 ACID: ACID TREATMENT EVENT SUMMARY 03/08/02 MIT-IA PASSED. (PREP FOR AOGCC MIT-IA) 03/29/02 DRIFTED WITH 2.25" CENTRALIZER & SAMPLE BAILER. OVERCOME BY DEVIATION @ 116961 WLM. BAILER CAME BACK EMPTY. LEFT WELL SHUT-IN. NOTIFIED DSO. 04/04/02 PRESSURE TEST. RIH AND TAG TO AT 12487' (CTM). ON LINE WITH NH4CL. INITIAL 1.3 B/M @ 2132 PSI. FINAL: 1.0 BPM @ 2400 PSI. POSITIVE RESPONSE W/ HCL AT PERFS. INITIAL: 1 BPM @ 1715 PSI. FINAL 1.4 BPM AT 938 PSI. HFL: INITIAL: 1.4 BPM @ 940 PSI. FINAL: 1.5 BPM @ 560 PSI. FLUSH WITH 170 NH4CL: FINAL INJECTIVITY: »>1.9 BPM (2726 BPD) @ 1540 PSI.«< ACID TITRATIONS: HCL: 7.8% MUD ACID: 9.10/0 HCL, 1% HF. IRON PPM < 22. ***TURN WELL OVER TO DSO TO PLACE ON PWI*** Fluids Pumped BBLS 0 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 0 TEST) 5.1 METHANOL 111 HCL ACID 50 MUD ACID 190 NH4CL ACID 356.1 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ( ( 1. Status of Well 0 Oil 0 Gas 0 Suspended 0 Abandoned B Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface , 1637' NSL, 1435' WEL, SEC. 14, T10N, R14E, UM ; . At top of productive interval; .1.::..30: C> 2,.' 2983' NSL, 2465' WEL, SEC. 15, T10N, R14E, UM~: ';"L-';;';-~'~~:-' ..: 3~jj~~k~~~~~5' WEL, SEC. 15, T10N, R14E, UM L:~~;:';(ik.",,:..: 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 87' ADL 028314 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 1/25/2002 1/27/2002 1/30/2002 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 12534 9095 FT 12499 9065 FT B Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, RES 23. CASING SIZE 20" 13-3/8" 9-5/8" 7" 3-1/2" x 3-3116 x 2-7/8" Classification of Service Well Water & Gas Injector 7. Permit Number 201-235 8. API Number 50- 029-20798-01 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 13-32Ai 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2214' MD 1900' (Approx.) WT. PER FT. 91.5# 72# 47# 29# 9.2# / 6.2# 6.16# GRADE H-40 L-80 L-80 / SOO-95 L-80 L-80 ASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 79' 30" 202# Poleset Surface 2530' 17-1/2" 1413 sx Fondu 2032 sx PF ICI Surface 11552' 12-1/4" 00 sx Class 'G', 300 sx PF ICI 112441 11580' 8-1/2" 87 sx Class 'G' 11156' 125341 3-3/4" 9 sx Class IG' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 6 spf MD TVD 12398' - 12498' 8992' - 9064' 25. TUBING RECORD SIZE DEPTH SET (MD) 5-1/2", 17#, L-80 111981 4-1/2", 12.6#, L-80 11273' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 20001 Freeze Protected with MeOH PACKER SET (MD) 111911 MD TVD 27. Date First Production March 26, 2002 Date of Test Hours Tested PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Gas Injection PRODUCTION FOR OIL-BBL TEST PERIOD GAs-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-MCF WATER-BBL OIL GRAVITY-API (CORR) CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. SUb~frefhi~. ~ I.,' 1q:o,. ~1":1J '(~,t~1': ~~.':L'I;' 1~ No core samples were taken. 28. ,) I:: '~.- '..,.,.,1' \' ¡.: i ¡ ! j .ÞJaska & Form 10-407 Rev. 07-01-80 R B 0 M S B F l MAY 3 2002 Submit In Duplicate ( ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. Sadlerochit I Zone 48 121681 89221 I;"" t "O< ~~~'I\: r" " ð'''-'~i n ;:f."l;~' ~ \,:,,~ ~l., 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date 0 L{. as-Q:l. 13-32Ai Well Number 201-235 Permit No. / A roval No. Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal. water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced. showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ( ( BP EXPLORATION Page 1 of6 Operations Summary Report Legal Well Name: 13-32 Common Well Name: 13-32A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 1/20/2002 End: 1/30/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Description. of Operations .. .. . .. .. .. ... 1/21/2002 00:00 - 01 :00 1.00 MOB P PRE Continue RD on well J-17B for move to 13-32. Rig released on J-17B at 23:30 on 1-20-02. 01 :00 - 01 :45 0.75 MOB P PRE Pump N2 to blow reel down for rig move. 01:45 - 03:15 1.50 MOB P PRE Continue rig down, Prep to unstab pipe from injector, and spool back on reel. 03:15 - 03:35 0.33 MOB P PRE Safety meeting prior to unstabbing pipe from injector. 03:35 - 06:00 2.42 MOB P PRE Spool pipe back on reel. Secure for transport. Issue hot work permit at 04:30 for installing coil clamp to reel. (Need to cut 2 holes with a cutting torch) 06:00 - 07:00 1.00 MOB P PRE Crew change and tour safety meeting. 07:00 - 09:00 2.00 MOB P PRE Install 2 3/8" and 2-7/8" combi rams in BOP stack for 2 3/8" CT operations. 09:00 - 10:00 1.00 MOB P PRE Lower injector head into pipe bay. 10:00 - 11 :30 1.50 MOB P PRE N/U tree cap and pressure tested with 4000 psi. Good test. 11 :30 - 15:45 4.25 MOB P PRE Derrick Down rig move operations, Rig not on dayrate. Move rig camp, fill tires [low press due to -30F]. Clean rig pits. Vac green tank. Install rams to lower derrick. Inspect rig pits with Tuboscope. 15:45 - 16:00 0.25 MOB P PRE SAFETY MEETING. Review procedure and hazards to pull off well. Check radios. 16:00 - 18:00 2.00 MOB P PRE Jack up rig. Pull rig off of well. Lower wind walls. 18:00 - 18:45 0.75 MOB P PRE Crew change and pre tour safety meeting. Discuss laying derrick over, cold weather safety. 18:45 - 21 :00 2.25 MOB P PRE Lay down derrick. 21 :00 - 22:00 1.00 MOB P PRE Pre Move safety meeting with rig personnel, security, Drilling tool service, CPS. As per ADW SOP. 22:00 - 00:00 2.00 MOB P PRE Begin rig move. Move from J pad to DS 13-32. 1/22/2002 00:00 - 07:30 7.50 MOB P PRE Move rig to DS 6. No problems during move. 07:30 - 12:30 5.00 MOB P PRE Raise derrick and wind walls. -35F, 5 mph. No problems. 12:30 - 13:00 0.50 MOB P PRE PRE-RIG MOVE SAFETY MEETING. With security, tool service, Nordic, BPX. 13:00 - 15:00 2.00 MOB P PRE Move from DS 6 past Security checkpoint and onto OS 13 back pad 15:00 - 17:30 2.50 MOB P PRE PU BOP stack. PJSM w/ DSO. Move rig over tree and set down. Level up 17:30 - 21:00 3.50 MOB P PRE Continue general RU. Chase 6" adaptor flange for flow cross to BOP stack. Take on fuel, water. Fight the elements -35 deg amb 21 :00 - 21 :30 0.50 MOB N PRE Redo 2" reel handling config in prep to load out 21 :30 - 21 :50 0.33 MOB P PRE Safety mtg re: 230T crane limits/reel handling/cold weather 21 :50 - 22:30 0.67 MOB P PRE Remove used 2" CT reel and set on Peak lowboy. Store derrick jacks (10W motor oil doesn't move well at -35) 22:30 - 00:00 1.50 MOB N MISC PRE Remove ODS reel drive flange 1/23/2002 00:00 - 02:00 2.00 MOB N MISC PRE Continue removal of ODS reel drive plate/bushings (tighter fit than expected). Install new one Work on frozen steam lines in cellar 02:00 - 02:10 0.17 MOB P PRE Safety mtg re: 230T crane limits/reel handling/cold weather 02: 1 0 - 03:00 0.83 MOB P PRE Set 2-3/8" reel in reel house. DSM set dike, spot slop tank. RU hardline to flowback tank and PT 03:00 - 04:45 1.75 BOPSUF P DECOMP ND tree cap. NU 6" adaptor flange on top of flow cross. NU BOPE Start normal rig rate for conversion at 0330 hrs 1/23/02 Printed: 2/4/2002 10:32:55 AM ( BP EXPLORATION Operations Summary Report Page 2 af6 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 13-32 13-32A REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 1/20/2002 Rig Release: 1/30/2002 Rig Number: Spud Date: 8/6/1982 End: 1/30/2002 Date From ~To Hours.. Activity Code NPT Phase Description of Operations ... ... ..... .. ... ..... 1/23/2002 04:45 - 06:45 2.00 BOPSUF N HMAN DECOMP Install VBR's below mud cross MO Peak crane at 0600 hrs 06:45 - 07:00 0.25 BOPSUF P DECOMP Crew change PJSM on testing BOPE & finishing reel conversion. Meanwhile warm-up BOP stack. Ambient temp - -40F. 07:00 - 09:00 2.00 BOPSUF P DECOMP RIU outside equipment & tarps for cuttings box & take on 300 bbls 2% KCL water into pits. 09:00 - 10:00 1.00 BOPSUF P DECOMP Start testing BOPE as per BP/AOGCC requirements. Test witnessing waived by AOGCC rep Chuck Scheve. Observe MV & test plug (TWCV?) leaking. 