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197-228
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-03A PRUDHOE BAY UNIT P-03A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/22/2025 P-03A 50-029-22176-01-00 197-228-0 W SPT 8679 1972280 2170 1013 1015 1013 1014 46 44 46 46 4YRTST P Sully Sullivan 9/8/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT P-03A Inspection Date: Tubing OA Packer Depth 400 2401 2335 2319IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS250910170418 BBL Pumped:4.2 BBL Returned:3.3 Wednesday, October 22, 2025 Page 1 of 1 MEMORANDUM TO: Jim Regg c i C)I t l 2 u Zi P.I. Supervisor I FROM: Bob Noble Petroleum Inspector I Well Name PRUDHOE BAY UNIT P -03A Insp Num: mitRCN210912153631 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, September 20, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P -03A PRUDHOE BAY UNIT P -03A Sre: Inspector ReviewedB P.I. Supry-3 Comm API Well Number 50-029-22176-01-00 Inspector Name: Bob Noble Permit Number: 197-228-0 Inspection Date: 9/12/2021 - Monday, September 20, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well --- - 8679 ! Tubing 982 - 984 983 - - 983 PTD t97zz8o T a Test � SPT YP ,Test psi P , 2170 IA 224 2411 2299 2278 BBL Pumped: P 42 ' IBBL Returned: -- a OA 39 ao ao ao Interval aYRTST P/F P ✓ - Notes - Monday, September 20, 2021 Page 1 of 1 i MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r ) WqrDATE: Friday,September 22,2017 P.I.Supervisor i � 7 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC. P-03A FROM: Lou Laubenstein PRUDHOE BAY UNIT P-03A Petroleum Inspector Src: Inspector Reviewed By: P.I.Supryp R— NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT P-03A API Well Number 50-029-22176-01-00 Inspector Name: Lou Laubenstein Permit Number: 197-228-0 Inspection Date: 9/17/2017 Insp Num: mitLOL170918160533 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P-03A • Type Inj W- TVD 8679 " Tubing 1090 - 1091 - 1089 - 1090 • PTD 1972280 (Type Test SPT Test psi 2170 " IA 94 2396 - 2352 2338 ' BBL Pumped: 3.3 BBL Returned: 2.8 OA 29 , ; 29 - 29 ' 29 - Interval 4YRTST IP/F P ✓ Notes: CAN MED rj4. ?C Friday,September 22,2017 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,October 02,2013 TO: Jim Regg '- P.I.Supervisor Ic' lb/7/13 SUBJECT: Mechanical Integrity Tests (( BP EXPLORATION(ALASKA)INC P-03A FROM: Chuck Scheve PRUDHOE BAY UNIT P-03A Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprvc192---- NON-CONFIDENTIAL Comm Well Name PRUDHOE BAY UNIT P-03A API Well Number 50-029-22176-01-00 Inspector Name: Chuck Scheve Permit Number: 197-228-0 Inspection Date: 9/28/2013 Insp Num: mitCS130929070753 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P-03A • I a In TVD 8679 IA ' 965 2810 I 2780 - 2775 - {TYP J G PTD I 1972280 IType Test sPT ITest psi i 2170 OA 19 . 19 19 1 19 Interval i4YRTST P/F 1 P - Tubing 2224 j 2230 2227 _i 22 - Notes: SCANNED DE( 2 3 2U1 Wednesday,October 02,2013 Page 1 of 1 • S Wallace,Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator©bp.com] 1:04 AM.0' Sent: Sunday, September 29, 2013 1 To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL;AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Team Lead;AK, D&C Wireline Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr,AK, OPS Well Pad YP; Charles, Marcus A; Wallace, Chris D(DOA) Cc: AK, D&C Projects Well Integrity Engineer; Clingingsmith, Mike J;AK, D&C Well Integrity Coordinator; Regg, James B(DOA) Subject: OPERABLE: Injector P-03A(PTD#1972280)AOGCC MIT-IA Passed All, Injector P-03A(PTD#1972280) passed an AOGCC witnessed MITIA on 09/28/2013. The passing test confirms two competent barriers in the wellbore. The well is reclassified as Operable. Please call with any questions. Thank you, Jack Disbrow BP Alaska-Well Integrity Coordinator = ` 1 GW Global Wells Nt } r_. Organization !l Office: 907.659.5102 WIC Email:AKOCWelllntegrityCoordinator @bp.com From: AK, D&C Well Integrity Coordinator Sent:Tuesday, September 10, 2013 7:06 PM To: AK, OPS GC1 OSM; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Well Pad YP; Warner, Scott Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Injector P-03A(PTD #1972280)AOGCC MIT-IA All, Injector P-03A(PTD#1972280) has come due for its AOGCC witnessed MIT-IA, and will pass its anniversary date of 09/29/2013.At this time the well is placed Under Evaluation to allow it to be brought online for testing. Per AOGCC Industry Guidance bulletin#10-02A,it will not be necessary to notify the state as we will be testing the well within the anniversary month. Plan Forward: 1. S: Reset SSSV 2. Ops: Bring well online 3. DHD:AOGCC MIT-IA to 2,500 psi once thermally stable Please call with any questions. 1 • • Thank you, Laurie Climer Alternate:Jack Disbrow) BP Alaska -Well Integrity Coordinator At Navy n¢ toa' WIC Office: 907.659.5102 WIC Email: AKDCWelllntegrityCoordinator @BP.com III 2 STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSIC411 REPORT OF SUNDRY WELL OPERAT ' i `FIV 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 (r Ot� v ` CEMENT SQUEEZE Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver 1 �fi etAe Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Alitaka 011$6(7fsr agri• Ctinvfithi Name: Development ❑ Exploratory ❑ An npr�, 197 -2280 3. Address: P.O. Box 196612 Stratigraphic Service 0 6. API Number: ", Anchorage, AK 99519 -6612 50- 029 - 22176 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028288 - PBU P -03A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12904 feet Plugs (measured) None feet true vertical 9050.71 feet Junk (measured) 12838 feet Effective Depth measured 12838 feet Packer (measured) 9899 9928 9933 feet true vertical 9038.2 feet (true vertical) 8651 8675 8679 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 35 - 115 35 - 115 1490 470 Surface 2669' 10 -3/4" 45.5# NT -80 34 - 2703 34 - 2703 5410 2480 Production 10219' 7 -5/8" 29.7# NT -95HS 33 - 10252 33 - 8936 8180 5120 Liner 309' 5 -1/2" 17# 13CR80 9983 - 10292 8719 - 8969 7740 6280 Liner 2650' 2 -7/8" 6.16# L -80 10254 - 12904 8938 - 9051 13450 13890 Liner Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ - - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 31 - 9987 31 - 8722 4 -1/2" BAKER SINGLE SET PATCH 9899 - 9933 8651 - 8679 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" KB Packer No 9899 \A 8651 4 -1/2" KB Packer 9928 8675 4 -1/2" TIW HBBP Packer 9933 8679 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: t �. 0 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 3,072 1,132 1 Subsequent to operation: 2,824 1,712 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 ❑ WAGS GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -224 Contact Joe Lastufka Printed Na oe Lastu Title Petrotechnical Data Technologist Signature Phone 564 -4091 Date 10/17/2011 Form 10 -404 Revised 10/2010 MOMS OCT 1 9 20i S bmit Original Only P -03A 197 -228 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P -03A 1/22/98 PER 11,890. 11,935. 9,035.57 9,036.9 P -03A 1/22/98 PER 11,956. 12,000. 9,037.92 9,041.08 P -03A 1/22/98 PER 12,198. 12,240. 9,042.99 9,043.36 P -03A 1/22/98 PER 12,333. 12,376. 9,042.29 9,041.68 P -03A 1/22/98 PER 12,610. 12,650. 9,037.16 9,036.04 P-03A 1/22/98 PER 12,743. 12,786. 9,035.87 9,036.5 P -03A 5/20/99 APF 11,270. 11,310. 9,031.42 9,029.09 P-03A 5/20/99 APF 11,020. 11,060. 9,047.04 9,042.2 P -03A 8/5/09 BPS 9,930. 12,786. 8,676.16 9,036.5 P -03A 8/10/09 BPP 9,930. 12,786. 8,676.16 9,036.5 P -03A 9/22/11 BPS 11,100. 12,786. 9,037.68 9,036.5 P -03A 9/23/11 SQZ 11,000. 11,100. 9,049.31 9,037.68 • P -03A 9/30/11 BPP 11,000. 12,786. 9,049.31 9,036.5 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • P -03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 9/22/2011 Continued from WSR 09 -21 -11 CTU 8 w/ 1.75" CT. Scope; cmt sqz. drift coil w/ 1.25" ball. Load wellbore w/ 150 bbls of 1% KCI w/ Safe Lube. RIH w/ PDS MGR/CCI to set down at 11966'. Jet and inject schmoo to 12083' w/ slow progress. Log from 12050- 9590'. POH. MU HES 2.875" composite plug assy., RIH and set below top set of perfs at 11100'. Perform injectivity test; 1176 psi @ 1.5 bpm. pooh. recovered ball * *job continued on WSR 09- 23 -11 ** ' 3 9/23/2011 } Continued from WSR 09 -22 -11 CTU 8 1/ 1.75" CT. Scope; cmt sqz. RIH w/ 2 7/8" WOT cement retainer. set at 11000. Pump 17 bbls 15.8# LARC cement thru retainer. Underdisplace by one bbl and had max 0.5 bpm @ 2050 psi before unstinging. Contaminate excess cement and FP while POH jetting to surface. 'Turn well over to DSO to leave SI. RDMO to S -125 Note: Top of cement retainer at 11000', top of composite plug at 11100' with cement in between. Job complete 9/27/2011 CTU #9 w / 1.75" ct: Job scope: Mill cement retainer & CIBP. RIH with motor & 2.30" 'four bladed cowboy mill. Tag cement top © 10991 and begin milling, milled to 10999', POOH to look at tool string. Milling string looks good, RBIH w/ same 'assembly, Tag cement © 10995', PUH, begin milling «< Job in progress »> 9/28/2011'CTU #9 w/1.75" CT Job scope: Mill cement retainer & CIBP. Not making progress milling at 10,993'. POOH. At surface found a 1" x 1/2" chunk of retainer stuck in the 'water coarse of the mill. Also the mill is trashed, bottom cutters gone and sides worn ;down. Send mill and ported sub in for rebuild. Cut 100' of coil. RIH w/ 2.25" venturi. 