10:00 - 11 :00 1.00 BOPSUF N HMAN DECOMP Confirm BPV instead of TWCV was installed. Callout grease crew to install dart plug on BPV. Meanwhile grind & weld pin onto reel drive motor. 11 :00 - 12:00 1.00 BOPSUF P DECOMP P/U & stand back injector for changing out gripper blocks while testing BOPE. 12:00 - 13:00 1.00 BOPSUF N DECOMP R/U T-bar & install dart plug on BPV. Meanwhile R/U & prep CT reel. 13:00 - 20:30 7.50 BOPSUF P DECOMP Recommence testing BOPE while changing out injector gripper blocks for 2-3/8" CT. Hook up hardline in reel house Rig Accept time is determined to be at 1730 hrs 1/23/02 based on 24 hrs given at normal rig rate for conversion of CT equipment to 2-3/8" 20:30 - 20:40 0.17 BOPSUF P DECOMP Safety mtg re: pull dart and BPV 20:40 - 22:15 1.58 BOPSUF P DECOMP Dry stick dart. RU lubricator and pull BPV, no press on well. RDMO DSM valve crew 22:15 - 00:00 1.75 BOPSUF P DECOMP Continue changing out injector gripper blocks to 2-3/8" 1/24/2002 00:00 - 03:00 3.00 BOPSUF P DECOMP Continue to change out gripper blocks on injector to 2-3/8" 03:00 - 06:00 3.00 BOPSUF P DECOMP Inspect and grease injector bearings. Change packoff 06:00 - 06:30 0.50 RIGU P DECOMP Crew change PJSM on stabing-in CT. 06:30 - 12:30 6.00 RIGU P DECOMP P/U injector & gooseneck. Pull & stab CT. 12:30 - 15:00 2.50 STWHIP P WEXIT R/U & install CTC. Install test plate & pull test to 35k - OK. M/U dart catcher. Launch dart & chase with Coil volume of 59.7bbls. 15:00 - 18:00 3.00 STWHIP P WEXIT M/U MHA & test inner reel valve, CT & MHA to 3500psi. Observe leak on CTC/check valve connection. M/U NRJ & MHA & torq-up w/tongs. Retest to 3500psi - OK. Continue M/U window milling BHA with 2-7/8" straight motor, 3.8" short gage mill & 3.8" NB string reamer. 18:00 - 20:15 2.25 STWHIP P WEXIT RIH w/ window milling BHA #1 circulating out FP fluid to XN nipple. Returns turned to mung water after MeOH returned. Dump 200 bbls and still had black water 20: 15 - 20:55 0.67 STWHIP P WEXIT Tag at XN at 11273' CTD, PUH 40k. RIH 20k, retag and corr to 11243' ELMD. Mill XN nipple 2.5/1050 w/15 stalls. Dress up 20:55 - 21 :05 0.17 STWHIP P WEXIT RIH 50'/min 2.6/1200 and tag pinch pt @ 11575.8'. PUH 40k w/6k overpull. Ease in hole until first motor work at 11575.5'. Corr to 11580', flag CT 21:05 - 23:10 2.08 STWHIP P WEXIT Begin milling window from 11580' 2.5/1070 Mill to 11586.0' where exit of liner occurred. Good amount of metal on magnets 23:10 - 00:00 0.83 STWHIP P WEXIT Drill open hole 11586-596' 1/25/2002 00:00 - 00:30 0.50 STWHIP P WEXIT Dress window. Dry tag twice 00:30 - 02:20 1.83 STWHIP P WEXIT POOH for drilling assy 02:20 - 03:00 0.67 STWHIP P WEXIT LD milling assy. Mill and SR were 3.80" and mill had center wear Printed: 2/4/2002 10:32: 55 AM .. BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: 13-32 Common Well Name: 13-32A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 1/20/2002 End: 1/30/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2002 Rig Name: NORDIC 1 Rig Number: Date From- To Hours Activity Code NPT Phase Description. of Operations .. ... ... .. 1/25/2002 03:00 - 04: 10 1.17 DRILL P PROD1 MU drilling BHA 04:10 - 06:15 2.08 DRILL P PROD1 RIH w/ BHA #2 (2.57 deg SR motor) 06: 15 - 07:25 1.17 DRILL P PROD1 Corr at flag -30.3' to 11558'. Start pump, PUH 44k. Sync MWD & orient TF to 30L. 07:25 - 07:30 0.08 DRILL P PROD1 SD pump (get 1 more click), RIH thru window & tag up @ 11594'. Check TF @ 18R. 07:30 - 09:20 1.83 DRILL P PROD1 Drill build to 11656' with 15-30L TF, 2.8/2.8bpm, 3200/3600psi & 31fph ave ROP. Meanwhile swap well to 8.6ppg FP mud. 09:20 - 09:55 0.58 DRILL P PROD1 Drill to 11664'. Tie-into Sag-River GR Marker (+10 correction). Continue driling to 11678' with 20-30L TF, 2.8/2.8bpm, 3200/3600psi & 38fph ave ROP. 09:55 - 11 :50 1.92 DRILL P PROD1 Orient 2 clicks & drill to 11713' with HS TF, 2.8/2.8bpm, 3450/3700psi & 18fph ave ROP. 11 :50 - 12:20 0.50 DRILL P PROD1 Drill to 11730' with HS TF, 2.8/2.8bpm, 3450/3850psi & 34fph ave ROP. Landed 2 ftvd deeper than planned as 2.57 deg motor is averaging 39 DLS. Decide d to drill ahead with current assembly till catch-up with trajectory. 12:20 - 12:25 0.08 DRILL P PROD1 Wiper to window. 12:25 - 12:35 0.17 DRILL P PROD1 Take check shot survey @ 11675'. 12:35 - 13:10 0.58 DRILL P PROD1 Orient TF to 80R. 13:10 - 14:10 1.00 DRILL P PROD1 Drill to 11743' with 60R TF, 2.8/2.8bpm, 3400/3700psi & 16fph ave ROP. 14:10 - 14:30 0.33 DRILL P PROD1 Drill to 11760 with 70-85R TF, 2.8/2.8bpm, 3400/3700psi & 34fph ave ROP. 14:30 - 14:35 0.08 DRILL P PROD1 Orient TF to 90R. 14:35 - 15:00 0.42 DRILL P PROD1 Drill to 11775' with 90R TF, 2.8/2.8bpm, 3400/3700psi & 36fph ave ROP. 15:00 - 16:00 1.00 DRILL P PROD1 Drill to 11800' with 90-1 OOR TF, 2.8/2.8bpm, 3400/3750psi & 25fph ave ROP. 16:00 - 17:10 1.17 DRILL P PROD1 Drill to 11831' with 100-110R TF, 2.8/2.8bpm, 3400/3750psi & 26fph ave ROP. 17:10 - 17:20 0.17 DRILL P PROD1 Wiper to window. 17:20 - 18:20 1.00 DRILL P PROD1 Take check shot surveys to confirm good azimuth magnetics. 18:20 - 18:30 0.17 DRILL P PROD1 Wiper to window 18:30 - 20:05 1.58 DRILL P PROD1 POOH for lateral assy 20:05 - 20:35 0.50 DRILL P PROD1 LD build assy 20:35 - 22:50 2.25 DRILL P PROD1 MU lateral assy w/ resistivity. Adjust motor to 1.69 deg 22:50 - 00:00 1.17 DRILL P PROD1 RIH w/ BHA #3 (1.69 deg motor) 1/26/2002 00:00 - 01 :00 1.00 DRILL P PROD1 Continue RIH w/ BHA #3 01 :00 - 01 :20 0.33 DRILL P PROD1 Corr -30' at 11530'. Orient to 33L. RIH thru window w/ sli wt loss. Precautionary ream 20'/min to TD 2.5/2950. Tag TD at 11819', corr+12'to 11831' 01 :20 - 02:25 1.08 DRILL P PROD1 Log MAD pass up from TD at 600'/hr 2.5/3050/123L 36.8k Log tie-in up from 11645' 02:25 - 02:35 0.17 DRILL P PROD1 Subtract 4'. RIH to TD at 11826' 02:35 - 03:25 0.83 DRILL P PROD1 Orient to right from 77L and not getting clicks. Go back to window. Can't get them just below window either. Try again in 7" above window and didn't get any either 03:25 - 05: 1 0 1.75 DRILL N DFAL PROD1 POOH for orientor 05: 1 0 - 06:20 1.17 DRILL N DFAL PROD1 Change jet in orientor from 14 to 12. Change motor 06:20 - 06:45 0.42 DRILL N DFAL PROD1 RIH w/ BHA #4 (1.69 deg motor) to 3000'. 06:45 - 07:30 0.75 DRILL N DFAL PROD1 SHT orienter with 6 clicks - not responding. 07:30 - 07:45 0.25 DRILL N DFAL PROD1 POOH for orienter changeout. (' f Printed: 2/4/2002 10:32:55 AM (' ( BP EXPLORATION Page 4 of6 Operations Summary Report Legal Well Name: 13-32 Common Well Name: 13-32A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 1/20/2002 End: 1/30/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2002 Rig Name: NORDIC 1 Rig Number: Date From -To Hours Activity Code NPT Phase Descri ption. of Operations .. ... .. . ... 1/26/2002 07:45 - 09:00 1.25 DRILL N DFAL PROD1 OOH. Changeout orienter. Check motor and bit - OK. 09:00 - 09:30 0.50 DRILL N DFAL PROD1 RIH w/ BHA #5 (1.69 deg motor) to 3000'. 09:30 - 09:35 0.08 DRILL N DFAL PROD1 SHT orienter - OK. 09:35 - 11: 10 1.58 DRILL N DFAL PROD 1 Continue RIH w/ BHA #5 to 11520'. Subtract avg corr of 20'. RIH thru window & tag up @ 11834'. Correct back to 11826'. 11: 10 - 11 :50 0.67 DRILL N DFAL PROD1 Attempt to orient - not getting clicks. PUH, orient to 58R & RBIH. 11 :50 - 12:25 0.58 DRILL P PROD1 Drill to 11839' with 55R TF, 2.8/2.8bpm, 3600/3950psi & 26fph ave ROP. 12:25 - 13:20 0.92 DRILL P PROD1 Orient 1 click & drill to 11860' with 90R TF, 2.8/2.8bpm, 3600/3950psi & 30fph ave ROP. 13:20 - 13:35 0.25 DRILL P PROD1 Orient TF to 60R. 13:35 - 14:00 0.42 DRILL P PROD1 Drill to 11870' with 49R TF, 2.8/2.8bpm, 3600/4000psi & 26fph ave ROP. Observe sudden total losses @ 11860' (possibly fault crossing), then rapidly bounce back to 2.5/2.2bpm @ 11870'. 14:00 - 14:30 0.50 DRILL P PROD1 Drill ahead to 11884' with 52R TF, 2.7/2.5bpm, 3500/3900psi & 27fph ave ROP. 14:30 - 15:50 1.33 DRILL P PROD1 Orient & drill ahead to 11913' with 90R TF, 2.7/2.7bpm, 3500/3900psi & 28fph ave ROP. 15:50 - 16:10 0.33 DRILL P PROD1 Wiper to window. 16:10 -17:40 1.50 DRILL P PROD1 Drill ahead to 11960' with 96R TF, 2.8/2.8bpm, 3550/3950psi & 17fph ave ROP. Still drilling Shublik (+/-100 api). Geo wants to drop angle to 85 degs to intercept Zone-4B. 17:40 - 18:40 1.00 DRILL P PROD1 Start new mud downhole. Orient & drill with 125R TF, 2.7/2. 7bpm, 3600/3950psi. 18:40 - 19:00 0.33 DRILL P PROD1 Wiper from 11980' to 11800' due to stacking 2.5/2.4 3280 19:00 - 19:15 0.25 DRILL P PROD1 Drilling 2.5/2.4 3300/125R at 88 deg 25'/hr 19: 15 - 19:45 0.50 DRILL P PROD1 Wiper to window from 11985' before orient around 19:45 - 20:10 0.42 DRILL P PROD1 Orient around 20:10 - 00:00 3.83 DRILL P PROD1 Drilling from 11985' 2.6/2.5 3450/72R at 85 deg 1 0-35'/hr w/ neg wt. Drill to 12076' in Shublik shale, looking for Z4 1/27/2002 00:00 - 00:10 0.17 DRILL P PROD1 Drilling w/ neg wt in Shublik at 83 deg looking for 242.3/2.2 2950/105R. Drill to 12082' 00:10 - 00:30 0.33 DRILL P PROD1 Wiper to window before orient around 00:30 - 00:55 0.42 DRILL P PROD1 Log tie-in up from 11640' 2.4/2.3 3200 90R 00:55 - 01 :15 0.33 DRILL P PROD1 Add 12.0', RIH. Swap to pump #1 01:15 - 01:25 0.17 DRILL P PROD1 Tag at 12090' corr TD. Geo wants 78 deg. Now at 80 deg at bit. Drill ahead in gradual dive looking for 24 2.5/2.4 3400 116R 20-30'/hr 01 :25 - 01:45 0.33 DRILL P PROD1 Orient around 01 :45 - 02:45 1.00 DRILL P PROD1 Drill Shublik w/ neg wt from 12090-120' at 80 deg. Now at 8826' TVD 02:45 - 03:00 0.25 DRILL P PROD1 Orient to left side 03:00 - 03:25 0.42 DRILL P PROD1 Drill Shublik 12120-130' and had drilling break-must be the mother lode (24), finally 03:25 - 03:45 0.33 DRILL P PROD1 Orient to break the dive, then drill ahead 2.6/2.5 3500 70L 100-120'/hr 12130-141' and progress stopped (can't get wt to bit due to BHA) 03:45 - 04:30 0.75 DRILL P PROD1 Wiper to window from 12141' 04:30 - 05:35 1.08 DRILL P PROD1 Drilling 2.3/2.2 3460 89L 40'/hr which gradually increased to 100'/hr. Drill to 12217' 05:35 - 05:55 0.33 DRILL P PROD1 Orient to drop to TD Printed: 2/4/2002 10:32:55 AM ( (' BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 13-32 Common Well Name: 13-32A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 1/20/2002 End: 1/30/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 1/27/2002 05:55 - 06:10 0.25 DRILL P PROD1 Drilling 2.6/2.5 3600/160R 150'/hr to 12251' and stacking 06: 1 0 - 06:20 0.17 DRILL P PROD1 Wiper to 12100' to smooth out DL's 06:20 - 07:15 0.92 DRILL P PROD1 Drill to 12295' with 2.8/2.7 4050/160R 59'/hr dropping as planned to TD 07:15 - 08:00 0.75 DRILL P PROD1 Wiper trip to TT. Hole in good condition. 08:00 - 09:00 1.00 DRILL P PROD1 RBIH & log GR tie-in (-1' corr). RBIH & try to straighten-out coil wraps. 09:00 - 09:25 0.42 DRILL P PROD1 Orient TF to 160R. 09:25 - 10:30 1.08 DRILL P PROD1 Drill ahead to 12370' with 160R TF, 2.8/2.7bpm, 3600/3800psi & 69fph ave ROP. 10:30 - 11 :05 0.58 DRILL P PROD1 Orient & drill to 12412' with 160R TF, 2.7/2.6bpm, 3500/3900psi & 72fph ave ROP. 11 :05 - 11 :55 0.83 DRILL P PROD1 Wiper trip to window. 11:55-13:35 1.67 DRILL P PROD1 Drill & TD well @ 12530' with 131R TF, 2.8/2.7bpm, 3550/3900psi & 75fph ave ROP. 13:35 - 13:40 0.08 DRILL P PROD1 Shoot survey @ 12509'. 13:40 -14:15 0.58 DRILL P PROD1 Wiper trip to window. Hole in good condition. 14:15 -15:30 1.25 DRILL P PROD1 Log GR tie-in (+5' correction). RBIH & tag TD @ 12534' (9007'vd) -final corrected depth. 15:30 -18:15 2.75 DRILL P PROD1 POOH for liner. Paint EOP flags @ 11000' & 10000'. 18:15 -18:35 0.33 DRILL P PROD1 Crew change & PJSM on LID BHA. 18:35 - 20:30 1.92 DRILL P PROD1 LD drilling BHA. Download res tool 20:30-21:15 0.75 CASE P COMP RU to run liner 21 : 15 - 21 : 30 0.25 CASE P COMP Safety mtg re: liner 21 :30 - 00:00 2.50 CASE P COMP MU 27 jts 2-7/8" 6.16# L-80 STL w/ float equipment and turbos, 5 jts 3-3/16" 6.2# L-80 TC11, 10 jts 3-1/2" 9.2# L-80 STL 1/28/2002 00:00 - 01 :00 1.00 CASE P COMP Continue MU liners 01 :00 - 02:05 1.08 CASE P COMP MU Baker Deployment Sub, Tieback Sleeve, CTLRT. Install Baker CTC. PT 35k, 3500 psi 02:05 - 04:30 2.42 CASE P COMP RI H w/liner on CT. See flag at 11406', did not corr to 11390'. PU 38k. RIH thru window 18k. A few bobbles along the way. See second flag -16' off also. RIH to TD at 11551' CTD (drilled TD is 12534'). Attempt to recip and called it quits at 55k (hole was rough last 100'). Park w/ shoe at TD 04:30 - 05:25 0.92 CASE P COMP Load 5/8" steel ball. Circ to seat w/ mud 2.2/2.1 2220 and sheared seat at 4100 psi. Release from liner at 32k 05:25 - 08:30 3.08 CASE P COMP Displace well to 2% KCI at 2.5/2.4bpm & 1185psi. Meanwhile R/U Dowell cementers. 08:30 - 08:45 0.25 CASE P COMP PJSM with all personnel concerning cementing operations. 08:45 - 11: 15 2.50 CASE P COMP Batch mix 20 bbls 15.8ppg cmt with additives. Cmt to wt @ 09:20 hrs. Flush/PT lines to 4k. Pumped 14 bbls cmt slurry @ 1.8/1.7 bpm & 1170 psi. Close inner reel valve & clean lines. Loadllaunch CTWP & confirm launch. Chase with KCL @ 2.6/2.5bpm & 1250psi. CTWP engage LWP at 59.4 bbls away. Shear plug with 3200psi. Continue displacing LWP @ & bump @ 68.3 bbls away. 12.5 bbls cmt behind 1m. Floats held. Pressure up to 1000 psi & sting out of liner. Displace & wash-up on TOL with 25 bbl biozan. CIP at 10:50 hrs. 11:15 -13:15 2.00 CASE P COMP POOH with CTLRT to 250'. Meanhile RD cementers. 13:15 - 13:45 0.50 CASE P COMP Nordic Crew change. PJSM on LID BHA. 13:45 - 14:30 0.75 CASE P COMP Tally accessories for liner cleanout BHA. Meanwhile circulate CT & BHA. 14:30 - 14:45 0.25 CASE P COMP OOH. R/B injector & LID CTLRT. Printed: 2/4/2002 10:32:55 AM ( - (' BP EXPLORATION Page 6 of6 Operations Summary Report Legal Well Name: 13-32 Common Well Name: 13-32A Spud Date: 8/6/1982 Event Name: REENTER+COMPLETE Start: 1/20/2002 End: 1/30/2002 Contractor Name: NORDIC CALISTA Rig Release: 1/30/2002 Rig Name: NORDIC 1 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations . .. 1/28/2002 14:45 - 15:00 0.25 CASE P COMP PJSM on on P/U 1-1/4" CHS tbg & liner cleanout BHA. 15:00 - 15:30 0.50 CASE P COMP R/U floor for RIH liner cleanout BHA. 15:30 -18:10 2.67 CASE P COMP P/U BHA #7 (1587.04') with 2.3" D331 mill, 2-1/8" motor & 50 jts of 1-1/4" CSH tbg. M/U injector. 18:10 - 20:00 1.83 CASE P COMP RIH with cleanout BHA#7. 20:00 - 20:30 0.50 CASE P COMP Cement comp str =1460 psi. Start motor above TOL and precautionary ream to TD 1.5/1340, clean. Tag TD at 12518' CTD (liner tally depth was 12498.69', normal corr) 20:30 - 22:00 1.50 CASE P COMP POOH circ'ing at max rate w/ fresh KCL 22:00 - 23:20 1.33 CASE P COMP Standback CSH 23:20 - 00:00 0.67 CASE P COMP Comp str 1730 psi. Install tree cap. Pressure IA from 120 to 1000 psi w/ diesel 1/29/2002 00:00 - 08:00 8.00 CEMT P COMP Cement comp str 1830 psi. WOC 1900 psi @ 0330 hrs, 2081 psi @ 0530 hrs 08:00 - 08: 15 0.25 CEMT P COMP PJSM on future operations. 08:15 - 10:30 2.25 CEMT P COMP Line up to & test liner lap. Compressive strength of cement @ 08:00 was @ 21 OOpsi. fA 850 psi @ onset of test. Staged up in 500 psi intervals, monitoring I/A. PT @ 2000 psi, leaked 600 psi in 30 mins, no change in IA pressure thoughout test. Repressured to 1000psi, leaked 150 psi in 15 mins. Review forward plan with town & decide to go for perf guns and let Wells Group run L TP when available. 10:30 - 10:45 0.25 PERF P COMP PJSM & HAlHM on perforation job. 10:45 - 13:00 2.25 PERF P COMP P/U & RIH 5 jts of 2" HSD 6spf perf guns. P/U & RIH 25 stds of 1-1/4" CSH workstring. 