'Make three venturi passes down to 10,995'. POOH. Recover —2 cups of cast iron debris including chunks of upper slips, elastomer elements, and potential pieces of lower slips. Mule shoe shows indications of turning on metal. RIH 2.30" four blade ?mill and ported sub w/ 1/8" holes to finish milling cement retainer and cement. «< Job in progress »> 9/29/2011'CTU #9 w/1.75" CT Job scope: Mill cement retainer & CIBP. «< Continued from ;09/28/11>>> RIH 2.30" four blade mill and ported sub w/ 1/8" holes to finish milling cement retainer and cement. Tag cement retainer at 10,998'. Mill through retainer and cement down to 11,054 ". Very slow ROP POOH. Mill in good condition with cement coated on 'pipe. RIH w/ 2.30" four blade mill and ported sub w/ 1/8" holes. Mill cement from 11,054' to 11,080'. Chase 10 bbl provis sweep to surface with bit in 4.5" at 9,950'. Perform injectivity test. WHP slowly increases above 2000 psi pumping 0.35 bpm. Establish inj rate of —.32 bpm @ 2000 psi. Rate is within acceptable criteria of successful cement squeeze. RIH and mill cement from 11,080' to top of 2 -7/8" HES fasdril at 11,100'. Mill HES Fasdril and begin pushing to TD. « <Job in Progress »> • • 9/30/2011 CTU #9 w/1.75" CT Job scope: Mill cement retainer & CIBP. « <Continued from ;09/29/11>>> = Milled 2- 7 /8 "HES Fasdril and push to TD at 12,851'CTM. Chase provis gel sweep 100H. RDMO. Notify Ops to POI. « <Job Complete »> FLUIDS PUMPED BBLS 323 1% KCL W/ .06% SAFELUBE 53 50/50 METH 297 1% KCL 17 15.8# LARC CEMENT 1771 1% SLICK KCL 20 PROVIS 2481 TOTAL TREE =+ 4 -1/16" 5M CIW SAFETY : WELL REQUIRES A SSSV WHEN WELLHEAD = 5M FMC P-03A ON M I. L ANGLE> 70° @ 10462'. ***CHROME ACTUATOR = OTIS TBG AND LNR KB. ELEV = 91.54' BF. ELEV = 56.05' KOP = 3952' Max Angle = 101 @ 10634' I 2048' I - 14 - 1/2" OTIS HXO SSSV NIP, ID = 3.813" Datum MD = 10197' Datum TV D = 8800' SS 110 -3/4" CSG, 45.5 #, NT -80, ID = 9.953" I—I 2703' I • GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2985 2893 0 CA -KBMG DMY BK 0 02/11/07 Minimum ID = 2.441" @ 10254' 4 5721 5421 42 CA -KBMG DMY BK 0 TOP OF 2 -7/8" LINER 3 8073 7155 39 CA -KBMG DMY BK 0 2 9533 8271 39 CA -KBMG DMY ** BK 0 06/01/09 1* 9905 8565 37 CA -KBMG DMY ** BK 0 06/01/09 14-1/2" BKR (CR) PATCH, ID - 2.45" (08/12/09) H 9899' -9933' **S TA #1 & #2 = DMY w/ EXTENDED PACKING I C *BEHIND PIPE 9922' - I--14 -112" PKR SWS NIP, ID = 3.813" 1 1 IP.M1 I 9932' H RIGHT HAND RELEASE LATCH 1 Ql. ►� 9933' H7-5/8" X 4 -1/2" TIW HBBP PKR, ID = 4.0" 1 1 9955' H4 -1/2" PKR SWS NIP, ID = 3.813" I 1 9975' H 4 -1/2" PKR SWN NIP, MILLED ID = 3.80" I 1 4 -1/2" TBG,12.6 #, 13 -CR, .0152 bpf, ID = 3.958" 1-1 9987' 9987' 1-- I4 -1/2" WLEG, ID = 3.958" I 1 9977' I — I ELMD TT LOGGED 07114/91 1 TOP OF 5 -1/2" TIW LNR I - 1 9983' 1 7 -5/8" CSG, 29.7 #, NT- 95 -HS, ID = 6.875" H 10252' , 'TOP OF 2 -7/8" LNR I 10254' I 10254' H BKR DEP SLV W /3" PROFILE 1 PERFORATION SUMMARY REF LOG: SPERRY SUN MWD GR ON 01/20/98 MILLOUT WINDOW ANGLE AT TOP PERF: 97 @ 11020' 10292' - 10299' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ( Z• 2" 4 11020 - 11060 S 09/23/11 /+ ,J� ( Qld� 2" 4 11270 - 11310 0 05/20/99 1.��" CV. q-3-11 1-2/3" 4 11890 - 11935 0 01/22/98 1 -2/3" 4 11956 - 12000 0 01/22/98 7 • 1 -2/3" 4 12198 - 12240 0 01/22/98 1 12851' CTM I F ISH - 2 -7/8" MILLED FASDRILL 1 -2/3" 4 12333 - 12376 0 01/22/98 41S1 PLUG (09/27/11) 1 -2/3" 4 12610 - 12650 0 01/22/98 WAWA 1 -2/3" 4 12743 - 12786 0 01/22/98 � 11 1111 11111111 1111 1 N 11111 PBTD 12838' I TOP OF WHIPSTOCK 1 10290' 1 ` ■ I PBTD I 10589' ! 1 1111111111111111111 4:4;:e 111 1 5-1/2" LNR, 17 #, 13 -CR, .0232 bpf, ID = 4.892" I 10674' .i1s1•1�1�1•11. 1 2 -7/8" LNR, 6.16 #, L -80, .00579 bpf, ID = 2.441" I - 1 12904' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/09/91 HF ORIGINAL COMPLETION 02/10/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: P -03A 01/22/98 HILDRETF SIDETRACK COMPLETION 10/11/11 RMH/ PJC CMT RETAINER/ SQZ (09/23/11) PERMIT No: 197 -2280 02/28/02 RN/TP CORRECTIONS 10/11/11 RMH/ PJC MILL CMT RETAINER (09/30/11) AR No: 50- 029 - 22176 -01 02/11/07 CJN/PAG GLV C/O SEC 31, T11 N, R13E 06/01/09 SWC/TLH GLV C/0 09/29/09 MVISV SET PATCH (08/12/09) BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 — 1=), ` ;t i'G RECEIVED Mr. Tom Maunder Alaska Oil and Gas Conservation Commission AUG 2011 333 West 7 Avenue Okl Anchorage, Alaska 99501 a & Get Cam' Commisskin Ancherls Subject: Corrosion Inhibitor Treatments of GPB P -Pad �q7 Dear Mr. Maunder, P.. 03R Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) P -Pad Date: 07/21/11 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 P - 1920920 500292228700 0.30 NA 0.30 NA 0.85 4/24/2010 P -02A 2000840 500292237601 0.30 NA 0.30 NA 4.25 4/25/2010 P -03A 1972280 500292217601 12.70 5.0 0.30 7/12/2010 2.55 8/5/2010 P -04 1910760 500292218000 1.80 NA 1.80 NA 15.30 4/25/2010 P -05A 2000510 500292254501 0.80 NA 0.80 NA 5.95 4/25/2010 P -06B 2051380 500292216602 11.30 3.0 1.00 7/12/2010 9.35 8/5/2010 P -07A 2011960 500292253501 0.50 NA 0.50 NA 1.70 4/24/2010 P -08A 2000850 500292237701 0.10 NA 0.10 NA 0.85 4/24/2010 P -09 1930580 500292236200 0.10 NA 0.10 NA 0.85 4/24/2010 P -10 1910520 500292215800 3.00 NA 3.00 NA 28.05 4/24/2010 P -11 1910290 500292214300 3.00 NA 3.00 NA 23.80 4/23/2010 P -12B 2001330 500292213602 0.30 NA 0.30 NA 0.85 4/23/2010 P -13 1901110 500292208000 0.30 NA 0.30 NA 1.70 4/23/2010 P -14 1910070 500292212900 7.50 NA 7.50 NA 56.10 7/21/2011 P -16 1901630 500292211300 4.30 NA 4.30 NA 37.40 4/22/2010 P -17 1901550 500292210500 8.00 NA 8.00 NA 89.30 4/28/2010 P -19 1901360 500292209400 0.80 NA 0.80 NA 5.10 4/21/2010 P -20B 2001590 500292208902 0.20 NA 0.20 NA 0.85 4/21/2010 P-21B 1970640 500292214802 0.40 NA 0.40 NA 4.30 4/21/2010 P -22 1931210 500292239600 0.30 NA 0.30 NA 1.70 4/23/2010 P -23 1931120 500292239300 0.30 NA 0.30 NA 0.85 4/24/2010 P -24 1970540 500292275500 1.80 NA 1.80 NA 8.50 4/24/2010 P -25 1970260 500292274200 64.00 24.0 2.60 7/17/2011 23.80 7/20/2011 P -26 1962000 500292272700 2.60 NA 2.60 NA 22.10 4/25/2010 P -27 2040500 500292320300 1.00 NA 1.00 NA 6.80 4/25/2010 P -28 2100480 500292342500 1.20 NA 1.20 NA 10.20 8/7/2010 • L SEAN PARNELL, GOVERNOR GAS �y ALASKA T OIL AND CAST 333 W. 7th AVENUE, SUITE 100 CO1sSERVA1►�IO1s COMMISSIOls ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Don Brown Petroleum Engineer E BP Exploration (Alaska), Inc. > �!!i)) P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU P -03A Sundry Number: 311 -224 Dear Mr. Brown: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this 'day of July, 2011. Encl. STATE OF ALASKA r 1 ALASKA. AND GAS CONSERVATION COMMISSIO i I APPLICATION FOR SUNDRY APPROVALS /� , ,l ' 20 AAC 25.280 �{ 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New PoE Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforat❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulat❑ Alter Casing ❑ Other: CEMENT SQUEEZE - 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ " 197 -2280 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0- 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22176 -01 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: _/ property line where ownership or landownership changes: �Y Spacing Exception Required? Yes ❑ No ❑ PRU P -03Q - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 028288 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12904 9050.71 12838 - 9038.2 • NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 35 115 35 115 1490 470 Surface 2669' 10 -3/4" 45.5# NT -80 34 2703 34 2703 5210 2480 Production 10219' 7 -5/8" 29.7# NT -95HS 33 10252 33 8936 8180 5120 Liner 309' 5 -1/2" 17# 13CR80 9983 10292 8719 8969 7740 6280 Liner 2650' 2 -7/8" 6.16# L -80 10254 12904 8938 9051 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# 13CR80 31 9987 - 4.5" BAKER SINGLE SET PATCH 9899 9933 Packers and SSSV Tvoe: 4 -1/2" TIW HBBP Packer Packers and SSSV MD and TVD (ft): 9933 8679 4 -1/2" KB PKR 9928 8651 4 -1/2" KB PKR 9928 8675 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/1/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Don Brown Printed Name Don Brown Title PE Signature (D Ph one Date °0 £7i 564 -4323 7/18/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 5 I t Da 4 Plug Integrity ❑ ❑ Integrity ❑ ❑ : s � \ - Plu Inte ri BOP Test Mechanical Inte ri Test Location Clearance � " a Other: ,i _ )03'° Eo. *i.'' >^?i t4i Cris . NiiCf1ISSiO Subsequent Form Required: / — yQ ( ' f ' '`" H 0 e / ,, APPROVED BY i Approved by: / COMMISSIONER THE COMMISSION Date: 7/Ls l l t ' D S JUL 25 2411 ORIGINAL F/ 7 'Zo Form 10-403 Revised 1/2010 z u mit i n Dupl P-03A 197 -228 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P-03A 1/22/98 PER 11,890. 11,935. 9,035.57 9,036.9 P -03A 1/22/98 PER 11,956. 12,000. 9,037.92 9,041.08 P-03A 1/22/98 PER 12,198. 12,240. 9,042.99 9,043.36 P -03A 1/22/98 PER 12,333. 12,376. 9,042.29 9,041.68 P-03A 1/22/98 PER 12,610. 12,650. 9,037.16 9,036.04 P-03A 1/22/98 PER 12,743. 12,786. 9,035.87 9,036.5 P-03A 5/20/99 APF 11,020. 11,060. 9,047.04 9,042.2 P -03A 5/20/99 APF 11,270. 11,310. 9,031.42 9,029.09 • P -03A 8/5/09 BPS 9,930. 12,786. 8,676.16 9,036.5 P -03A 8/10/09 BPP 9,930. 12,786. 8,676.16 9,036.5 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • leo foal. /. 1.1,\ To: C. Olsen/T. Norene J. Bixby /R. Liddelow Date: July 11, 2011 Cc: Don Brown, Pad Engineer From: Mike Aivano, Wells Engineer Subject: P -03 CT Cement Squeeze Est. Cost: APBPPDWL03 IOR: 100 This procedure includes the following steps: # Type Procedure 1 F Schmoo Be Gone 2 C Set Plugs and Cement Squeeze 3 C Drill Out Plugs and Cement (WOC 3 Days) Current Status On Injection Last Ink 10- May -2011 4088 bwpd @ 1275 psi Whp Max Deviation 101° at 10634 ft Deviation at Top Perf 97° at 11020 ft Min ID 2.441" @10254' and top of 2 -7/8" Liner Last Tag: 06- Oct -2010 12,754' ctmd Last Downhole Op: 07- Oct -2010 CT IPROF w/ Warmback Passes Latest H2S value: No data available for well — water injector SBHP/T: 04- Nov -2005 3314 psi & 218 deg F at 8800' SS datum NOTES: Sundry Required for Squeeze Objectives Squeeze off injection into perforation from 11,020' — 11,060' and (heel section) to increase injectivity into lower sets of perforations ( toe section ). The perforation to be squeezed will need to be isolated with solid plug below and a squeeze plug above. Well History Well P -03A is a PWI that sits in a pattern of low producers. There have been three CT Memory IPROF's run on this well (05/06/1998 & 10/04/1998). • First IPROF (05/06/1998) - -- spinner tool blades were missing (broken off) when tool was retrieved from well - -- acquired no spinner data and tools set down @ 10493'. P -03 CT Cmt Sqz.doc 1 7/18/2011 • • • • Second IPROF (10/04/1998) was run after CT do to 12810' (10/02/1998) and an Acid Simulation from 11590' to 12817' (10/03/1998) - -- spinner tool was clogged on most of the logging passes but some usable data was acquired (10/04/1998). From the (PROF data it appears that most of the water injection is going into the perfs from 11955' to 12000'. The perfs from 11020' - 11060' and 11270' - 11310' were perforated after the IPROF's • Third (PROF (10/06/2010) — tool failed, spinner not damaged but data not usuable except warmbacks. Warmbacks indicate injection at 11,200' to 11,060', 11,890' to 12,000' and 12,333' and 12,376'. A pulse test was completed in February of 2009 between this injector and producers P -05A and P- 12B with little response. After a 4/5/2011 pattern review, the team feels that if we shut off the heel perfs and attempt to get injection back deeper into the formation, injection comformance should improve. Ann Com History: • 08/12/09: Set Chrome patch @ 9900' to 9929' • 08/14/09: MIT -IA Passed to 3000 psi • 08/05/10: Treated with RG -2401 cc: w /a: Well File Contacts: Mike Aivano Don Brown 564 -5916 (w) 564 -4323 (w) 227 -6035 (c) 351 -7108 (c) P -03 CT Cmt Sqz.doc 2 7/18/2011 • • • • Job Notes • Cement Specifications are shown below. • BHCT is estimated to be 180° F at 11020' and with 110° F fluid pumped from surface. • Static reservoir temperatures in the area are 220 — 225° F. The cement blend should be designed for BHST of 220° F so that the cement does not set up prematurely in the wellbore during the squeeze. CT Squeeze Cement -LARC Ppg: 15.8 ppg. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110 °F API fluid loss: 30 -40 cc Thickening Time: 6 -8 hours Filter cake thickness: 0.25" — 0.5" - The ratio of cake thickness to filtrate volume should be consistent with lab results. - The filter cake should be firm and dry. - The slurry should be smooth and homogenous. - There should be no free water or gelation of the slurry. Compressive Strength: 2000 psi in 24 hrs Plastic viscosity: 25 - 45 cp Yield point: 5 —15 Ibf /100ft2 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 2:00 90 0 2:30 150 4000 3:00 175 7500 3:30 175 6000 4:30 190 6000 6:30 BHST 6000 P -03 CT Cmt Sqz.doc 3 7/18/2011 • • • • Fullbore 1. Freeze Protect and shut in flowline. 2. Fullbore Schmoo -B -Gone Treatment, displace well with 1 %KCL. 3. Freeze Protect Well to 2200ft Coil Tubing - Cement Squeeze 1. M/U MHA, Memory GR / CCL, and 2.25" JSN. 2. RIH to PBTD, P/U and get weight back, flag pipe. 3. PUH while jetting at 1.5 bpm with slick KCL to a closed choke. 4. Jet from flag depth to top of 2 -7/8" liner. POOH 5. M/U HES Fas Drill Composite Plug for 2 -7/8" 6.16 # Tbg. 6. RIH to flag depth, P/U and get weight back and correct depth. 7. Tie into SLB Memory PSP log 6- Oct -2010. 8. PUH to 11075 ft and set plug. 9. Confirm plug set as per HES Rep. 10. From top of plug PUH 25 ft. Flag pipe. 11. Perform Injectivity Test with slick KCL to a closed choke at 1.5 bpm. 12. POOH 13. M/U Weatherford FH -One Trip Cement Retainer for 2 -7/8" 6.16 # Tbg. Pinned for 3000 -4000 lbs 14. RIH to flag depth, P/U and get weight back and correct depth. 15. PUH to 11,000 ft and set Cmt Retainer. 16. Confirm plug set as per Weatherford Rep. 17. Rig Up Cementers. 18. Batch Mix 18 bbls of 15.8 ppg LARC cement. Send Sample to lab for UCA test. 19. Once cement is mixed, pump the cement at 0.5 - 1.0 bpm. a. 5 bbl fresh water spacer b. 18 bbls 15.8 ppg LARC cement c. 15 bbl fresh water spacer d. 20 bbls of Biozan 20. Pump just under 18 bbls of cement below the Cmt Retainer. Prior to the 15 bbl fresh water spacer hitting the squeeze plug, unsting and shut down pumps. PUH to 10,250 ft, out of the 2 -7/8" liner. • Do not allow freshwater spacer below squeeze plug. • If zone begins to squeeze off (indicated by decreased pump rates), unsting and circulate out remaining cement. • Without any cement below the Cmt Retainer - TOC is approximately 9,500 ft. 21. At 10,250 ft, bring pumps back on line and RIH to 10,650 ft. 22. When Biozan is at CT nozzle, continue RIH and contaminate cement inside 2 -7/8" liner down to 10,970 ft. 23. Chase Biozan and contaminated cement to surface with slick KCL, POOH at 60 %. 24. Freeze Protect top 2,200 ft of well with diesel. 25. RDMO CT, will need to WOC for 3 days. Check with SLB Lab on UCA Test from field sample. Coil Tubing - Mill Plug and Cement 1. M/U MHA, Jars, Motor, and Mill ( 2.25" - 2.30 "). Drift on 2 -7/8" Tbg is 2.347" 2. RIH to 10,250 ft and perform weight checks as needed. P -03 CT Cmt Sgz.doc 4 7/18/2011 • • 3. Continue to RIH inside 2 -7/8" liner, perform weight checks as needed. 4. Mill through any stringers and cement down to the top of squeeze plug. 5. Once milling operation indicates on squeeze plug, flag pipe and correct depth to 11,000 ft, circulate Geo -Visc sweep. 6. Continue milling operation, perform weight checks as needed. Circulate 10 bbl Geo -Visc sweep every 20 ft milled or as needed. 7. Once at 11,070 ft, circulate 10 bbl Geo -Visc Sweep and chase out of the hole with slick KCL. PUH to —11,000 ft. 8. Close choke and pressure test tubing to 2,000 psi for 30 minutes. Document pressures and LLR. • If LLR is =/< 0.35 bpm at 2,000 psi — successful, continue milling operations. • If LLR is > 0.35 bpm at 2,000 psi — failure. 50 K /a PO • Contact Mike Aivano or Don Brown if cement squeeze is a failure 9. Continue milling operation through HES Fas -Dril plug. • Caution: Well may experience lost returns or partial lost returns once slips on plug are milled up. 10. Push packer remains down past lowest perforations. 11. Circulate final Geo -Visc sweep. POOH at 80 %. 12. RDMO CT. Have Operation put well on injection. P -03 CT Cmt Sgz.doc 5 7/18/2011 . . . • 0 • TREE= 4-1/16" 5M CIW SAFETY NOTES: WELL REQUIRES A SSSV WHEN WEL LFEAD = 5M FMC ON Ml. WELL ANGLE > 70° @ 10462'. ""CHROM E ACTUATOR = 0115 -0 3A TBG AND LNR "" KB. ELEV = 91.54 BF. ELEV = 56.05 KOP = 3952' Meet Angle = 101 @ 10634' 1 1/0 I I 2048' H4-112" OTIS I-0(0 SSSV NIP, ID = 3.813" I .. .__..-_ Datum MD = 10197' Datum WD = 8800' SS 10-3/4" CSG, 45.5#. NT-80, ID = 9.953" H 2703' 1 GAS LET MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 2985 2893 0 CA-KBMG DMY BK 0 02/11/07 Minimum ID = 2.441" @ 10254' 4 5721 5421 42 CA-KBMG DW BK 0 TOP OF 2-7/8" LINER 3 8073 7155 39 CA-KBMG DV( BK 0 , 2 9533 8271 39 CA-KBMG DMY" BK 0 06/01/09 1' 9905 8565 37 CA-KBMG DMY" BK 0 06101/09 14-1/2" BKR (CR) PATCH, ID- 2.45" (08/12/09) H 9899'.9933' I---x MC "STA #1 & #2 = DMY w/ EXTENDED PACKING *B8-II ND PIPE I I I 9922' H4-1/2" FKR SWS NIP, ID = 3.813" I 2. z 9932' HmErr HA No Ram SE LATCH I Z — 1 9933' H7-5/8" X4-1/2" 11W HBBP PKR, 0= 4.0' I I I I 9955' H4-1/2" PKR SWS NIP, ID = 3.813" I I I I 9975' H4-1/2" PKR SWN NIP, WILLED ID = 3.80" I 4-1/2" TH0,12.64, 13-CR .0152 bpi, 0 = 3.958" H 9 " T I / \ I 9987' H4-1/2" WLEG, 0 = 3.958" I 1 9977' H amp - rr LOGGED 07/14/91 I ITOP OF 5-1/2" TPN LNR H 9983' 1 II 7-5/8" CSG, 29.74, NT-95-I-6, ID 6.875" H 10252' 1-41 • TOP 0F2-7/8" LNR H 10254' I ri 10254' BKR DEP SLV W/3" FROFLE I PERFORA TON SUMMARY REF LOG: SPERRY SUN MAO GR ON 01/20/98 MLLOUT WINDOW ANGLE AT TOP FERE: 97 @ 11020' 10292 - 10299' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Op n/Sqz DATE 2" 4 11020 - 11060 0 05/20/99 V 2" 4 11270 - 11310 0 05/20/99 1-2/3" 4 11890 - 11935 0 01/22/98 1-2/3" 4 11956 - 12000 o 01/22/98 1-2/3" 4 12198 - 12240 0 01/22/98 1-2/3' 4 12333 - 12376 0 01/22/98 1-2/3" 4 12610 - 12650 o 01122/98 i 4114 1-213" 4 12743 - 12786 0 01/22/98 W4Wel ••••SOS• '4111 ■•••••••1 1••••••• 1TOP OF WHIPST MID 12838' J H 10290' ■••••••01 •••••••• AI ■•••••••I 1••••••• I PBTD H 10589' 44.14./4 ■••••••14 ii■ ••••••■• /0••■ 40400+01 4000 ..............., 4.• 15-1/2" LNR, 174, 13-CR .0232 hpf, ID'" 4.892" H 10674' ' 4 1 2-7/8" LNR, 6.16#, L-80, .00579 bpf, ID = 2.441" H 12904' DATE REV BY CONVENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/09/91 HE ORIGINAL COMPLETION 02/11/07 CJN/PAG GLV C/O WELL: P-03A 01/22/98 HILDRETF SIDETRACK COMPLETION 06/01/09 SWCITLH GLV C/O FERMT N3: 197-2280 02/28/02 RN/11" CORRECTIONS 09/29/09 W/SV SET PATCH (08/12/09) AF1No: 50-029-22176-01 04/20/04 JLJ/KAK MUDD NP ID CORRECTION 02/10/11 MEILIND - ADDED SSSV SAFETY NOTE SEC 31, T11N, R13E 09/25/06 JCM'PAG SET PX TTP @ 9922' 11/12/06_ JLJ/TLH PX TTP PULLED (11/2/06) BP Exploration (Alas ka) P-03 CT Cmt Sqz.doc 6 7/18/2011 • • chlumberger Company: BP Exploration (Alaska), Inc. Well: P-03A FINAL Field: Prudhoe Bay Borough: North Slope State: Alaska Memory Injection Profile 7 Memory PSP GR/CCL/Spin/Temp/Press „cs 6-OCT-2010 < ots c 2593.99 FNL & 2020.4' FWL Elev.: KB. 91.54 ft _j 0 13 ) z z at Surface G.L a i n u _ o _ 00 D.F. cn 0 5 M '6116 g Permanent Datum: MSL Elev.: 0.00 ft z Q- (`' a- -J Log Measured From: RKB 91.54 ft above Perm. Datum Drilling Measured From: RKB E API Serial No. Section: Township: Range: 8 ir 3 50-029-22176-01 31 11N 13E Los t in. Date 6-Oct-2010 Run Number De ith Driller 12838 ft Schlumbert er Depth TD Not Tat ted Bottom Lcq Interval 12740 ft Top Log Interval 10808 ft Casint Fluid T pe Injection FLuids Salinit Densit 11111111111.111.11111111111111 Fluid Level 11111111110=111111111.111 BIT/CASING/TUBING STRING Bit Size 1.11111.111111111.11111.1111 From 1111111.11111111.11111111 To 11111111011111.1111111.11. Casin, tibin e Size 2.875 in Weight 6.16 Ibmilt Grade L-80 From 10254 It To 12888 ft Maximum Recorded Temperatures Logger On Bottom Time 6-Oct-2010 18:10 11111111.11.111111111.1 P C Unit Number Location 9075 Prudhoe B; 01111111 • Recorded B Beau Archambault Witnessed Bv WArinnar I Woof . . �i r rrrwrirw v � �wrwr a___ I ----- �Roitn - _- --- --- MO OB I -�� 1:� :_I M� ••I n _ m i_t r.i :___ I i1�■1■�■.�ii i ai1 ■ �i ■ i �'t+�i ii # )•■---fit- l i m s i � ii= ■a ••I 1 �r�i�■�ilri ■■ .>t _si �a�■i� ..1 wwww. �.. VIII■.rN.r■ Iw wry I.II�wemtr.rw■. .■Z .i 1r :I a.r�rr. i i rl�w� I .w I..rr rl Lrr�al�.r...�a� _.r. mow■ — .. rrrri _l_a�■ � �i..r>lwsorim■I. ■w 1. �■■� ■ 1 ■ o ■rlrt■w1.�1.�■■ - w ■.:_1..__..I�1_ .■ ■�I■.■I.wiwnwl.w rw■wI.■.■ �IIIwIew■ �I.wisw r�w.■I wwww .r1w�w.WIN . ... . wlw.■ I. wwl■ wrlwi w.��wE��!Iw•w■�1�� .ww■I ___Iww_.._..�>t.>��ri�.��� IMMwfr..1 1--�t�� !rte w�r..IN 1 wi.�■ -. I iwr!!■.M!■■. nim L�1� 1>t.� w ■• 1>��r 11wr, Iii• mi. m RU ' `«wr,_ i_w. I i . ■ir■■ iii i- i-i — _ _ ■ i�r-- - -- l_.1 ___m__ • _._ _ i o _u_� �r - u_ : : 1 _- .0 W Iii .