13:00 - 15:30 2.50 PERF P COMP MU injector. RIH with perf guns. Tag bottom @ 12514'. 15:30 - 15:45 0.25 PERF P COMP PJSM & HAlHM on pumping bleach pill. Emphasize on proper PPE, spill prevention & good communication. 15:45 - 16:20 0.58 PERF P COMP Line up to & pump 16 bbls 6ppb lithium hyperchlorite followed by 2 bbls of rinse freshwater behind. 16:20 -17:15 0.92 PERF P COMP Load 5/8" ball & circ down while positioning guns for bottom shot at top of PBTD (12498'). Pump ball on seat @ 52.4 bbls away. Meanwhile rinseout bleach truck with 30 bbls water for filling hole while POOH. 17:15 -17:20 0.08 PERF P COMP Pressure up to 31 OOpsi & observe guns fire.. Perf Intervals: 12398'-12498'. 17:20 - 19:00 1.67 PERF P COMP POOH with guns filling hole via the annulus. Hole stable. 19:00 - 19:15 0.25 PERF P COMP Safety mtg re: CSH 19:15 - 21:45 2.50 PERF P COMP LD 50 jts CSH (wet string) 21:45 - 22:00 0.25 PERF P COMP Safety mtg re: perf guns 22:00 - 22:40 0.67 PERF P COMP LD perf guns-all shots fired. Load out guns 22:40 - 00:00 1.33 WHSUR P COMP RU nozzle BHA. RIH w/ CT to 2000'. POOH after freeze protecting 1/30/2002 00:00 - 00:15 0.25 WHSUR P COMP Fin POOH after FP. SI master. Jet stack 00: 15 - 00:40 0.42 WHSUR N COMP Circ, WO DS N2 pumper 00:40 - 02: 15 1.58 WHSUR N COMP Circ while RU to pump N2 and PT. PJSM 02:15 - 03:30 1.25 RIGD P COMP Displace CT w/ N2 and bleed off. Vac pits, load out misc equipment 03:30 - 04:30 1.00 RIGD P COMP Safety mtg re: set BPV. Bring tools to rig floor. DSM set 6" BPV in Gray hanger. Load out tools 04:30 - 06:00 1.50 RIGD P COMP ND BOPE 06:00 - 0.00 RIGD P COMP Rig Released at 0600 hrs 1/30/02. Cut CTC. Unstab CT. LD gooseneck. Set injector in box Printed: 2/4/2002 10:32: 55 AM (' ( AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 13-32A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11 ,500.00' MD Window / Kickoff Survey 11,582.00' MD (if applicable) Projected Survey: 12,534.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED FEB 20 2002 Al8taOl&GesCona . Anchõiagé ~r! Attachment(s) '.'~..I)¡l"'~:~".i"..$..."'.i':~': ' 0. '.. .:~I.~,..'.,..,.,"~~I..',":,I'",.".'."',., '"".',, ,.'.',,\11'," I,',', ',,' r " I" I I, LI'''~ " '...:\>';':~,I;.~..;'L "'". . , I',. ," L- I 12-Feb-02 -'- North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 13, Slot 13-32 13-32A Job No. AKMW22009, Surveyed: 27 January, 2002 ~, SURVEY REPORT 11 February, 2002 Your Ref: API 500292079801 Surface Coordinates: 5931669.20 N, 685789.09 E (70013' 05.8543- N, 148030' 04.1437- W) Kelly Bushing: 87.00ft above Mean Sea Level ~" spel''',:/-EiUI! DRILLING seRVices A Halliburton Company Survey Ref: svy11099 Sperry-Sun Drilling Services . Survey Report for 13..32A Your Ref: API 500292079801 Job No. AKMW22009, Surveyed: 27 January, 2002 Alaska Drilling & Wells North Slope Alaska PBU_EOA DS 13 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastings Northlngs Eastlngs Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (° /1 OOft) 11500.00 41.000 290.000 8694.36 8781.36 913.62 N 6047.29 W 5932433.69 N 679721.15 E 2926.82 Tie On Point MWD Magnetic ~ 11582.00 40.580 293.990 8756.46 8843.46 933.67 N 6096.94 W 5932452.51 N 679671.02 E 3.219 2962.64 Window Point 11593.21 42.620 300.000 8764.84 8851.84 937.05 N 6103.56 W 5932455.73 N 679664.31 E 39.961 2968.08 11636.09 60.030 298.000 8791.54 8878.54 953.15 N 6132.76 W 5932471.11 N 679634.73 E 40.761 2993.20 11652.80 62.970 294.000 8799.51 8886.51 959.58 N 6145.96 W 5932477.21 N 679621.38 E 27.421 3003.75 11686.05 73.120 284.000 8811.96 8898.96 969.50 N 6175.06 W 5932486.41 N 679592.04 E 41.311 3023.03 11721.10 87.680 283.100 8817.79 8904.79 977.57 N 6208.57 W 5932493.65 N 679558.34 E 41.617 3042.07 11751.08 93.800 291.710 8817.40 8904.40 986.52 N 6237.13 W 5932501.90 N 679529.56 E 35.222 3060.25 11788.13 94.600 305.190 8814.67 8901.67 1004.08 N 6269.55 W 5932518.66 N 679496.73 E 36.349 3087.84 11822.48 90.660 318.490 8813.09 8900.09 1026.92 N 6295.04 W 5932540.86 N 679470.68 E 40.336 3118.02 11850.28 90.930 323.950 8812.70 8899.70 1048.58 N 6312.45 W 5932562.09 N 679452.74 E 19.662 3144.33 11878.58 94.010 332.930 8811.48 8898.48 1072.64 N 6327.23 W 5932585.78 N 679437.37 E 33.514 3172.00 11910.13 93.830 340.690 8809.32 8896.32 1101.56 N 6339.62 W 5932614.38 N 679424.28 E 24.545 3203.40 11940.31 91.010 347.210 8808.04 8895.04 1130.52 N 6347.95 W 5932643.12 N 679415.24 E 23.518 3233.46 11975.06 84.850 353.200 8809.30 8896.30 1164.70 N 6353.85 W 5932677.16 N 679408.49 E 24.712 3267.61 12005.98 84.850 2.360 8812.08 8899.08 1195.44 N 6355.04 W 5932707.86 N 679406.55 E 29.505 3296.90 12037.93 84.580 10.820 8815.03 8902.03 1227.02 N 6351.40 W 5932739.51 N 679409.42 E 26.380 3325.32 12073.88 81.940 15.580 8819.25 8906.25 1261.76 N 6343.25 W 5932774.45 N 679416.70 E 15.060 3355.19 ---... 12105.18 80.000 24.920 8824.17 8911.17 1290.73 N 6332.57 W 5932803.67 N 679426.67 E 30.113 3378.76 12134.93 79.380 22.800 8829.50 8916.50 1317.50 N 6320.73 W 5932830.72 N 679437.84 E 7.314 3399.86 12167.21 81.590 13.640 8834.85 8921.85 1347.70 N 6310.80 W 5932861.16 N 679447.03 E 28.809 3424.85 12225.01 85.370 2.360 8841.43 8928.43 1404.47 N 6302.84 W 5932918.10 N 679453.59 E 20.459 3475.47 12272.68 74.980 3.070 8849.55 8936.55 1451.32 N 6300.62 W 5932965.00 N 679454.65 E 21.845 3518.74 12303.43 68.900 4.300 8859.08 8946.08 1480.48 N 6298.75 W 5932994.20 N 679455.81 E 20.134 3545.50 12351.56 60.700 10.470 8879.57 8966.57 1523.62 N 6293.24 W 5933037.45 N 679460.25 E 20.601 3584.15 12386.81 55.240 15.230 8898.27 8985.27 1552.74 N 6286.64 W 5933066.73 N 679466.14 E 19.255 3609.25 12421.96 48.020 19.280 8920.08 9007.08 1579.04 N 6278.52 W 5933093.22 N 679473.61 E 22.432 3631.19 12460.13 40.970 21.040 8947.29 9034.29 1604.15N 6269.33 W 5933118.54 N 679482.18 E 18.749 3651.64 12492.73 35.070 24.210 8972.96 9059.96 1622.68 N 6261.64 W 5933137.26 N 679489.40 E 19.058 3666.43 12509.01 32.510 28.440 8986.49 9073.49 1630.80 N 6257.64 W 5933145.47 N 679493.21 E 21.348 3672,69 --- -- ------ -_.----- -- --- - --- - --- 11 February, 2002. 12:56 Page 2 0'4 DrillQlIest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 13-32A Your Ref: API 500292079801 Job No. AKMW22009, Surveyed: 27 January, 2002 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 12534.00 32.510 28.440 9007.57 9094.57 Local Coordinates Northlngs Eastlngs (ft) (ft) Global Coordinates Northlngs Eastlngs (ft) (ft) 6251.24 W 1642.61 N 5933157.44 N 679499.31 E '- All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Magnetic Declination at Surface is 26.498° (24-Jan-02) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well Reference and calculated along an Azimuth of 340.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12534.00ft., The Bottom Hole Displacement is 6463.45ft., in the Direction of 284.722° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 11500.00 11582.00 12534.00 8781.36 8843.46 9094.57 913.62 N 933.67 N 1642.61 N 6047.29 W 6096.94 W 6251.24 W Tie On Point Window Point Projected Survey 11 February, 2002 - 12:56 Page 30f4 . Alaska Drilling & Wells PBU_EOA DS 13 Dogleg Vertical Rate Section (0/100ft) Comment 0.000 3681.60 Projected Survey ~, ~, DrillQuest 2.00.08.005 sperry-Sun Drilling Services': Survey Report for 13-32A Your Ref: API 500292079801 Job No. AKMW22009, Surveyed: 27 January, 2002 . North Slope Alaska Alaska Drilling & Wells PBU_EOA DS 13 Survey tool program for 13-32A From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) r-"', '- 0.00 11500.00 0.00 11500.00 8781.36 12534.00 8781.36 AK-1 BP _HG - BP High Accuracy Gyro (13-32) 9094.57 MWD Magnetic (13-32A) ~, - .~.__. ._- -.-- 11 February, 2002 - 12:56 Page 4 0(4 DrillQuest 2.00.08.005 ( ( \'. MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L -1 04 Date Dispatched: 6-Feb-02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Flo ies Surveys 2 Received By: ~'I.O~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 em Sidetrack 13-32Ai, Demonstration of Isolation ( ( " Subject: CTD Sidetrack 13-32AI, Demonstration of Isolation Date: Wed, 9 Jan 2002 13:47:31 -0600 From: "Sherwood, Alistair" <SherwooA@BP.com> To: "'Tom Maunder, (AOGCC)'" <tom_maunder@admin.state.ak.us> Tom, Reference 13-32 completion schematic & eBl log section faxed to your office, (276-7542) today. Condition's of approval on 13-32Ai permit to drill, (201-235) stipulate that the cemented 3-1/2" x 3-3/16" x 2-7/8" completion be MIT'd and a eBl run. We are not planning on running a eBl as I believe regulation 25.030 d7, (isolation of injection fluids) can be satisfied with the following: Reference eBl log attachment; The whipstock has been set in 7" csg, the top being 11,578' md. This will result in an 11,682' md top of 7" window penetration when milled. The formation adjacent to the exit is Sag River with TSAG being 11,577'. Kavik is therefore not touched. Interpretation of the 180 ft of eBl amplitude curve shown on the attachment, indicates a good quality cement job above the window. Infact good quality cement extends up to 11,290',45' below the 7" liner packer at 11,244'. So assuming a good 4,OOOpsi MIT on the sidetrack completion prior to perforating, isolation of injection fluids based on this evidence can be demonstrated. Please advise if you disagree with this reasoning. Regards Alistair Sherwood Coil Tubing Drilling Engineer Greater Prudhoe Bay BP Exploration (Alaska) 900 E. Benson Blvd, Anchorage. +(907) 564 4378 +(907) 440 8301 ~ P~rt 1.2.1- T~pe~ apPïication/ms-tnef,1 I ~ ,Encoding: base64 _.._-------~-~_...~-..............._------_.~..'-- 1 of 1 \ '15 d - \;)~ da\-d-~S- 2/27/02 11 :30 AM ~tVl !VWNi't( A.tX3Ct z.(6 -79fz, Au71Ã1,( Jib&J(To!) 56¥ -SSIO 01/09/2002 11.:52 FAX 907 564 5510 (' RDUI lIP IlASD DRILUNG & WEUS TO: COMPANY: FAX: FROM: FAX: bp I4J () () 1 DATE: ~ ~ ~Jas~~ nil R, r,::i~ r.nn~ GOíml1'~If" ¡ Anchorage PHONE: fjß~I~6 sz,C/ 43>f23 MESSAGE: 1ðNl/~ff +u ~ff~~ 6 ~ ~ I~ M my ~,~ 60f7- . fy~ , ~ . t¿, Number of attachments not includinQ fax cover: 01/09/2002 11:52 .FAX 907 564 5510 bp 13-32Ai PROPOSED CTD SIDETRACK TREE = GRA Y GEN 3 WB-LHEAD= GRAY ACTUATOR = AXB...SON KB. ELEV = 87' BF. ELEV = KOP= ' Max Angle = Datum MD = Datum ND = 2910' 7100' 11639' 8800'55 113-3/8" CSG, 72#, L-BO, ID = 12.347" I 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" -t Minimum ID = 3.725" @ 11256' 4-1/2" OTIS XN NIPPLE I Proposed TOe = 11,200' I ITOPOF 4-1/2" TBG-PC 1-1 llop OF 7".~~~ ¡ToP of Froposed 3-1/2" Liner 1-111220'1 \4-1/2" lEG-PC, 12,6#, L-BO, 0,0152 bpf, 10" 3.958" 1 11273' ~ CSG, 47#, L-80/S00es, ID = 8.681" I IToP of Proposed Whipstock I PERFORATION SUMMARY REF LOG: BHCS ON 08/21/82 ANGLE AT TOP PERF: 41 @ 11585' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 11585-11595 0 06/20/92 3.3/8" 4 11605-11615 0 06/20/92 3-3/8" 4 11676-11714 0 12/11/85 3-1/8" 4 11725-11785 0 11/27/82 3-1/8" 4 11795-11B01 0 11/27/82 3-1/8" 4 11814-11820 0 11/27/82 3-1/8" 4 11826.11846 0 11/27/82 3-1/8" 4 11856-11866 0 11/27/82 17" Lt'-IR, 29#. L-BO, .0371 bpf, ID = 6.1B4" I 12048' r4J 0 () 2 f SAFETY NOTES ~ - - " "1 8 -15-1/2" Otis RQ SSSV NIP, to = 4.562" I I Proposed TOL = 11,155' 1'-' 5-1/2" BOT PBR ^¥Yl 1-19-5/8" X 5-1/2" aaT ~R I -15-1/2" X 4-1/2" XO 1 :; ::1 I ~ I .~.! -14-1/2" BOT SHEAROUT SUB 1 4-1/2" TUBING 'TAIL ELM 1T LOGGED Õ_1/07/90 J 2-7/8" 8T -LLTñër~ Ceñ~~t;~~~,r,:,~] --ll!.frf"\ - '1:"'""':" . . II I.. B \. ~ ..~ DATE REV BY COMMENTS DATE REV BYI \, [ \.., ~1VIIV1t:N I ::.;~' PRUDHOe SAY UNrr 08(26/82 ORIGINAL COMPLETION 09/06/01 per 13-32A ST Proposed WEll..: 13.32A ST Proposed 01/09/01 SIS-SL T CONVERTED TO CANVAS ^ n 0í\1'V) PERMrTNo: 162-123 02/21/01 SIS-LG REVISION 'AN U 7 c...V'.~' API No: 50-029-20798,"01 06/19/01 RNrTP CORRECTIONS Sec. 14, T10N, R14E, 2513.96 FEL 2583.45 FNI. II .. ._,..b,' Inti ~, !'Ii'~~. ~ . ~ \1 'I t, ~,"~ : '. ~; ¡ , '" BP EJ(ploratlon (Alaska) :;,!t. " - --,.. 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'1 ll{l /,,', ,- - ,.~ ' ...: II ~> I )¡ Aood'ÎÍe, ¿~í bö¡J¡ '" -1 I}-.$¿ -, \. ~ 3/Z,Ç jI'C¡J; 1- T . w.. H I,~ \. "'. '.J J " ' I.~; j i ~ ~ . ~i'd' ',' : / .. r: !!IIi... ~~fli i (, i ,... ~ fin ! ,!'.; ~ 1 .... !S t ~1 ~ ' I~ ... .. ' ,~ .' t '"'. :'1 8!!'!t '1 ~ \ \ ~ ~ ~ ~ I 1 1\, ~ 'j' : ~: ~~..! ~fr ~ . ¡~ 11' '\. ~ .... (., .. .', .-..~ =f =4 ~nl ~ ~ .. . ..,', :: í 'I ~ ). ;:~ \ f >. "" I 'ì~1 í\" 11 ,-. :n}, "' \t ,.:¡ ,; !"; ,~, . .. ,, } \~ f :,.) )¡ T .. . r~ ~¡t: J " . ..; ~ 11 - .. 1 II, i ~ ! " i~\ f .' - 'f' j: ~" ~ tiiiI ~" I I' ! ~ : 'h -=:. , .-: ;:" ,', , ~ If:.- r;q :! \ ~ 'j\ , ":L.. ~i \ I T . r " '~ :; ~ ì' I . H~~: " I I '~, {. " : ~ ~ ~ ~ I "'" : it). " , I '" ' ' S ~ f ~ i 1,( " ~~ ¡ I ill '- - J' \ . I... : \ í' (:: , ~Ff --.... !;f " IL , , ,;~ "\. . ~ ... nr, ì'~ i. ; -.- ~ '~ ;~:t . ( -1 ., ..... ,.;;;::::: :~~} ¡~. -- ~ ' . ( ])1 ft' ip; ~ ,,) . ...... - ;a".. .:~} .. .. -<oJ !!'" T~ : " \ -.. - c 0 I'f' ~t~ ,.'d ,. , 6 , ''';:::: ..~ ,. ""::.' It: \ I., ~:" ~ liP: ~:h " . "" - 0Cõ:l ( ,,,' ,'It ~,. , -.;:: ... If ~:f :.r J ~ .. ~ 1 ... ~rH ,\ i i .. ~ tJ, tH~' ;.~ ~:, '~~ ;¡ ~, I ~. ¡ ~ ! .J! ~ ,\~ ; ,,' ."; ,I, .......... ~. ,~~ i .'f ~ t iI' ( J ~, ¡:d .... ..~: ~ t#" ~~:., ~ ~: ......... 'pi' it ~ (f ..' r ~' !' , ""-'- i ~: ~ I , .~ . \'" i' , ..... 1. :(' !:f' ~' j , I ,. "'11. ~ . 'I '( ..... ,h, ], 1.1, ¡; I'r ;' ~ n¡ ! i ,,--, :h' 1 ~ ~! ~ r \. Ht;. IJI I H'~' ~.' í " ~'. < t Hi , i ,y :.p ~. .. ,~ ~~ ; ~ I ..(0 i ì I, , ~ \ t! ~}~!: i ,. ::i >, !' ,,:¡ .~, J ~ 11 ~ ~ ~. . " îr j' I I,' .1 ,""" un- : ¡ \. .i' ". :. ,I 't.. '/' \ In.. ',': Ii; I.t..,. ~1'" , ~. , ;)~J ~ ... \' , If' ) ~' ". ( ~ ~ I~.. {. I ,P' ~ ( ~1f~1fŒ (ID~ ~~~~~~ ( AlASKA OIL AlWD GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. J'TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer , BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK. 99519-6612 Re: Prudhoe Bay Unit 13-32Ai BP Exploration (Alaska), Inc. Pennit No: 201-235 Sur. Loc. 1637' NSL, 1435' WEL, Sec. 14, TI0N, RI4E, UM Btmhole Loc. 3235' NSL, 2418' WEL, Sec. 15, TI0N, RI4E, UM Dear Ms. Endacott: Enclosed is the approved application for pennit to redrill the above referenced well. The pennit to redrill does not exempt you from obtaining additional pennits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennitting detenninations are made. Annular disposal has not been requested as part of the Pennit to Drill application for Prudhoe Bay Unit 13-32Ai. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, b ' 'PLVI~'~ Cammy echsli Taylor ( Chair BY ORDER OF THE COMMISSION DATED this 20thday of December, 2001 jjc/Enc1osures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. - STATE OF ALASKA ALASKA ( - AND GAS CONSERVATION COMM(' PERMIT TO DRILL 20 AAC 25.005 tlJ0Ar- \ 1.,ll:?/ 0 I "- ~ ,~o\ kf\J l\~ ION ~\\'1VY I I /',!L ~ ~~bbl l1-. \ 10 0 i WU,,, per' ~ 1 a. Type of work 0 Drill II Redrill 11 b. Type of well 0 Exploratory ~tratigraPhiC T~st AfDevelopment Oil 0 Re-Entry 0 Deepen iii Service 0 Development Gas Single Zone)! 0 Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. 87' RKB Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 DZ$31Ç'Z¿ ADL 028314 ßb 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1637' NSL, 1435' WEL, SEC. 14, T10N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 25921 NSL, 2303' WEL, SEC. 15, T10N, R14E, UM 13-32A L w6~- Number 2S100302630-277 At total depth 9. Approximate spud date 3235' NSL, 2418' WEL, SEC. 15, T10N, R14E, UM 01/10/02 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028312,2044' MD No Close Approach 2560 12570' MD / 89931 TVDss 16. To be completed for deviated wells 0 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 11580' MD Maximum Hole Angle 93 Maximum surface 2294 psig, At total depth (TVD) 8800' / 3350 psig 18. Casing Program Specifications Setting Depth Quantitv of Cement i7p. Too Bot om Hole Casina Weiaht Grade Couolina Lenath MD TVD MD TVD (include staae data) 3-3/4" 3-3/16" x 2-7/8" 6.2# /6.16# L-80 ST-L 1415' 11155' 8519' 12570' 8993' 86 sx Class 'G' ~=-: ~III;I:I\I"'I ~ 19. To be completed for Redrill, Re-entry, and Deepen Operations. III '10- - -- ". ........ Present well condition summary Total depth: measured 12050 feet Plugs (measured) DEC 0 5 2001 true vertical 9209 feet Effective depth: measured 11989 feet Junk (measured) Alaska Oil & Gas Cons. CommissÎOn true vertical 9161 feet Anchorage Casing Length Size Cemented MD TVD Structural Conductor 79' 20" 2202# Poleset 79' 79' Surface 2530' 13-3/8" 1413 sx Fondu, 2032 sx PF 'C' 2530' 2530' Intermediate 11552' 9-5/8" 500 sx Class 'G', 300 sx PF 'C' 11552' 8821' Production Liner 804' 7" 287 sx Class 'G' 11244' - 12048' 8587' - 9027' Perforation depth: measured true vertical 20. Attachments II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood, 564-4378 Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the for~oiaQ iSJnjè and ~ect to the best of my knowledge I. tic Signed Alistair Sherwood '1I';:¡;{u/---I"ð(/~DI',,",. Title CT Drilling Engineer Date I ¿/ il 0 f ':I,I,"",il"::"'¡;,I,:i')"'I,'il .,,' "".'''1,, ~ ~"¡¡¡a :,I!'"">";','(,,,I.:,,,I' ',..'.",.:,/:>,,:,,:,,', ,. '""",' ',: :.:., ":i,.I:"::':"""'::",::',,,:,I"'}':;I::,::,,,::,.:, ..$1."1;, ,'''''''::':,;,:'"'.:,;;,,,:',1,:'''':':,: . ',';' .,1,,,,,,,,, "I.,: "I, Permit ~umber <"? S API Number 1 Approval Di.~ h See cover letter ''2.r":; j" - 23~, 50- 029-20798-01 J ~2 'If' for other reauirements Conditions of Approval: Samples Required 0 Ves ~ No Mud Log Requirelt / 0 Ves ZiNo Hydrogen Sulfide Measures ~ Ves 0 No Directional Survey Required aVes 0 No fJ,...!1rv¡ Required Working Pressure for OPE 0 2K 0 3K D4K D5K D10K D15K J{3.5K psi for CTU Other: 1'1 r. T'~ w.A-{ ~v.e\,¿t' <'I' y,l(;,A" J5f!9(J/O / J """'" \, by order of Aooroved Bv Oriainal Sìaned B" ,......,. ~ I "" . sioner the commission Date Form 10-401 Rev. 12-01-85Cammy Oechsli UK \ \J \ \'11-\ L Su~mit In/rriplicate ( BPX 13-32a Sidetrack , ( Summarv of ODerations: A CTD sidetrack of the WAG injector 13-32 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Phase 1: Integrity test inner annulus, (IA). Drift & caliper the tubing and liner. Set a mechanical whipstock in the liner. Mill a window in the liner with service coil, if available. Planned for December 24, 2001 . Set a mechanical whipstock in the 7" liner at 11,578' MD (8840.5' TVDss). . P&A existing perforations below the whipstock with 30 bbls of 15.8ppg cement. Phase 2: Drill and Complete CTD sidetrack: Planned for January 10, 2002 2%" coil will be used to drill a -920 ft, 3%" open hole sidetrack, (as per attached plan) from a window cut in 7" liner. The sidetrack will be completed with 1,350 ft of solid, cemented & perforated, 3-3/16" x 2-7/8" liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6 - 8.7 ppg) Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. / . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3-3/16", l-80, liner will be run from 11,155'md (TOl, 8,519' TVDss) to approximately 11,610'md, (1 jt outside of the window). 2-7/8" solid liner will be run fron the window to TO at 12,570' md'. The completion will be cemented in place with approximately 17.5 bbls (annular volume plus 25% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. ~- . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray and Resistivity log will be run while drilling the open hole section. . A memory GR/CCl will be run inside liner prior to perforating. Hazards . Since the well is an injector an H2S concentration for 13-32 is not available. Producers proximal to 13- 32, namely 13-14 & 14-30 have production H2S contents of -30ppm. . The well path will cross one mapped fault. This fault, with an estimated 50 feet of throw, is located approx 250' past the KOP. lost of drilling fluid to the fault is probable. Reservoir Pressure Reservoir pressure is estimated tÇ> be 3,350 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,294 psi. ,.,/ TREE = GRAY GEN 3 (' WELLHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 87' BF. ELEV = KOP= 2910' Max Angle = 55 @ 7100' Datum MD = 11639' Datum1VD = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" 1 Minimum ID = 3.725" @ 11256' 4-1/2" OTIS XN NIPPLE 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, ID = 4.892" l-i ITOP OF 4-1/2" TBG-PC l-i 'TOP OF 7" LNR 1 11198' I 11198' 1 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 1 19-5/8" CSG, 47#, L-80/S0095, ID = 8.681" 1 ÆRFORA TION SUMrv1A RY REF LOG: BHCS ON 08/21/82 ANGLEATTOPÆRF: 41 @ 11585' Note: Refer to Production DB for historical perf data SIZE SPF INTERV A L Opn/Sqz DATE 3-3/8" 4 11585-11595 0 06/20/92 3-3/8" 4 11605-11615 0 06/20/92 3-3/8" 4 11676-11714 0 12/11/85 3-1/8" 4 11725-11785 0 11/27/82 3-1/8" 4 11795-11801 0 11/27/82 3-1/8" 4 11814-11820 0 11/27/82 3-1/8" 4 11826-11846 0 11/27/82 3-1/8" 4 11856-11866 0 11/27/82 IPBTD I I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 12048' 13-32 (I) .1 I SAFETY NOTES ~ -i 5-1/2" Otis RQ SSSV NIP, ID = 4.562" 1 -15-1/2" BOT PBRASSY 1 -i9-5/8" X 5-1/2" BOT PKR 1 -i5-1/2" X 4-1/2" XO 1 11256' -i4-1/2" OTIS XN NIP, ID = 3.725" 1 -14-1/2" BOT SHEA ROUT SUB 1 -i4-1/2" TUBING TAIL 1 l-i ELM IT LOGGED 01/07/90 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 08/26/82 ORIGINAL COMPLETION 01/09/01 SIS-SL T CONVERTED TO CANV AS 02/21/01 SIS-LG REV ISION 06/19/01 RNlTP CORRECTIONS PRUDHOE BAY UNrr WELL: 13-32 ÆRMrr No: 82-123 API No: 50-029-20798-00 Sec. 14, T10N, R14E, 2513.96 FEL 2583.45 FNL BP Exploration (Alaska) TREE = ( I SAFETY NOTES 13-32A ( PROPOSED CTD SIDETRACK GRAY GEN 3 WELLHEAD = GRAY ACTUATOR = AXElSON KB. ElEV = 87' BF. ElEV = KOP= 2910' Max Angle = 55 @ 7100' Datum MD = 11639' Datum1VD = 8800'SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1 5-1/2" TBG-PC, 17#, L-80, .0232 bpf, 10 = 4.892" -i' 11198' I Minimum ID = 3.72588 @ 11256' 4-1/2" OTIS XN NIPPLE I TOP OF 4-1/2" TBG- PC l-i ¡TOP OF 7" LNR 1 14-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1 19-5/8" CSG, 47#, L-80/S0095, 10 = 8.681" 1 <8 11155' 11166' -15-1/2" Otis RQ SSSV NIP, 10 = 4.562" 1 l-i Top 3-3/16" Liner I 1-i5-1/2" BOT PBRASSY 1 l-i 9-5/8" X 5-1/2" BOT PKR I -15-1/2" X 4-1/2" XO 1 -i4-1/2" OTIS XN NIP, 10 = 3.725" 1 -¡Top of Cement 1 -14-1/2" BOT SHEAROUT SUB 1 -14-1/2" TUBING TAIL 1 l-i ElM TT LOGGED 01/07/90 1 \ , , >"""., 111610'1-13-3/16" X 2-7/8" XO 1 , ~." --'~ ""''''''', .... ... . .... '.... ........ , "':", .. " , , ", " 3-3/4" OHI , , \ \ , \ \ \ I , I I I I I I II I I I , I I I I I !1: I I I I I I I I I I I I I I I I' \r.. ....<1 '...