�".Iw10110 . .1Ui.w um I3wwI■w�w�w w� SIB i�w :�1� 3' .E ■li i rmmmm �iw �iw �1��r'►!■�11■�I.� : �Q WI iw.■. � tf . � i1■1���11� • tw• _l____.__ I _ w. �I■�I11wt�� 1 ■ �01�110 �flr�: � � I_ __Emu mmmm =m �► M IN Elm a r ■I■ P -03 CT Cmt Sqz.doc 8 7/18/2011 11/01/10 SchlumbePger NO. 5637 Alaska Data & Consulting Services Company: State of Alaska 2625 Gambell Street, Suite 400 Alaska Oil 8. Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CO MPG -13 BCRJ -00038 X -FLOW CHECKABPSET RECORD 09115110 1 1 MPS43 AYKP -00104 S C M TI 1 1 P N PROFILE 1 -09 BCRJ -00036 PRODUCTION �- 09/12110 1 4 9 0 1 W -37A l D88000048 MEM PRODUCTION PROFILE 09/11/10 A 1 W -31A 2F -00064 MEM PRODUCTION PROFILE 09/16/10 1 06 -19A AWJI.00112 MEM PRODUCTION PROFILE 09/19/10 1 1 12.05ALl BAUJ -00050 MEM PRODUCTION PROFILE 09/20/10 1 i P7 -16 BCRJ -00049 INJECTION PROFILE 10/06/10 1 1 04 -03 BCRD -00059 PRODUCTION PROFILE 09127/10 1 1 P-03A AZ2F -00065 MEM INJECTION PROFILE — 10/08/10 1 1 G -198 AWJI -00114 MEM PRODUCTION PROFILE 10/04/10 1 1 Y -36 BD88 -00058 MEM GLS 1 t — 10/09/10 1 1 3-031J-33 BCZZ -00025 PRODUCTION PROFILE 09/11/10 1 t L -214A BAUJ -00043 MEM INJECTION PROFILE 09/13/10 1 1 H -01A AW, 1.001111 MEM PRODUCTION PROFILE 10114110 1 1 16 -06B BBUO -00023 PRODUCTION PROFILE BP CORRECTION 06/08110 1 1 i H -38 AZ2F -00068 MEM PRODUCTION PROFILE # M 10116170 1 1 P2-44 BCRD -00063 PRODUCTION PROFILE 10/15/10 i 1 B-1 3B AYKP -00091 CH EDIT PDC -GR (SCMT) s t ! 7 /02/70 02 -228 tOAKA0069 OH MWD /LWD EDIT 7/07/10 2 W -19B BCRJ -00034 CH EDIT PDC -GR (SCMT) 9/07110 1 i OWDW -SE APBPD3WELL RST REDO - PRINTS 09/23/10 1 OWDW -NW BBSK -00033 RST — 09124110 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • Nov 2 6 . , STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Other Q TUBING PATCH Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension (~ 9899-9929 Change Approved Program ~ Operat. Shutdown ~ Pertorate ~ Re-enter Suspended Well [] 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ~ Exploratory ^ 197-2280 / / 3. Address: P.O. Box 196612 Stratigraphic~ Service Q 6. API Number: Anchorage,AK 99519-6612 ~ 50-029-22176-01-00 J 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO-028288 ~ PBU P-03A 10. Field/Pool(s): S~ P 2 9 z Q Q~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL ~ 11. Present Well Condition Summary: 8~ 8 8$ 0115. p11~t!'i1SS Anchorage Total Depth measured 12904 / feet q /~ Plugs (measured) None feet ~ true vertical 905 ~ri % feet , ~~ ! '~/~ Junk (measured) None feet ~ Effective Depth measured 10589 feet Packer (measured) 9933 9899 9929 true vertical 9217 feet (true vertical) 8679 8651 8675 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" SURFACE - 110 SURFACE - 110 Surface Intermediate 2703 10-3/4" 45.5# NT-80 SURFACE - 2703 SURFACE - 2703 5210 2480 Production 10252 7-5/8" 29.7# NT95HS SURFACE - 10252 SURFACE - 8936 8180 5120 Liner 2650 2-7/8" 6.16# L-80 10254 - 12904 8938 - 9051 13450 13890 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 31 - 9987 31 - 8722 4.5" BAKER SING~E SET PATCH 9899 - 9929 8651 - 8675 Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer 9933 ~ 8679 45 KB PKR ~-~y,~ , 9899 46 KB PKR f ~~~-" " "'\ , .M".-~ """9929 ~ -~, 8651 8675 ~ l 3 ~;,~ 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions includin volumes used and final pressure: ~ ~, ~~ ''~'~ ~~ ~v r'~ 2~~~ g 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1185 872 Subsequent to operation: 2962 1384 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X 16. Well Status after work: ,/ Oil Gas WDSPL GSTOR ^ WAG Q GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-244 Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature ~ Phone 564-4944 Date 9/24/2009 .~ Form 10-404 Re~ed 7/2009 - ~~,; ~ ,y l, Submit Original Only '~.~~.. !~"' ~~`'~. ,:~f~!' : ~~~~ !~'~1~~ Ot1 P-03A 197-228 PFRF ~TTAC_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base P-03A 1/22/98 PER 11,890. 11,935. 9,035.57 9,036.9 P-03A 1/22/98 PER 11,956. 12,000. 9,037.92 9,041.08 P-03A 1/22/98 PER 12,198. 12,240. 9,042.99 9,043.36 P-03A 1/22/98 PER 12,333. 12,376. 9,042.29 9,041.68 P-03A 1/22/98 PER 12,610. 12,650. 9,037.16 9,036.04 P-03A 1/22/98 PER 12,743. 12,786. 9,035.87 9,036.5 P-03A 5/20/99 APF 11,020. 11,060. 9,047.04 9,042.2 P-03A 5/20/99 APF 11,270. 11,310. 9,031.42 9,029.09 P-03A 8/5/09 BPS 9,930. 12,786. 8,676.16 9,036.5 P-03A 8/10/09 BPP 9,930. 12,786. 8,676.16 9,036.5 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~ • P-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ***"WELL S/I ON ARRIVAL""*"(pre patch) DRIFT TO SWN NIP @ 9975' MD W/ 3.805" GUAGE RING....ALL CLEAR DRIFT TO 9985' SLM W/ 20' x 3.70" DMY PATCH DRIFT....ALL CLEAR _.~...... . _ SET 4-1/2" x 2-7/8" NIPPLE REDUCER la~ 9930' SLM (9955' MD1 :K SET TO 9929' SLM (SHEARED) XX PLUG (22" OAL, 3/16" PORTS) i LRS CURRENTLY RIGGING UP TO PERFORM CMIT ;"*CONTINUED ON 8/6/09 WSR*** .__ _ .___~ .. __--~_ --_._ .__ ..._. _~._.-- --------_ _ _ ____- ---___._ ~ ~.~. ~ __~____ 8/5/2009~T/I/0= 250/0/0. Temp= SI. TBG & IA FL (for SL). TBG FL @ surface. IA FL @ 200' (6 bbl). ~SL in control of well on departure. ~ ~SV,WV= C. SSV,MV= O. IA,OA= OTG. NOVP. ~ __ _ ~ ~. _.._----_ ---- - --. _m. .~ _._. . _._ _ __ _ _~_m_ .._..... _______ .~~ .~ ~_ _____.____._._~_ 8/5/2009 T/I/0=400/0/0 Assist Slickline, CMIT TxIA to 3000. (Eval TxIA Comm) ; Pumped into Tbg with 5 bbls diesel to reach 3000 psi. IA did not track Tbg. Job ~in progress. """Continued on 08-06-09 WSR*** ___- _._._~____.__r. .___.__.. -- ---_ ___ _._ _~ ~_.__..~__._. __,__~ ~__m ---------,- 8/6/2009:""`CONTINUED FROM 8/5/09 WSR"** (pre patch) ; LRS PERFORM CMIT TO 3000# "PASS" j"""JOB COMPLETED, WELL LEFT S/I, PAD OP NOTIFIED**" _.._ _.~ ~_ _ _ _. ~._ ..______ ______ .~_.~ ~ ~ _..._ ______r_ .. _ ~ ~._ .~ _.._.. _._.___ ~, _ .....~ _____~ __ ***. . . *** .. . . 8/6/2009~ Continued from 08-05-09 WSR Assist Slickline, CMIT TxIA PASSED to ~3000 psi. (Eval TxIA Comm) Pumped into IA with 10 bbls diesel to reach test ~pressure. T/IA lost 0/100 psi in the 1st 15 mins 0/40 psi in the 2nd 15 mins for a ~total pressure loss of 0/140 psi in 30 min test. FWHP's=500/350/0. SV, WV ~shut. MV, SSV, IA, OA Open. Slickline on location upon departure. ~~ ~~~~ 8/6/2009i"'''' WELL SHUT IN ON ARRIVAL"** (E-LINE SET PATCH) ~~ ~ INITIAL T/I/O = 500/300/0 i RIG UP 4.5" BAKER SINGLE SET PATCH AND RIH. ~ '*** JOB CONTINUED ON 7 AUG 2009*"* ~ , 8/7/2009'""'JOB CONTINUED FROM 6 AUG 2009"'`* (ELINE SET PATCH) ; PATCH STUCK RIH DURING CORRELATION PASS. PATCH SET OFF ~ 879.1 FT, CCL ;- l ~J~ F~.~OP OF PATCH AT 9888'. BOTTOM OF PATCH AT , i 9922'. IWELL SI ON DEPARTURE, SSV CLOSED. FINAL T/I/O = 500/300/0. ~''*''JOB INCOMPLETE"*` _ _ _~ _.__.____ _ _ .~ ___~_ ~ ._._ __~_ _.. ~._ _ . ~___.___ 8/9/2009~CURRENTLY~POOH W/~4*1/~Pre patch) , 2" x 34.8' BAKER PATCH PULLED FROM 9=871' PROGRESS, CONTINUED ON 8/10/09 WSR*** ~ • 8/10/2009~*""CONTINUED FROM 8/9/09 WSR"'`*(pre patch) PULLED 4-1/2" x 34.8' BAKER STRADDLE PATCH (intactl FROM 9,871' SLM. EQUALIZED AND PULLED 2-7/8" XX PLUG BODY (intact) FROM 9,940' SLM. NOTIFIED DSO OF WELL STATUS*** 8/11/2009~**"WELL SHUT IN ON ARRIVAL.*** (ELINE SET PATCH) INITIAL T/I/O: 325/100/0 BEGIN RIG UP. ~***JOB CONTINUED ON 12-AUG-2009.**'` 8/12/2009 """JOB CONTINUED FROM 11-AUG-2009.*** INITIAL T/I/O: 325/100/0 PSI. SET BAKER CHROME PATCH WITH TOP MID-ELEMENT AT 9900' TO 9929'. SURFACE AND VISUAL CONFIRMATION OF PATCH SETTING. FINAL T/I/O: 300/100/0 45 "KB UPPER STRADDLE PACKER AT 9899' 45 "KB" LOWER STRADDL PACKER AT 9929' OD=3.70" ID=2.45" i 8/14/2009 T/I/0=280/100/0. MIT-IA PASSED to 3000 psi. (Post Patch / Eval TxIA) Pumped 4 bbls of diesel into IA to reach test pressure. IA lost 40 psi in the 1st ~ 15 mins and 10 psi in the 2nd 15 mins for a total pressure loss of 50 psi in 30 ~ ' ~ min test. Bled IA, bled back 4 bbls. DSO notified of well status and tree valve ~ positions as follows: SV, WV, SSV closed. Master open. IA and OA open to ~ ~ ~gauges. FWHP's= 280/100/0. ~ ~ 9/12/2009 T/I/0= 1450/460/20 Temp= Inj. MIT IA PASSED to 4000 psi (AOGCC state ~ ~witnessed by John Crisp) Pressured up IA to 4000 psi w/ 5 bbls neat. 1st 15 min A ost 70 psi, 2nd 15 min IA lost 10 psi with a total loss of 80 psi in 30 min ~ ~test. Bled back 5 bbls neat. Final WHP's= 1450/240/20 "Valves are SV=closed, _ ~WV,SSV,MV,IA and OA open on departure" ; FLUIDS PUMPED BBLS 1 MEOH 5 NEAT 8 DIESEL 14 TOTAL ! MEMORANDUM To: Jim Regg P.I. Supervisor ~ ~ f ~~( /'~(~ ~ l FROM: John Crisp Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, September 14, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P-03 A PRUDHOE BAY LJNIT P-03A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~,~~ Comm Well Name: pRUDHOE BAY L1NIT P-03A API Well Number: 50-029-22176-01-00 Inspector Name: John Crisp Insp Num: m;tJCro9o914085212 Permit Number: 197-228-0 ~ Inspection Date: 9/12/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. P-03A e in W T~ 8679 ,. ~ jA 460 Wel~- ~TYP J• ~ P.T.D t9~zzao I~TYPeTest sPT Test psi 2169.75 ~ OA zo ~ Tubing i laso Interval a~rsT p~F P ~ 4000 '~ 3930 3920 ~ ~ 20 _ zo ~ o ~aso ~ ~aso i laso ~ - ~ - _ NoteS• 4.9 bbls pumped for test. _ ~':,~~Q\!~1~f~/¢L`' jjj ~At'r •' Nn4i y'+ti~~ y ~"\$a..~~~~ (/ ~ ~• . ~~ jjr~(!~J r (,J Monday, September 14, 2009 Page 1 of 1 OPERABLE: P-03A (PTD #197~0) Passing AOGCC MITIA post patc: Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] ,~ Sent: Saturday, September 12, 2009 10:43 PM ~~ ~f ~' ( ~~d~~°~ I To: NSU, ADW Well Integrity Engineer; Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Brown, Don L. Cc: Williams, Carrie; Holt, Ryan P(ASRC); Winslow, Jack L. Subject: OPERABLE: P-03A (PTD #1972280) Passing AOGCC MITIA post patch All, ~ Well P-03A (PTD #1972280) passed an MITIA to 4000 psi on 09/12/09. The passing test verifies iwo competent barriers. The well has been reclassified as Operable and may continue injection. Please call with any questions or concerns. Thank you, Torin Roschinger (alt. Anna Dube) Well Integrity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 From: NSU, ADW Weil Integrity Engineer Sent: Sunday, September 06, 2009 8:41 PM ~;,f~ ~;~ ~' ' ~~ ~~~J ~~~~5..~~r~v<~ E - ~ To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; Schwar~, Guy (DOA) <guy.schwartz@alaska.gov>; GPB, Area Mgr Central (GCl/3/FS3); GPB, GCl OTL; GPB, GCl Welipad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Brown, Don L. Cc: Williams, Carrie; NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC); Winslow, Jack L. Subject: UNDER EVALUATION: P-03A (PTD #1972280) Ready to POI for AOGCC MITIA post patch All, Well P-03A (PTD #1972280j was patched and tested in August but was not ready to be placed on injection due to the GC1 shut-down. The well has nowT.~een rec-lass~ed as Under Evaluation so that it may be placed on injection and an AOGCC witnessed MITIA may be obtained for UIC compliance. A wellbore schematic has been included for reference. `~ Please let us know if there are any questions. Thank you, Anna ~Dude, ~.~. (alt Torin Roschinger) Well Ir~tegrity C~ordinator GP~ lflfells Craup ~hone: (907} 659-5102 11 /4/2009 OPERABLE: P-03A (PTD #197~0) Passing AOGCC MITIA post patch• Page 2 of 2 Pager: (907) 559-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, April 10, 2009 8:20 PM To: 'Regg, James B(DOA)'; 'Maunder, Thomas E(DOA)'; GPB, Area Mgr Central (GCi/3/FS3); GPB, GCl OTL; GPB, GCl Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Brown, Don L. Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Holt, Ryan P(ASRC) Subject: NOT OPERABLE: P-03A (PTD #1972280) Failed MITIA for AA Compliance ~ ~.U3.} AI I, /~ Well P-03A (PTD #1972280) is currently under AOGCC Administrative A~ rn oval for TxIA communication. The well failed a MITIA for AA compliance due to a lack of stabilization on 04/10/09. The request has been made to shut-in and freeze rotect the well as soon as possible. The well has been reclassified as Not Operable. Di nos ics o confirm a liquid leak rate will continue in order to evaluate the plan forward for the well. Please let us know if you have any questions. Thank you, Anna ~u6e, ~P. E. Well tntegrity Coardinator GPB Wells Group Phone: {907} 659-5'102 Pager: (907} 659-5100 x1154 11 /4/2009 TREE = 4-1 /16" 5M C{W WELLHEAD = ACTUATOR= 5M FMC~ 071S KB. ELEV = 91.54' ' BF. ELEV = 56.05'I KOP = 3952' Max Angle = ~ 101 ~ 10634' Datum MD = 10197' Datum 1V D= 8800' SS~ ~ 10-3i4" CSG, 45.5#, NT-80, ID = 9.953" ~--~ 2703~ Minimum ID = Z.441" @ 10254' TOP OF 2-7/8" LINER 4-1/2" TBG,12.6#, 13-CR, .0152 bpf, ID = 3.958" TOPOF 5-112" TfW LNR 7-5/8" CSG, 29.7#, NT-95-HS, ID = 6.875" TOP dF 2-7/8" LNR GA S LIFf MA NDREI.S ST MD TVD DEV TYPE VLV LATCH PQRT DATE 5 2985 2893 0 GA-KBMG DMY BK 0 02/11l07 4 5721 5421 A2 CA-KBMG DMY BK 0 3 8073 7155 39 CA-KBMG DMY BK 0 2 9533 8271 39 CA-KBMG DMY"* BK 0 06/01/49 1 99d5 8565 37 CA-KBMG DM Y** BK 0 06/01/09 "~STA #1 & #2 = DMY w/ IXTEiVDED PACKING 9922' ~ 4-112" PKR SWS N1P, ID = 3.813" 9932~ RlGH7 HAND RELEASE LATCH 9933` 7-518" X 4-1/2" TIW HBBP PKR, ID = 4.0" $g~~' 4-1I2" PKR SWS NfP, ID = 3.813" 9975~ 4-112" PKFt SWN MP. MILLED iD = 3.80" 9987' 4-1/2" WLEG, IQ = 3.958„ 9977' - ELMD TT LOGGED 07/14i91 10254' I-{ BKR DEf' SLV W13" PROFILE 5987' 9983' 10252' 1az~~ PERFORATION SUMMARY REF LOG: SPERRY SUN MWD GR ON 01/2Q/98 ANGLE AT TdP PERF: 97 @ 11 d2d' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Qpn/Sqz DATE 2" 4 11 D20 - 11060 O 05l20/99 2" 4 11270 - 11310 O 05/26/99 1-2/3" 4 11890 - 11935 O 01/22J98 1-2/3" 4 11956 - 12000 Q 01/22I98 1-213" 4 12198 - 12240 O 01/22/98 1-2/3" 4 12333 - 12376 O 01/22/98 1-2J3" 4 12610-12650 O 01/22/98 1-2/3" 4 12743 - 12786 O 01/22J98 TOPOF WHIPSTOCK PBTD ~ 5-1/2" LNR, 17#, 13-GR, ,0232 bpf, ID = 4.892" MILLOUT WINDOW 1 Q292' - 10299' 10290 ~' '~ 10589' 10674" 2-7/8" LNR, $.16#, L-80, .d0579 bpf, ID = 2.441" 12~1~4" DATE REV BY COMMENTS DATE REV BY COMMENTS as~osas~ HF ORIGINAL CQMPLETiQN 02/11l07 CJN/PAG GLV C/O 41/22/98 HILDRET SIDETRACKCOMPLEtiQN 06/01l09 SWC/TLH GLV C/O OZi28102 RN/TP COF2RECTIONS 04i20104 JLJ/KAK MfLIED N{P {D CdRRECTfCSPJ 09125/06 JCNVPAG SET PX TTP @ 9922' 11/12l06 J~J/TLH PX TTP PU~LED (11/2/06) ~aTD ~-~ 12$3$' PRUDHOE BAY UNIT WELL: P 03A PERMIT No: 197-2280 API No: 50-029-22176-01 SEC31, T11N, R13E BP E~cploration (Aiaska} ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMII~ISSION Mechanical integrity Test Email to: Winton_Aubert~admin.state.ak.us; Bob Fleckenstein~min.state.ak.a~;.F~rre Re~g ire.state.ak.us; Tom_Maunder~admin.state.ak.us OPERATOR: BP Exploration (Alaska}, fr~c_ FIELD / UNIT / PAD: Prudhce Bay / P6U P P pa~ DATE: 09/12/09 OPERATOR REP: Torin Roschirx~er AOGCC REP: John Crisp packer pepqs PFe4est tsritia~ '45 NCm. 3(S Min. Well P-03A Type Inj. W TVD 8,679` Fut»r~g 1~5d 1450 1450 1450 Interval 4 P.T.D. 1972280 Type test P Test psi 2170 Casietg ~60 40QU 3930 3920 P/F P Notes: AOGCC 4-yr UIC MITIA to 4000 psi p~ost tubireg pateh OA 2Q 20 20 20 Well T tnj. lVD Tubing fnterval P.T.D. T test Te~ psi Casir~ P/F Notes: OA Well T In'. 7UD Tubing Interval P.T.D. Type test Test psi Case~ P/F Notes: ~ Well Type Inj. ND Tubi Interval P.T.D. T test Test " Casir~g P/F Notes: C)A Well Ty~ Inj. T1fQ Tubireg Interval P.T.D. Type test TesY psi C~i P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = water TYPE TEST Codes M = Annul~ Ip~i6oring P = ~rdard Pressure Test R= Intemal R~i~tive Taacer Scaavey A = Tempera4ure ArwmatySurveyt. D = Differeretial Tem~rature T~t ~~~ ~~~~ ~J~ ~j~I'~: , S`a ~0:2 u'4+~ G y:+~a:/ ~~~a f I r.~, c.^ f_ l: U J ~~~r ~ INTERVAL Codes 1= IniNal Test 4 = Four Year Cycle V = Required by Va~iance T =Test during WoYicover O = Other (describe in notes) MIT Report Form BFL 9/1/OS M1BT ~U P-03R 09-12-09.x1s ~ • ~'C~~ " ~ ~~ i k'{ rt~ ~ @ f ~ 6 ~~' L p`T F, I[L a Q~ ~4 ~ ~ t r ' = `, - ~ ~~ ~ 8 r r ~ ~.'~, k°` 1 ~ `` r ~ ~ < <~ ~ r r~ ~ ~ 4 ~~ a ~~ ~~ ~.--~~ ~ E ~' ~ ~ ~ ~ '€. ~~ SARAH PALIN, GOVERNOR ~ :,~ ~_ . _ . ~ _ '~ _.~~` ;.~ ~,~ ~ & ~ .. m ~ ~,s ~. ~ ~ ~ d ~ ~ ~+ ~t~~~t~~+ ~ 7 hAVENUE SUITE 100 ~-7~A 0~ L~lsL llt~-7 ~ 333 W. t , CO1~T5ERQATIOI~T COMl-IISSIOI~T E~ ANCHORAGE, ALASKA 99501-3539 ~ PHONE (907) 279-1433 . FAX (907) 276-7542 Mr, Don Brown Pad Engineer BP Exploration (Alaska),Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU P-03A ~~.~ ~~,~ _ Sundry Number: 309-244 , j~ ! SF ~.t~ ~~~.~ul ~ '"- ~ ~ ~~'' l } !~ ~j,-1 kdl t4 F ~ ~.:+l+. /J~~~" '°"xro.* . Dear Mr. Brown: Enclosed is the approved Application for Sundr~~ Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. d Chair f' DATED thisZ3 day of July, 2009 Encl. STATE OF ALASKA '? Y J1,J~~ ALAS~IL AND GAS CONSERVATION COMMI~N ~ APPLICATION FOR SUNDRY APPROVALS ~n aa~ ~~ ~Rn ~~~~~~~C~~~~~ ~ o~ '~ JUL ~ u ~f~~~ - ~~a - - - 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ aiver " er Alter casing ^ Repair well Q Plug Perforations ^ Stimulate ^ Time Extension ;~~~~~~~hIG PATCH Change approved program ~ Pull Tubing ~ Perforate New Pool ^ Re-enter Suspended Weil ~ 2, Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ~ Exploratory ~ 197-2280 ~ 3, Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22176-01-00- 7, If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU P-03A ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADLO-028288 - 91.54 KB - Prudhoe Bay Field / Prudhoe Bay Pool 12• PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12904 - 9050.71 • 10589 9217 NONE NONE Casing Length Size MD ND Burst Collapse Conductor 110' 20" Surface 110' Surface 110' Surface 2703' 10-3/4" 45.5# NT-80 Surface 2703' Surface 2703' 5210 2480 Production 10252' 7-5/8" 29.7# NT95HS Surface 10252' Surface 8936' 8180 5120 Liner 2650' 2-7/8" 6.16# L-80 10254' 12904' 8938' 9051' 13450 13890 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# 13Cr80 31 - 9987 Packers and SSSV Type: 7-5/8"x4-1/2" TIW HBBP PKR Packers and SSSV MD (ft): 9933' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ~ Development ~ Service -^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 7/30/2009 Oil ^ Gas [] Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q- GINJ ~ WINJ ~ WDSPL ~ Commission Representative: Prepared by Gary Preble 564-4944 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Don Brown Printed fVame Don Brown Title pad Engineer Signature (1 n 7 Phone Date `~ ~ ~ ~~~ ~~~ D~ ~>~~c-o-c,~ ~ 564-4323 7/16/2009 COMMISSION USE ONLY ~ ~ a. - ~' ~ Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity [] BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: Subsequent Form Required: L~{°~~ v APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ ~3 ~ ~~ v ~ Form 10-403 Revised 06/2006 ~~ ~~ ~UL ~~ 20~9 Submit in Duplicate . ' ~ • • ~ To: J. Bixby / C. Olsen, GPB Well Ops TL From: Don Brown, P Pad Engineer Whitney King, Wells Engineer Subject: P-03A Patch PBPPDWL03-N This procedure includes the following steps: Date: July 08, 2009 10-403 Required 10-404/407 Required Est. Cost: $100,000 IOR: 100 BOPD Step Type Procedure 1 S Drift w/ dummy patch. Set nipple reducer. (pre-patch) 2 E Set 4-1/2" Baker patch. MITIA to 3000 psi, establish LLR if fails. Current Status SI PW injector Ave Inj Rates 1200 to 2500 bwpd @ 800 to 1300s psi Max Deviation 101 ° at 10634 ft Min ID 2.441" @ 10,254' (3.8" in TT C 9975') 3.813" @ 2048' (min ID between surface and patch depth at 9898') Last Tag: 05/31/09: Drifted Tubing to 10234' SLM Last Downhole Op: 06/02/09: LDL Latest H2S value: Injector, beware on returns SBHP/T: 3314 psi, 218F on 11/04/08 at 8800' SS, 10,197' MD Tie-In Log: PDS LDL 02-Jun-09 Obiective The objective of this program is to patch over the leak found by a TecWel LDL at the SWS nipple (9922') just below GLM #1 (9905'). Weil Historv Well P-03A is a PWI with a TxIA communication leak. On 12/06/2002, a MIT-IA to 3000 psi failed at a LLR of 0.4 gpm. The well remained on injection and in 2007, a TecWel log was run and leaks were found at GLM's #1, 2, and 5 and at the X-Nip at 9922' MD. These valves were then re-dummied and the well passed an MIT-(A to 4000 psi. However, as long as the well is injecting, the IA continues to repressurize and has been manageable by bleeds. In early April of 2009, the well failed a MIT-IA to 3000 psi with a 3.3 gpm leak rate and the well remains shut in. TxIA communieation