~.... I I 12570'1--i2-7/8" ST-L Liner, Cemented & Perf'd I 1 Top of Proposed Whipstock 1 11578' ÆRFORA TION SUMMARY REF LOG: BHCS ON 08/21/82 ANGLEATTOPÆRF: 41 @ 11585' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 3-3/8" 4 11585-11595 0 06/20/92 3-3/8" 4 11605-11615 0 06/20/92 3-3/8" 4 11676-11714 0 12/11/85 3-1/8" 4 11725-11785 0 11/27/82 3-1/8" 4 11795-11801 0 11/27/82 3-1/8" 4 11814-11820 0 11/27/82 3-1/8" 4 11826-11846 0 11/27/82 3-1/8" 4 11856-11866 0 11/27/82 IPBTD 1 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1 12048' DATE REV BY COMMENTS DATE REV BY COMMENTS 08/26/82 ORIGINAL COMPLETION 09/06/01 pcr 13-32A ST Proposed 01/09/01 SIS-SL T CONVERTED TO CANVAS 02/21/01 SIS-LG REV ISION 06/19/01 RNlTP CORRECTIONS I PRUDHOE BA Y UNIT WElL: 13-32A ST A'oposed ÆRMrr No: 182-123 APt No: 50-029-20798-01 Sec. 14, T10N, R14E, 2513.96 FEl2583.45 FNL BP Exploration (Alaska) 0 8550 8600 8650 8700 8750 H I I 8,780 8800 i 8,81 ? (jj Q) ~8850 0 ~ 8900 8950 9000 9050 9100 9150 rei M5 500 1 1,000 1,500 Path Distance (Feet) 2,500 Angle@ K,O,= 41 deg MD:11580 2,000 13-32a case 103 Sept. 5, 2001 Ted x4694 3,000 Tot Drld:990 ft 12570 TO Marker TVD 3,500 TSGR TVD TVD Kick Off 8.8151 8,81 51ft TVD Deprtr @KO MD KO Pt MD New Hole 11,580 990 Total MD 8,993 DLS deg/l00 Tool Face 990 (,) .3 (,) "- U') E 0 .... ....... (\j u r::: ro ... '" :a >- -7,500 1 2 8,780 8,780 1 3-32a Case 103 Sept. 5, 2001 Ted x4694 -7,000 -6,500 X distance from Sfc Loc -6,000 2,000 1,500 1,000 500 -5,500 NEW HOLE Kick Off TO uStãtëPiane Surface Loc Drawn: Plan Name: 679,487 685,789 990 1 2/412001 13:28 Case 122 BOP for 13-32 and B-28 CT sdtrks ( Subject: BOP for 13-32 and B-28 CT sdtrks Date: Thu, 13 Dee 2001 17:33:59 -0600 From: "Stagg, Ted 0 (ORB IS)" <StaggTO@BP .com> To: "Tom Maunder'" <tom_maunder@admin.state.ak.us> (' Tom, Both 13-32 and B-28 sidetracks will be 3 3/4" hole and use 2 3/8" coil. The proper BOP diagram for both is attached. Thanks for catching yet another error. Ted -----Original Message----- From: Tom Maunder [mailto:tom maunder@admin.state.ak.usl Sent Thursday, December 13,2001 11 :14 AM To: Ted Stagg Subject: 13-32A Ted, A help request. I don't have Allistair's eddress. I was reviewing the permit for the well. There is a coil diagram, but I think it is an old one. It doesn't show the variables. There is a diagram in the B-28a which is correct. Thanks. Tom r- __~_M'_- ,,----~ -.---- -- Name: BOP .xls , ~BOP.xIS Type: Microsoft Excel Worksheet (application/vnd.ms-excel) Encoding: base64 ~------~--------.-.... ..- . - ...,~.. 1 of 1 12/13/01 3:30 PM ( ~'".m~ - c~ cy~ \-:rl (] ~" :2" CT (' 10,000 psi Pack-Off Lubricator ,/ ~ d..." Pipe/Slips 7 1/16" Pipe/~/;p$ :;) ~~ " ... ... :t ff SWAB OR MASTER VALVE BOP-Tree Well Rig Floor SSV I Master Valve I Base Flange I ,j! ( ( H 198748 DATE 09/28/01 CHECK NO. 00198748 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS 100.00 VENDOR DISCOUNT ALASKAOILA NET 00 092701 CK092701L PYMT OMMENTS: HANDL NG INST: 100.00 Per it to Drill ee S/H - Terri Hubb e X4628 \3~3~A DEC 0 5 2001 Alaska Oil & Gas Cons. Anchorage iE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO No.H 198748 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00198748 PAY DNEHU.NDRED.& OO/100..**it****************"'****.-*********** OS. Dt:JLLAR ,ALA$~A OILAfilDG~S ÇqNSERVAT ION ..tOMMISS:I ON,. 333 WEST 7:rH~VENUE . SUITE:tqO. ., . ANCHORAgE ,DATE. .Q9128/01, .I,'/: AMOUNT . i 10~j'~¡1 To The ORDER Of NOTNALIP ÂFTER120,DAYS '. ' .' .. . . \l4)jlktŒj III ~ 118 ? l. 8 III I: 0 l. ~ 2 0 3 8 11 5 I: 0 0 8 ...... ~ g III ( ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME f}Jtl /3-3z/l CHECK 1 STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL -I? $ EXPLORATION INJECTION WELL INJECTION WELL RED RILL / CHECK WHAT APPLIES ADD-ONSIOPTIONS) MULTI LATERAL (If api number last' two (2) digits are between 60-69) PILOT HOLE (PH) / ANNULAR lISPOSAL ~NO ANNULAR DISPOSAL <--> YES ANNULAR DISPOSAL THIS WELL "CLUE" The permit is for a new wellbore segment of existing well -----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be . clearly differentiated in both name (name on permit plus PH) _and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Annular disposal has not been requested. . . Annular Disposal of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note that an disposal of fluids generated. . . ANNULUS <--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. The permit is approved, subject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. 1. Permit fee attached. . . . . . . . 2. Lease number appropriate. . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available'in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbóre plat included.. . . . . . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . . 11. Permit can be issued without conservation order. . . . . . . . A:l,~ DATE J 12. Permit can.be issued without administrative approval.. . . . . i2. -(.,.0 13. Can permit be approved before 15-day wait.. . . . . . . . . . ENGINEERING 14. Conductor string provided . . . . . . . . .. . . . . . . . . . 15. Surface casing proteds all known USDWs. . .. . . . 16. GMT vol adequate to drculate on conductor & surf csg. . . . . 17. CMT vol adequate to .tie-in long string to surf csg. . . . . . . . 18. GMT will cover all known productive horizons. . . . .'. . . . . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . 21. If a re-drill, has a 10-403 for abandonment been approved. . . 22. Adequate wellbore separation proposed.. . . . . . . .' . . . . 23. If diverter required, does it meet regulations. . . . . . . . . . 24. Drilling .fluid program schematic & equip list adequate. . . . . 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . Q~TE 26. BOPE press rating appropriate; test to ~6o" Dsig. flll(:l:' t ' 27. Choke manifold complies w/API RP-53 (May 84). . . . . . " , 28. Work will occur without operation shutdown. . . . . . . . . . . 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . 30 P t b d I h d n ulfide measures ~ ()~he-f ~ex-fLlce_r<.. bU- rlUZ_~~{jJ ..-,3¿J$PM .1-(5. 31: D:~~r:~nt:~s~~epo:~tiar o~~;re:sure zones. . '. .. .... ... Y. (J 32. Seismic analysis of shallow gas zones. . . . . . . . . ~. . .. .~ N APPR DATE 33. Seabed condition survey (if off-shore). . . . . . . . . . . . Y N /'Z .t;,.,.ð ( 34. Contact name/phone for weekly progress reports [explo ory only) Y N ANNULAR DISPOSAL35. With proper cementing records, this plan . (A) will contain waste in a suitable receiving zone; . . . . . . . (8) will not contaminate freshwater; or cause drilling waste. .. to surface; , ' (C) will not impair mechanical integrity pf the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and E will not circumvent 20 AAC 25.252 or 20 MC 25.412. Y N ~;8i- _ENGINE~~G: .~~?<8~MMI~SION:, S .. l7b ' JM~.I¿//~/() l' 2ð WELL PERMIT CHECKLIST FIELD & POOL b ,S' COMPANY INIT CLASS ADMINISTRA TION l).{ \ ~ , GEOLOGY APPR DATE c:\msoffice\wordian\diana\checklist (rev. 11/01/100) PROGRAM: exp GEOLAREA Y N .5'u-,ç~ Þ~-h~'Þ'k A-DL Dz.,ß3>iS; ~r ~'C'~-$V~../~ -r:"D, òÀV Api- C:>2i?3/~ Þ , ' well bore seg O/(roQ~ ann. disposal para req ON/OFF SHORE 0 )-1 serv N N N N, N N iN - N N Y N . ~ ~~A, Y N fJ./A . ~~., ~ H-IA ",N . ;./ N 't-, N iVN j i~/~ c 0 Z 0 ~ :e ::0 ( ~ m z ~ :I: en > :0 m :Þ ( Y N Y N ::~ç: ti J~:~. tv ~: 7" , J,.. Com mentsllnstructions: ( (- Well History File APPENDIX Information of detailed nature that is not particularly gennane to the Well Permitting Process but is part of the history file. . To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically . . organize this category of information. (: Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Dec 11 14:30:52 2002 Reel Header Service name........... ..LISTPE Oat e. . . . . . . . . . . . . . . . . . . . . 02/12/11 Origin. . . . . . - . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Tape Header Service name.. """" ...LISTPE Date.................... .02/12/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......Ol Previous Tape Nam(~...... . UNKNOWN Comments. . . . . . . . . . . . . . . . .81'S LIS Physical Eor Comment Record 'TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DA'rA ,JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW-22009 S. LATZ SEVCIK/ EGBA,T # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # TÑELL CASING RECORD (' Writing L,ibrary. Scientific Technical Services Writing Library. Scientific Technical Services 13-32A 5002920"79801 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 1l-DEC-02 MWD RUN 3 AK-MW-22009 S. LATZ SEVCIK/EGBAJ 14 :LON 14E 1637 1435 87.00 .00 47.24 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 11578.