was not at the wellhead - PPPOT passed on 4/19/09. A TecWel log run 05/31/09 found leaks at station #1 and SWS Nipple with a possible leak signature at GLM #2. DGLVs with extended packing were reset in station #1 and #2 on 06/01/09 but the MIT-IA still failed. The TecWel LDL was re-run on 06/02/09 and recorded a leak at the SWS nipple (9922') just below station #1. Well Inteqritv Summarv > 12/06/02: MITIA Failed LLR=0.4 gpm. > 02/07/07: WRP set C~3 9950' MD, MITT to 4500 psi Passed > 02/09/07: Tecwel indicates leak in X-Nip @ 9922' MD and GLM's #1, 2, & 5 > 02/10/07: Pull & reset DGLVs in Sta #1, #2, #5 ' > 02/12/07: Calipered 4.5" T•10 jts 20-40%, pulled WRP from 9950'~MD, set MCX > 04/16/07: AOGCC MITIA Passed to 4000 psi > 07/23/07: IAP BUR 200-300 psi / day, MIT-IA passed to 2500 psi > 06/21/08: PO bled IAP from 2140 psi to 450 psi > 04/10/09: AOGCC MIT-IA Failed to 2500 psi > 04/19/09: PPPOT-T Passed > 05/31/09: LDL found leaks C~3 St#1&2, LLR too small for big pump > 06/01/09: Set DGLV w/ ext packing in ST#1,2; MIT-IA failed. > 06/02/09: > 04/26/09: MIT-IA Failed, LLR ~ 3 gpm @ 3000 psi TecWel LDL finds leaks at GLM #2 & SWS nipple at 9922' Please contact Don Brown at 564-4323(w), 745-8386(h) or 351-7108(c) or Whitney King at 564- 4840 (w) or 310-989-7674 (c) with any questions or concerns you might have regarding this program. cc: Well File North Slope 2 Risk Discussion: • • • 06/01/09 attached WSR: B&F tubing after unable to pass 9892' SLM. Attempted to set 4- 1/2" X-lock catcher sub but got stuck @ 548' SLM. X-line came back covered in schmoo and shifted. SL Drift Pre-Patch 1. RU SL. 2. Drift for 4-1/2" x 30' Baker patch (OD: 3.75") to TT at 9977' MD. 3. Set nipple reducer in 1.875" lock @ 9975' in the 4-1/2" PKR SWN nipple (milled ID = 3.8"). Note: no go has been milled out in the 4-1/2" PKR SWN nipple. BHT: 218°F on 11/04/08 BHP: 3314 psi on 11/04/08 E/L Set Patch 4. Set the 4-1/2" Baker patch with KB packers (one run) across GLM #1 (9905' MD) and 4-1/2" SWS nipple (9922' MD). Top element should be set C 9899' MD and bottom element set @ 9929' MD. Tie into GLM #1 and set as per manufacturer recommendations. Note: this will be a chrome patch, well has chrome tubing. Drift patch with 1.875" drift prior to setting in order to ensure plug can be set in nipple reducer. Patch Setting Depth: 9899' - 9929' MD (30') Tie-In Log: PDS LDL 02-Jun-09 Collars (Tubing Tail Attached) Pup Jt 9.00' 9896.44' GLM #1 6.74' 9905.44' Pup Jt 9.78' 9911.91' 4-1/2" SWS Nipple 1.14' 9921.69' Pup Jt 9.77' 9922.83' 5. MIT-IA to 3000 psi. Establish a LLR if the MIT-IA fails. 6. RDMO. ~ ~, Ti~= A-l/ifi'S~ACNV Wf'~LF~IFAf3= SMf~ ACTUA'ft~t = ,e {?765 ,.. 1~. ~V n . ~1.54' 8€. ~EV = 56.05' Kt~ = 39~a2' Max A = 141 1~834' Ds~m ND = 1019T Dflh~'-ND= 8840'SS Minimum ID = 2.441" ~ 1~254' TQ~P t~~ 2-7t$"' L1~fER d-112' TBfii,12.&#.13~CR~ .0152 ~F~ ID= 3.558` fiC~OF 5-t12" "1'PN Lt+IFt T-.~'i/8° ~SG. 29.7#. IVT-96-HS. ~ = 6.875' C~4S ~~?' Mp~S ST MD N~ OEV 7YPE V~V LATt~i P(JRT fl!1'1E 5 2~85 2893 0 CA-I4BM(i DAAY 8K 0 02Jii/07 A 5721 5421 d2 t`A-K~M~ OAA1' BK Q 3 8073 7155 39 t'A-KBNK; flMY BK Q 2 8533 8271 3~ CA1-K~IAC OMY 8K Q 02l11/07 1 89~i 8565 37 C~PI-KBMC'a DMY BK 0 07J11107 99~2' wc~r~n~~ns~~.n~ 9933' 7-5t8' X A-1 /2' TAdJ 1~~8P PKR, Id = d.0' L 9955' r- j 4-112' PKR ~SVYS 1VIP, D= 3.813` ~ 9~75` 4-1 t2" PKR 3W~'1 NF; M11~ ~= 3.80` 998T a-ttz' +N~EG, r~ = 3.a~a` 99T7` ~n~n'n"Lat~on1At91 1fl2~J4' H~CR 0~ 5LV WC3' TIOtd ~',~IuIARY f~ L4G: SdJN 1~N0 C~ft ON 01120~$8 A1~1G~£Al'TQd~P6~:97~ 11a20' 1~: R~fer M Rodu~tlor- ~ far t~saxicai perf d~a SIZE S~F M'~/AL OpMS#z flhATE 2" 4 11020 -11Q6U O OSI2Ql99 2` 4 112T0 - 11310 O Q512~t'$9 1-7l3' 4 11890-11835 O O11F2l98 1~?13' +t 119fi6 -120Q0 ~ 01l27/88 1-2tS' 4 12t98 -122A17 0~ 01122!$8 1-2/3' 4 123g3 - 12378 O 01122158 1-2l3' d 12610 -1~50 O Oit22t98 1-2t3' 4 12743 - 12T$B ~ 01122l98 TOP C}F WHNa5T4i~C ~--~ 10230' ~61D 10~89~' FI~L041f ~IItP~00V1+ f42S2' -14289' PS~D 2-Tt$' WR 8.16l~,1-80, ,4U579 bpf, ID = 2.4A1' ~--~ 12'~04' DATE REV BY C~4~MBQT'5 OM~TE f7E1/ ~Y C%7hRu~VTS 08tG9191 HF L C4MPttT~Ofi ~/11/07 GNW~AG GLV GrQ a o~r~rrae La~.r s~rr~-c~ce ~.~r~ 42t28142 F~IVITP aQ~8C3'IC~S Odl2iNa4 ,~.IJK1~K fi~1~t~RD 4~+25J06 .1CAA+PAG S`~f' PX TTP 9~22' 111121Y16 .N_JITLN PX T'iF PIA.!_~ 11 t?l~) P'F~JOMDE6AY V~VI'f VY£Ll~. F~43A ~rr~: ~~~.rtao API Mo: 5Q-42&22178-Ot S£~ 31. 'T11N, R13E ~+ 6~torat~on (A#sika) ~ • ~ __. _--- ~- --- ---. __ _ __ . _~ ___ __ _ _. ~ i TecWel LDL ~ ~ 02-Jun-09 ~ +- , i --- -. ~ ' ------- - ~,; ~_- ~--- ------ , ; __ , i~ ,- : - - - - _ --- _ . _ _ _ _ ---- ~ ' 00 `~--_ - - ---------- _.. ~_ ~ #~ ~ ; - - ----- : ~ , -~ i ~, - , ~. L . . ~~~,~,~ _ . , . . ___ :ker I i ~ -~ l~ i...- - -- --- - - ~--+- ,7 _ 5 ! • RIGft AUDI 2 WELLf P-3 TUBING SIZE 4-1/2" TUBING WT 12.60 TUBING THREAD TDS TUBING GRADE 13 CHRM DATE 6/7191 TUBING SUMMARY Rlg AUDI 2 Det• 6/7/91 Wall ~ P-3 Tubing 4- t/2" 12.60 TDS 13CHR KB: ' AGL 260JTS ON RACK 253 JOINTS RAN 7 JT3. OUT 9983.04 FT. ON RACK 9716.59 FT.RAN 266.45 FT. OUT 6 ~ WELL SERVICE REPORT ~ LJ WELL P'O3A JOB SCOPE LEAK DETECTION LOG UNIT SWCP #10 DATE 6/1/2009 DAI~Y WORK GAS LIFT--TO DUMMY VALVES; IN PROGRESS DAY SUPV VARBLE COST CODE PLUS PBPPDWL03-I KEY PERSON SWCP-PERLJ NIGHT SUPV CHAMBERS MIN ID 2.441 " DEPTH 10254 FT TTL SIZE 3.958 " DAILY SUMMARY ""`"CONT JOB FROM 5-31-09'*"* (Idl) DRIFT W/ 3.80" GAUGE RING TO X-NIPPLE @ 9955' MD. UNABLE TO PASS 9892' SLM. ATTEMPT TO SET 4 1/2" X-LOCK CATCHER SUB. GOT STUCK @ 548' SLM. X-LINE CAME BACK COVERED IN SCNMOO AND SHIFTED. BRUSH & FLUSH TUBfNG W/ 4 1/2" BRUSH, 3.80" GAUGE RING TO 9955' SLM. SET 4-1/2" X-LOCK CATCHER SUB C~ 9929' SLM. PULLED DGLV FROM STA # 1@ 9905' MD & STA # 2 C 9533' MD. SET BK-DGLV W/ EXT PACKING IN STA #2 @ 9533' MD & STA #1 9905' MD. PULL EMPTY CATCHER SUB FROM 9929' SLM. "*""CONT JOB ON 6-2-09""`* LOG ENTRIES Init Tb , IA, OA -> 250 30 0 TIME COMMENT 00:00 CONT JOB FROM 5-31-09..CURRENTLY RIH W/ 2' 1 7/8" STEM, 3.80" GAUGE RING.. S/D ~ 9892' SLM..UNABLE TO WORK PAST..POOH 01:13 OOH W/ TOOLS..NO MARKS ON GAUGE RING. 01:33 RIH W/4 1/2" X-LINE (SEL), 4 1/2" X-LOCK CATCHER SUB. GOT PICK UP WEIGHT C~ 548' SLM. TOOK 1400# PULL TO COME FREE..CAME UP HOLE 20' AND IT TOOK A 1400# OJ LICK TO COME FREE..POOH 01:56 OOH W/ 700LS, X-LINE SHIFTED TO NON SEL AND COVERED IN THICK SCHMOO. NOTIFY COMP REP. GOING TO BRUSH & FLUSH. 02:26 STANDBY FOR LRS TANKER. LAY DOWN LUB AND REPACK S-BOX 03:54 LRS TANKER ON LOC, FINISH REPACKING S-BOX 04:33 P/T LUB 500# LOW 2500# NlGN..GOOD TEST..HAVE LRS BEGIN PUMPING HOT DIESEL 05:29 20 BBLS AWAY...RIH W/ KJ, 4 1/2" BRUSH, 2' 1 7/8" STEM, 3.80" GAUGE RING.. 05:47 LRS DOWN ON PUMP, CHANGE OUT FROM PERL TO GRAHAM, INSPECT LOC, PJSM 06:55 LRS CHANGE OUT, PJSM W/ LRS 07:30 LRS TRANSFER FLUIDS FROM TANKER 07:49 LRS BEGAN PUMPING 08:05 CONT R1H, CLEAN UP TUBING BRUSH DOWN TO 9955' SLM...POOH 10:25 OOH W/ TOOLS, CH ECK OUT TOOLS, CYCLE SSV 10:52 RIH W/ 4-1/2" X-LINE, 4-1/2" X- CATCHER SUB, SHIFT X-LINE, SD Ca? 9929' SLM SET CATCHER...POOH 13:00 OOH W/ NO CATCHER 13:22 RIH W/ KJ, 4-1/2" OK-6, 1-1/4" JDC TO STA # 1, LOC & SD C~ 9883' SLM LATCH VALVE TOP OUT SPANGS SEEN PRESSURE CHANGE...POOH 14:45 OOH W/ BK-DGLV 15:01 RIH W/ SAME TO STA # 2, LOC, SD C«~ 9512' SLM LATCH VALVE, 7 0-JAR LICKS TOOLS COME FREE 16:25 OOH W/ BK-DGLV 16:47 RIH W/ KJ, 4-1/2" OK-6, BK-DGLV W/ EXT PACKING TO STA # 2.. S/D C~ 9512' SLM, SET VALVE..POOH 18:14 CREW CHANGE TO PERL, INSPECT LOC, PJSM..CONT TO POOH.. 19:05 OOH W/ TOOLS VALVE SET..LAY DOW N LUB TO REPACK S-BOX. 24 TURNS ON .125 CARBON 19:56 RIH W/ KJ, 4 1/2" OK-6, BK-DGLV W/ EXT PACKING TO STA #1. LOC & S/D @ 9883' SLM. SET VALVE...POOH 21:30 OOH W/ TOOLS VALVE SET 21:40 RIH W/ 4 1/2" GS. LATCH AND PULL CATHER C~ 9929' SLM..POOH 23:16 OOH W/ EMPTY CATCHER..STAB BACK ON WELL, HAVE LRS R/U TO IA 23:59 CONT JOB QN 6-2-09 F inal Tb , IA, OA -> 300 200 0 JOB COSTS SERVICE COMPANY - SERVICE DAILY COST CUMUL TOTAL CH2MHILL LABOR $960 $1,980 EQUIPMENT FLEET $2,100 $4,200 ORBIS $1,300 $2,600 SCHLUMBERGER $8,582 $16,448 , ' ~~ . ~ SCHLUMBERGER PLUS 15 PERCENT $1,287 $2,467 WAREHOUSE $48 $8,160 PDS $0 ~ $19,600 LITTLE RED PLUS 20 PERCENT $0 $3,003 LITfLE RED $0 $15,018 TOTAL FIELD ESTIMATE: $14,277 $73,476 FLUID SUMMARY 1 BSL DIESEL FOR P/T SEE LRS LOG GAS LIFT VALVES GLM NUM GLM DEPTH VALVE TYPE PORT SIZE TRO LATCH TYPE COMMENTS 2 9,533 DUMMY BK EXTENDED PACKING 1 9,905 DUMMY BK EXTENDED PACKING • VV~L~ 4~~ TRAN~1/TTAL II. PeoAaive DiagNasric SErtvicES, INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 • RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmit~at letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn; Joe Lastufka LR2-1 900 Benson Bhrd. Anchorage, Alaska 99508 ~-~ ~,r~.r~~ . ~-~` J i.J ~' ~ L ~ ~ and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 9951$ Fax•. (907) 2458952 UTL+ !9~-~~' ~~ ~l 1) LeakDetection - WLD 02,Jun-09 P-03A Color Log / EDE 50-029-22176-01 2) yp Signed : Date : SUN Print Name: +~1 Cas L: Anchr PROACTIVE DIACiNO8TIC SERVICES, INC., 1S0 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 89518 PHONE: (907)245-8951 FAX: {807)245-88952 EMAIL : pdsanchorage~memorvloa.com WEBSITE : www.memorvlog~ com C:\Documems and Settings\Owner\Desktop\Tmnsmit_BP.docx a • WELL LQG r TR.4NSM/TTAL is PaoAciivE D'IayNOmc SEA, ANC. To: AOC~C Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/C~en Hole/Mechanical Logs and/or Tubing Inspectaon(Caliper/ MTT) The technical data listed below is being submitted herewith. lease acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and U~~ Iq~- ~a~s f~~Y ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907j 2458952 1) Leak Detection - WLD 31-May-09 R03A 2) Signed Color Log / E~ 50.029-2217fr01 N _. ~._- Date : ~~~~ D 3 ZOG~ Print Name: ~~~ ~iE ~. C~~ C,~t. ~,c~a~i~~i RP~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Ro SUITE C, ANCHORAGE, AK 88518 PHONE: (807)245-8951 FAX: (907)245$8852 E-IwA1L : ~dsancltoraaeCoDrnemorvlo~.com WEBSRE : .memorvlo®.com C:\Docnments and Settingsl0wner~DesktoplTrn,ismit BP.dacx MEMORANDUM TO: Jim Regg ~~~n ~I ~' ~r~ P.I. Supervisor FROM: RCN ~ f`f~ Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 