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS O'I'HERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. :::::. ALL VERTICAL DEP~rHS ARE T'RUE VERTICAL DEP'I'H - SUBSEA ( TVDS S) . aO/-a35 ì /3'65 ( ( 3. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL; DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 2 MADE ONLY 2' OF PROGRESS BEFORE IT WAS NECESSARY TO POOH FOR A DIFFERENT ORIENTER. EWR4 DATA FOR THE MWD RUN 1 INTERVAL WERE ACQUIRED DURING THIS TRIP. THESE DATA WERE MERGED WITH THE EWR4 DATA FROM MWD RUN 3 - NO SEPARATE MAD PASS PRESENTATION IS INCLUDED. 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM D. SCHNORR, BP EXPLORA'rION (ALASKA), INC., DATED 1/31/02, QUOTING AUTHORIZATION FROM JOHM BUZA. MWD DATA ARE CONSIDERED PDC. HOWEVER, THE RUN 2 SGRC DA'rA WERE CORRECTED TO THE RUN 1 SGRD DATA, AND THE CORRECTIONS WERE .APPLIED TO 'J'HE RUN 2 EWR4 DATA (THE CORRECTIONS WERE MINIMAL - THE MAXIMUM WAS 1.S'). 5. MWD RUNS 1 AND 3 REPRESENT WELL 13-32A WITH API#: 50-029-20"/98-01. THIS WELL REACHED A TarAL DEPTH (TD) OF 12534'MD/9038'TVDSS. SROP == SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC := SMOOTHED Gl\.MMA, RAY COMBINED. SGRD:= SMOOTHED NATURAL GAMMA RAY. SEXP := SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP := SMOOTHED PHASE SHIFT-DERIVED RESIS'I'IVI'I'Y (SHALLOW SPACING) . SEMP := SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service nams.......... ...8T8LI8.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/11 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PSU TOOL CODE RPD RPM RPS RPX FET GR ROP $ .1 clipped curves; all bit runs merged. .5000 START DEP'I'H 11563.0 11563.0 11563.0 11563.0 11563.0 11569.0 11595.0 s'rm) DEPTH 12502.5 12~)()2.5 12502.5 12502.5 12502.5 12488.5 12534.0 # ( ".'C , BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED PBU MWD MWD $ DATA SOURCE TOOL CODE BIT RUN NO MERGE TOP 1 11569.0 3 11563.0 MERGE BASE 11825.5 12534.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.... ......... ... . Down Optical log depth units... ........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record......... ... .Undefined Absent value..................... .-999 Depth Units....................... Datum Speci ficat.ion Block sub-type... 0 Name Service Order Units Sizl'; Nsam Rep Code Offset Channel DEFT FT 4 1. 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 6 t~ 12 4 RFS MWD OHMM 4 1. 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 Fir:s.t La.st Name Service UrÜt Min Max Mean Nsam Reading Reading DEPT t'rr 11563 12534 12048.5 1943 11563 12534 ROP MWD FT/H 1.53 3456.67 74.3964 1879 11595 12534 GR MWD API 22.2 70[:i.09 114.032 1840 11569 12488.5 RPX MWD OHMM 0.34 2000 88.7171 1879 11563 12502.5 RPS MWD OHMM 0.6 2000 146.433 1879 11563 12502.5 RPM MWD OHMM 0.2 2000 1 92 . 433 1879 11563 12502.5 RPD MWD OHMM 0.15 2000 145.253 1879 11563 12502.5 FET MWD HOUR 0.24 20.89 5.27888 1879 11563 12502.5 First Reading For Entire File..........11563 Last Reading For Entire File....... ....12534 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......02/12/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.002 Physical E.OF File Header Service name.............STSLIB.OO2 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation.......02/12/11 Maximum Physical Record..65535 Fi 1 e Type................ LO ( Previous File Name.......STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # fILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 ( header data for each bit run in separate files. 1 .5000 START DEPTH 11569.0 11595.0 STOP DEPTH 11796.5 11825.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): TOP LOG IN'I'ERVAL (F''I~): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL srrRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): H BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (8): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVI'!'Y (Ol-IMM) A'l' TEMPERATURE (DEGF) MUD A'r MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPE:RATURE: MUD FILTRATE l\T M'I': tJIU D CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction..... ....,. ......Down Optical log depth units.... .......Feet Data Reference Point............ ..Undefined Frame Spacing.. """"""'" ....60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units....................... Datum Specification Block sub-type...O 25-JAN-02 Insite Memory 11825.0 11563.0 11825.0 40.6 94.6 '1'OOL NUMBER 002 3.750 11578.0 Flo Pro 8.60 65.0 8.2 19000 6.4 .000 .000 .000 .000 .0 145.0 .0 .0 (" ( Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD010 API 4 1 68 4 ~, ROP MWD010 FT/H 4 1 68 8 J -' First Last Name Service Unit Min i'1ax Mean Nsam Reading Reading DEPT FT 11569 11825.5 11697.3 514 11569 11825.5 GR i'1WD010 API 54.96 705.09 155.789 456 11569 11796.5 ROP i'1WDOI0 FT/H 1. 53 3456.67 106.901 462 11595 11825.5 First Reading For Entire File... .......11569 Last Reading For Entire File...........11825.5 File Trailer Service name........... ..8'1'8LI8.002 Service Sub Level Name... Version Number...........l.O.O Date of Generation.. .....02/12/11 i'1aximum 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.......02/12/11 Maximum Physical Record..65535 File Type................ LO Previous File Name. ... ...STSLIB.002 Comment Record FILE HEADER FILE NUi'1BER: RAW MWD Curves and log BIT RUN NUi'1BER: DEPTH INCREMENT: # FILE SUMMAf\Y VENDOR TOOL CODE RPD RPM RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 3 .5000 START DEPTH 1.156~5. 0 11563.0 11563.0 11563.0 11563.0 11 797.0 11826.0 STOP DEPTH 12502.5 12502.5 12502.5 12502.5 12502.5 12488.5 12534.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOI,E SOFTWARE VERSION: DATA 'T'YPE (MEMORY OR REAL-TIME): 'I'D DRILLER (FT): 'l'OP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG i'1INIi'1Ui'1 ANGLE: i'1AXIi'1UM ANGLE: 27-JAN-02 Insite 4.3 Memory 12534.0 11563.0 12534.0 32.5 94.0 # TOOL STRING (TOP fro BO'I'TOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER (I (' GM $ Dual GR 72829 BOREHOLE AND CASING DATP-. OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 11578.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: Flo Pro 8.60 65.0 9.5 24000 4.0 .060 .030 .140 .160 70.0 149.0 70.0 70.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ II Data Format Specification Record Data Record 'Type.................. 0 Data Specification Block Type.....O 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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Servj-ce Order Units Size Nsam Rep Code Offset. Channel DEPT F'r 4 1 68 0 1 ROP MWD030 F"I'/H 4 1 68 4 2 GR MWD030 API 4 1. 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1. 613 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11563 12534 12048.5 1943 11563 12534 ROP MWD030 F'I'/H 2.05 367.29 63.7987 1417 11826 12534 GR MWD030 API 22.2 526.35 100.274 1384 11 797 12488.5 RPX MWD030 OHMM 0.34 2000 B8.7171 1879 11563 12502.5 RPS MWD030 OHMM 0.6 2000 146.433 1879 11563 12502.5 RPM MWD030 OHMM 0.2 2000 192.433 1879 11563 12502.5 RPD MWD030 OHMM 0.15 2000 145.253 1879 11563 12502.5 FET MWD030 HOUR 0.24 20.89 5.27888 1879 11563 12502.5 First Reading For Entire File..........11563 Last Reading For Entire File...........12534 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 ( Date of Generation.......02/12/11 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name............ .L1STPE Date. . . . . . . . . . . . . . . . . . . . .02/12/11 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Reel Trailer Service name.............LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/12/11 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.............. ..UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Wri ting Libr'ary. Physical EOF Physical EOF End Of LIS File ( Scientific Technical Services Scientific Technical Services