28, 2009 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P-03A PRUDHOE BAY iJNIT P-03A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~= Comm Well Name: PRUDHOE BAY UNIT P-03A API Well Number: 50-029-22176-01-00 Inspector Name: RCN Insp Num: mitRCN090528124454 Permit Number: 197-228-0 Inspection Date: 4/10/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P-03A - Type Inj. ~/ TVD 8679 IA 23s0 2s10 2440 2370 P.T.D 19722so TypeTest SPT Test psi 2slo pA zo zo zo 20 Interval aYRTST p~ F / Tubing soo soo soo soo NOtes' This was the second attempt on this well today. We bumped it up and watched it fail again. The orig. IA pre-test pressure was 1020 psi - Pr-~ 3~o u~ ~~ N~,~~ ~~>Lv-sts5~~ ~ `~~-ti~c~ ,c,t,-i-~ ~~~ ~- ~~1~(z~v~ Thursday, May 28, 2009 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska (hl and Gas Conservation Conmussion llATI:: Wednesday, April 15.2009 To: Tim Regg ---~ P.I. Supervisor ~~~ ~ 4 I ~~'~~ ~j SLIIT.TF,C'I': Mechanical Integrihr "I'~ts [3P EXPLORr\TiC)N (ALASIG\)1NC P-03A F'KOmt: l3ob Noble Pxunxol: sAV t,~rr P-os:~ Petroleum Inspector Src: Inspector nlnn]_t'(~NFiDFNTIAL Keviewed ITy: Y.I. Suprv ~~-- Comm Well Name: rRUnxoE BAY uNrr P-osA API Well Number: so-o29-zzt~6-of-otl Inspector Name: Bob Noble ,ni~RCN090413054959 Permit Number 197-22R-0 ~ Inspection Date• a'1or2009 Insp Num: • Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. -15 Min. 60 Min. - - ~ ~ _i Well . P o3~ !T~ a In . ' _I-TVp ~ xh~~ ~ IA ~ u~_~) ~ _xx) ~ . yin ~ ..3so } _.. i _.. _ P T. rti9r_~xortT~peTest LSP7 Test,pst ~ -.__ ?S~xi 1 DA ~ ~ . _! _ + - - - -- - __ _ i _ _ ~_ _ __ - t xiu) xcx~ r x~u) I xa~ ' .Interval aY1zTS'r P/F _ __ r - Tubing i_ _ l ~ I _. _ ~ --- --- Notes' We pump it up again and it still failed. ~~~n J~~vVtQ.- - ~ -'' dZL Wednesday, Aprit I>. 2009 Page 1 of 1 NOT OPERABLE: P-03A (PT~#1972280) Failed MITIA for AA Com~nce Page I of 1 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Friday, April 10, 2009 8:20 PM ~~~ ~~ ~~~ ~ ~~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; GPB, GC1 Wellpad Lead; GPB, Well Pad YP; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Wells Opt Eng; Brown, Don L. Cc: Quy, Tiffany; NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: NOT OPERABLE: P-03A (PTD #1972280) Failed MITIA for AA Compliance All, i ,ems ~o ~' ~" Well P-03A (PTD #1972280) is currently under AOGCC Administrative Approval for TxIA communication. The well failed a MITIA for AA compliance due to a lack of stabilization on 04/10/09. The request has been made to shut-in and~reeze protect the well as soon as possible. The well has been reclassified as Not Operable. ~'` Diagnostics to confirm a liquid leak rate will continue in order to evaluate the plan forward for the well. Please let us know if you have any questions. Thank you, Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 _~ ~. 4/14/2009 FW: P-03A (PTD #1972280) IA rewsurization Regg, James B (DOA) . Page 1 of2 From: NSU, ADW Well Integrity Engineer [NSUADWWelllntegrityEngineer@BP.com] \ \ 1 ç A ~. 11.... 1 -tA {) Sent: Tuesday, July 24,200710:26 AM \~'/l To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA) Cc: Engel, Harry R; Subekti, Herry; NSU, ADW WI Tech Subject: FW: P-03A (PTD #1972280) IA repressurization Attachments: MIT PBU P-03A 7-23-07 (2).xls Jim, Well P-03A passed an MITIA last night to 2500 psi. The well only required 2.1 bbls of neat methanol to pressure the annulus to 2500 psi. At this point we believe the IA repressurization is due to fluctuating water injection rates. Our current plan is to continue monitoring the IA pressure for signs of communication. I have attached the MIT form from last night's test. «MIT PBU P-03A 7-23-07 (2).xls» Please call with any questions or concerns. Thank you, Andrea Hughes SCANNED AUG Q 6 2007 From: NSU, ADW Well Integrity Engineer Sent: Monday, July 23, 2007 9:03 PM To: Regg, James B (DOA); Maunder, Thomas E (DDA); Rossberg, R Steven; Engel, Harry R; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC1 OTL; NSU, ADW Well Operations Supervisor; Subekti, Herry Cc: NSU, ADW Well Integrity Engineer; Holt, Ryan P (ASRC) Subject: P-03A (PTD #1972280) IA repressurization Jim and Tom, Well P-03A (PTD #1972280) is exhibiting signs of pressure communication between the tubing and IA. The IA build up rate from a bleed on 07/20/07 was found to be -200 psi/day with an IA fluid level at surface. Because the well is currently on produced water injection, we would like to keep the well on-line for diagnostics. The plan forward is as follows: 1. D: Bleed lA, BUR - DONE 2. F: AOGCC witnessed MITIA - Scheduled for 07/24/07 3. WIC: Shut-in well if fails, If passes eval if AA needed (due to fluid level at surface) A wellbore schematic, 90-day TIO plot and injection plot have been included for reference. Please call with any questions or concerns. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 7/24/2007 ADMINISTRATIVE APPROVAL AIO 3.020 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99~ 19-6612 ~~ s~~ ~ ~ 200 RE: PBU P-03A (PTD 1972280) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 03.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or '`Commission") hereby grants BP Exploration (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water injection in the subject well. PBU P-03A exhibits inner annulus repressurization that is being managed by periodic pressure bleeds. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU P-03A. The Commission further finds that, based upon reported results of BPXA's diagnostic procedures and wellhead pressure trend plots, PBli P-03A exhibits two competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection in PBU P-03A 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, injection rates, and IA pressure bleeds; 3. BPXA shall perform an MIT-IA every 2 years to 1.2 times the maximum anticipated well pressure; 4. BPXA shall limit the well's IA pressure to 2,000 psi; A[O 03.020 September 14, 2007 Page 2 of 2 5. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 6. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection, and 7. The NIIT anniversary date is April l; 2007. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DONE at AnclZorage, Alaska and dated September 14, 2007. y / ~ : ~%~ ~~ Chairman Daniel T. Seamount, Jr Commissioner ~,-~~ ~ .~ e ~,~, ,f ~. ~ ~~ ~,; -~ ~` ~~~c -~ +, ~~ ~~. ~~ i Q~~ ..J ` _ ~_xyJ~~ '~~~~~r ~~~~~ti ~~y ~~ Cathv . Foerster Com issioner FW: P-03A (PTD #1972280) IA rewurization Pager: (907) 659-5100 x1154 . Page 2 of2 7/24/2007 . . 1.eúq 1\ZA\D1 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.uS;Jim_Regg@admin.state.ak.us;Tom_Maunder@ad~in.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test BP Exploration (Alaska), Inc. Prudhoe Bay 1 PBU 1 P-Pad 07/23/07 Andrea Hughes N/A Packer Depth Pretest Initial 15 Min. 30 Min. Weill P-03A I Type Inj. I W TVD I 8,679' Tubing 2180 2160 2160 2160 Interval I 0 p.T.D.1 1972280 I Type test I P Test psil 2500 Casing 1050 2500 2460 2450 P/FI P Notes: MIT-IA for integrity verification. OA 0 0 0 0 Weill I Type Inj. I I TVD I Tubing Interval I P.T.D.I I Type test I I Test psil Casing P/FI Notes: OA Weill I Type Inj.1 I TVD I I Tubing I Interval! p.T.D.1 I Type test I I Test psil I Casing P/FI Notes: OAI Weill I Type Inj.1 TVD I Tubing I I Interval I p.T.D·1 I Type test I Test psi I Casing I I P/FI Notes: OA I I Weill I Type Inj.1 TVD I Tubing Intervall P.T.D. Type test I Test psi! Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT PBU P·03A 7·23·07 (2).xls 'd-'ð \q1~~ / P-03A 110-3/4" CSG, 45.5#, NT-80, 10 = 9.953" Minimum ID = 2.441" @ 10254' TOP OF 2-7/8" LINER 14-1/2" TBG,12.6#, 13-CR, .0152 bpf, 10" 3.958" 1 9987' 1 TOP OF 5-1/2" TIW LNR I 17-5/8" CSG, 29.7#, NT-95-HS, 10" 6.875" I I TOP OF 2-7/8" LNR I . SAFETY NOTES: 70° @ 10462' AND 90° @ 10566' *** CHROMETBG AND LNR *** 2048' -14-1/2" OTIS HXO SSSV NIP, iD" 3.813" ST MD TVD 5 2985 2893 4 5721 5421 3 8073 7155 2 9533 8271 1 9905 8565 GAS LIFT MANDRELS DEV TYÆ VLV LATCH o CA-KBMG OMY BK 42 CA-KBMG DMY BK 39 CA-KBMG Otv1Y BK 39 CA-KBMG DMY BK 37 CA-KBMG OMY BK PORT DATE o 02/11/07 o o o 02/11/07 o 02/11/07 9922' -14-1/2" PKR SWS NIP, ID = 3.813" I 9932' H RIGHT HAND RELEASE LA TCH I 9933' -i7-518" x 4-112" TIW HBBP PKR, 10 = 4.0" 9955' -i4-1/2" PKR SWS NIP, 10 - 3.813" I 9975' -i 4-1/2" PKR SWN NIP, MILLED 10 = 3.80" 9987' -i4-1/2" WLEG, 10 - 3.958" I 9977' H ELMO TI LOGGED 07/14/91 --i BKR DEP SL V W/3" PROFILE I PERFORATION SUMMA RY REF LOG: SPERRY SUN MVVO GR ON 01/20/98 ANGLE AT TOP PERF: 97 @ 11020' Note: Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 11020 - 11060 0 05120/99 2" 4 11270 - 11310 0 05/20/99 1-2/3" 4 11890 - 11935 0 01/22/98 1-2/3" 4 11956 - 12000 0 01/22/98 1-2/3" 4 12198 - 12240 0 01/22/98 1-2/3" 4 12333 - 12376 0 01/22/98 1-2/3" 4 12610 - 12650 0 01/22/98 1-2/3" 4 12743 - 12786 0 01/22/98 I TOP OF WHIPSTOCK I I PBTD I 15-112" LNR, 17#, 13-CR, .0232 bpf, ID = 4.892" I DA TE REV BY COMMENTS 06/09/91 HF ORIGINAL COMPLETION 0i/22/9S HllDRET SIDETRACK COM PlETION 02/28/02 RNITP CORRECTIONS 04/20/04 JLJ/KAK MILLED NIP 10 CORRECTION 09/25/06 JCMlPAG SET PX TIP @ 9922' 11/12/06 JLJ/TLH PX TIP PULLED (11/2/06) MILLOUT WINDOW 10292' - 10299' DA TE REV BY COMMENTS 02/11/07 CJN/PAG GLV C/O PRUDHOE SA Y UNrT WELL: P-03A PERMrT No: 197-2280 API No: 50-029-22176-01 SEC31, T11N, R13E BP Exploration (Alas ka) . MEMORANDUM State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~ P.I. Supervisor ',~ ~ 7 4/ ~ 107 DATE: Monday, April 23, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC P-03A PRUDHOE BA Y UNIT P-03A ~ryCó \<\1/ FROM: Bob Noble Petroleum Inspector Src: Inspector Reviewed By: ..-= P.I. Suprv _ )î:si2-- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT P-03A API Well Number: 50-029-22176-01-00 Inspector Name: Bob Noble Insp N um: mitRCN070416172549 Permit Number: 197-228-0 Inspection Date: 4/I6/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well P-03A Type Inj. I w TVD 8679 IA 450 4010 3850 I 3840 P.T.D 1972280 TypeTest I SPT Test psi 2169.75 OA 20 20 20 20 Interval OTHER P/F P / Tubing 1780 1780 1780 1780 Notes: Pre Ml swap SCANNED APR 3 0 Z007 Monday, April 23, 2007 Page 1 of 1 . . 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;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: Well BP Exploration (Alaska), Inc. Prudhoe Bay I PBU / P pad 04/16/07 Anna Dube Bob Noble \ Gtì -1-1---3 Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 Tubing Casing OA Tubing Casing OA TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 4 P INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) 5CANNiD APR 1 9 20D1 MIT PBU P-03A 04-16-07.xls RE: STATUS: P-03A (PTD 1972280) IA Rep.ization - MIT form . Jim and Tom, The T ecwel LOL run on P-03 (PTO #1972280) found leaks at gas lift mandrels #1 , #2 and #5. The gas lift valves in these mandrels have been changed and a subsequent MITIA passed to 4000 psi. Please /" see the attached MIT form for the MITIA performed on 04/01/07. The plan forward for this well is as follows: 1. WOE: Put on PWI 2. FB: AOGCC witnessed MITIA to 4000 psi (pre MI swap) 3. WIC/WOE: Swap to MI and monitor for TxlA communication. / The well has been changed from Trouble to Normal status. «MIT PBU P-03A 04-01-07.xls» Please call with any questions. Thank you, Andrea Hughes Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 sCANMED À?R 0 5 2007 --~~~ From: NSU, ADW Well Integrity Engineer Sent: Saturday, December 09,20063:15 PM To: 'Winton Aubert (E-mail)'; 'James Regg' Cc: GPB, Wells Opt Eng; GPB, Optimization Engr; Cismoski, Doug A; Kurz, John; GPB, GCl Area Mgr; GPB, GC1 Wellpad Lead; NSU, ADW WI Tech; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Kaminski, Alice; GPB, Well Pad YP; NSU, ADW Well Integrity Engineer Subject: RE: STATUS: P-03A (PTD 1972280) IA Repressurization 10f2 4/3/20072: 13 PM RE: STATUS: P-03A (PTD 1972280) IA ReP.ization - MIT form . Hello Jim & Winton. i A bleed conducted 12/6/06 confirmed IA repressµrization on welt P-03. The IA pressure was bled from 1350 to 390 psi, and repressured to 1280 the next day. Tubing pressure is 1100 psi. I , As per AI03, the well will be shut-in. Current plans are to run a 'TecWell" noise log and attempt to determine the leak point. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com From: NSU, ADW Well Integrity Engineer Sent: Tuesday, December 05,20069:31 PM To: 'Winton Aubert (E-mail)'; 'James Regg' Cc: NSU, ADW Well Integrity Engineer; GPB, Wells Opt Eng; GPB, Optimization Engr; Cismoski, Doug A; Kurz, John; GPB, GC1 Area Mgr; GPB, GC1 Well pad Lead; NSU, ADW WI Tech; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; NSU, ADW WL & Completion Supervisor; Kaminski, Alice; GPB, Well Pad YP Subject: STATUS: P-03A (PTD 1972280) IA Repressurization Hello Jim & Winton. Injection well P-03A (PTO 1972280) exhibits IA repressurization when on injection. The Operator reported the IA repressured to tubing pressure overnight. An MITIA on 11/9/06 passed to 3000 psi. Recent events: > 11/09/06: MIT-IA Passed to 3000 psi > 12/03/06: Operator bled lAP to 360, repressured to tubing pressure overnight Current plan is to conduct an additional bleed to confirm the Operators results. If the IA repressures, we will shut-in the well and evaluate further diagnostic work. The well has been added to the monthly UIC report. Attached is a wellbore schematic and wellhead pressure plot, please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com Content-Description: MIT PBU P-03A 04-01-07.xls MIT PBU P-03A 04-01-07.xls Content-Type: applicationlvnd.ms-excel Content-Encoding: base64 2 of2 4/3/20072: 13 PM . . 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;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD 1 UNIT 1 PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay 1 PBU 1 P pad 04/01/07 Andrea Hughes j~r. ·1 bt.\4° Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIP-03A I Type Inj. I N TVD I 8,679' Tubing 0 0 0 0 Interval 0 p.T.D.11972280 I Type test I P Test psi! 4000 Casing 320 4,000 3,940 3,910 P/FI P Notes: MITIA to evaluate tubing repair, pre-POI. OA 20 20 20 20 Weill Type Inj. I I TVD I Tubing Interval I P.T.D.I Type test I I Test psi! Casing P/FI Notes: OA Weill I Type Inj.1 TVD I I Tubingl Intervall p.T.D.1 I Type test I I Test psi I Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing I I I Intervall P.T.D.I I Type test I Test psi I Casing I I P/FI Notes: OA I I Weill I Type Inj.1 TVD I Tubingl Interval I P.T.D·I I Type test I Test psil Casing I P/FI Notes: OAI ~/ TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly SUNey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) MIT Report Form BFL 9/1/05 MIT PBU P-03A 04-01-07.xls . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Records Department 333 W. 7th Ave Suite 100 Anchorage. Alaska 99501 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1) 2) 3) 4J 5) 6) 7) Leak Detection(WLD) EDE Disk P - 03Ai 09-Feb'()7 SCANNED FEB 1 4 2007 u:r~ ¡0-q.-GG'Ö t:1: ¡L¡Lf9<7 Signed: ~- .ÞL-- 1 4 Z007 Date: Print Name: &(;~.f-h1.0_ mOJU/lk.eVl PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPOIU RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: PDSANCHORAGE@MEMORYLOG.CCM WEBSITE : \i\¡;i'l'J"\LMEMORYLCH3"COM C:IDocuments and SettingslPDS Anchorage - MPLIDesktoplTransmit_ Original. doc STATUS: P-03A (PTD 1972280) IA Repressurization . . Hello Jim & Winton. Injection well P-03A (PTD 1972280) exhibits IA repressurization when on injection. The Operator reported the IA repressured to tubing pressure overnight. An MITIA on 11/9/06 passed to 3000 psi. Recent events: > 11/09/06: MIT-IA Passed to 3000 psi > 12/03/06: Operator bled lAP to 360, repressured to tubing pressure overnight Current plan is to conduct an additional bleed to confirm the Operators results. If the IA repressures, we will shut-in the well and evaluate further diagnostic work. The well has been added to the monthly UIC report. Attached is a wellbore schematic and wellhead pressure plot, please call with any questions. «P-03A.pdf» «P-03 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.eom "./" ¡, '!}.u..s¥:;:rh ð:~~j~JtJ~c..tJ {. q ., I"., (", l Content-Description: P-03A.pdf P-03A.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: P-03 no Plot.jpg TIO Plot.jpg Content-Type: image/jpeg Content-Encoding: base64 1 of 1 12/7/2006 9:55 AM TREE = 4-1/16" 5M CIW W8-LHEAD = ACTUA TOR = KB. 8-EV = BF. 8-EV = KOP= Max Angle = P-03A SAFEfY NOTES: 700 @ 10462' AND 900 @ 10566' **. CHROM E TBG AND LNR *** . 2048' -)4-1/2" OTIS HXO SSSV NIP, ID = 3.813" I 110-314" CSG, 45.5#, NT-80, ID = 9.953" Minimum ID = 2.441" @ 10254' TOP OF 2-7/8" LINER GAS LIFT MANDR8-S ST MD 1VD DEV TYÆ VLV LATCH PORT DATE 5 2985 2893 0 CA-KBMG BK 4 5721 5421 42 CA-KBMG BK 3 8073 7155 39 CA-KBMG BK 2 9533 8271 39 CA-KBMG BK 1 9905 8565 37 CA-KBMG BK 9922' -i 4-1 12" PKR SWS NIP, ID = 3.813" 9932' 9933' H RIGHT HAND R8-EASE LATCH I -)7-5/8" X 4-112" TIW HBBP PKR, 10 = 4,0" 9955' -)4-1/2" PKR SWS NIP, ID = 3.813" I 9975' -)4-1/2" PKR SWN NIP, MILLED ID = 3.80" TOPOF 5-1/2" TIW LNR I 14-1/2" TBG,12.6#, 13-CR, .0152 bpf, 10 = 3.958" I 9987' 9987' -)4-1/2" WLEG, 10 = 3.958" I 9977' H ELMO TI LOGGED 07/14/91 17-5/8" eSG, 29.7#, NT-95-HS, ID = 6.875" I I TOP OF 2-718" LNR I ÆRFORA TION SUMI\,1ARY REF LOG: SPERRY SUN MWO GR ON 01/20/98 ANGLEAT TOP ÆRF: 97@ 11020' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 2" 4 11020 - 11060 0 OS/20/99 2" 4 11270 - 11310 0 OS/20/99 1-2/3" 4 11890 - 11935 0 01/22/98 1-2/3" 4 11956-12000 0 01/22/98 1-2/3" 4 12198 - 12240 0 01/22/98 1-2/3" 4 12333 - 12376 0 01/22/98 1-2/3" 4 12610 - 12650 0 01/22/98 1-2/3" 4 12743 - 12786 0 01/22/98 MILLOUT WINDOW 10292' - 10299' I TOP OF WHIPSTOCK I I PBTD I ¡ 2-7/8" LNR, 6,16#, L-80, ,00579 bpf, 10=2.441" 15-1/2" LNR, 17#, 13-CR, .0232 bpf, 10 = 4.892" I OA TE REV BY COMMENTS 06/09/91 HF ORIGINAL COMPLETION 01/22/98 HILDRET SIDEfRACK COM PLETION 02/28/02 RN/TP CORRECTIONS 04/20/04 JLJ/KAK MILLED NIP ID CORRECTION 09/25/06 JCfvVPAG SET PX TIP @ 9922' 11/12/06 JLJITLH PX TIP PULLED (11/2/06) OA TE REV BY COMMENTS PRUDHOE BA Y UNfr WELL: P-03A PERMfr No: 197-2280 Apt No: 50-029-22176-01 SEC 31, T11 N, R13E BP Exploration (Alaska) .... Re: P-03A (PTD# 1972280) Plan Forward . . Well has been operated in the past as a WAG injector, and leaks to MI. You are commencing water injection, correct? What is the reason for the OA pressure that has stabilized near 1000 psi while well has been SI? I see from well history in our files there was an MITOA failure on 5/18/2001 with no additional info about follow-up. This should be addressed in your plans as well. Jim Regg AOGCC NSU, ADW Well Integrity Engineer wrote: Hello Jim & Winton, Injection well P-03 (PTD# 1972280) was shut in due to an MIT-IA conducted 12/6/02 that failed on pressure stabilization. On 09/25/06, both an MIT-T and MIT-IA passed to 3000 psi. The failure on 12/02 is thought to potentially be due to thermal effects. Our plan is to re-start injection and repeat the MITIA once the well is thermally stable. Planned actions: 1. SL: Pull TTP 2. Put on injection 3. FB: Conduct AOGCC witnessed MIT-IA Qf Attached is the wellbore schematic. Note the TIO plot starts 10/01. please call with any questions or comments. «P-03A.pdf» «P-03 TIO Plot.jpg» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: NSUADNWellIntegrityEngineer@bp.com 'brì ~¡~~~-k,,~ \¡Jet( I a:Ù· s v:J / i~\r SC0(¡ppècA. -k:) ~ C,-,*'r i r\\ec-h~,- (T x]:A ) it \ 17 zv() 2-- .1'v't¡:7 0[+ .-Çule8 <J hstz.où! ,_. S1- $I,ye .bec ZCù?- I of 1 10/24/2006 2:43 PM TREE" 4-1/16" 5M CIW WELLHEAD" 5M FMC ACTUA TOR = OTIS KB. ELEV = 91.54' BF. ELEV = 56.05' KOP = 3952' Max Angle = 101 @ 10634' Datum MO = Datum TVD = 8800' SS P-03A 110-3/4" CSG, 45.5#, NT-80, 10 = 9.953" Minimum ID = 2.441" @ 10254' TOP OF 2-7/8" LINER 14-1/2" TBG,12.6#, 13-CR, .0152 bpf, 10=3.958" I 9987' I TOP OF 5-1/2" TIW LNR I 17-5/8" CSG, 29.7#, NT-95-HS, 10 = 6.875" I TOPOF 2-7/8" LNR I ÆRFORA TlON SUMMARY REF LOG: SÆRRY SUN MWO GR ON 01/20/98 ANGLEAT TOP ÆRF: 97 @ 11020' Note: Refer to A-oduction OB for historical perf data SIZE SPF INTERVAL Opn/Sqz OATE 2" 4 11020 - 11060 C OS/20/99 2" 4 11270 - 11310 C OS/20/99 1-2/3" 4 11890-11935 C 01/22/98 1-2/3" 4 11956 - 12000 C 01/22/98 1-213" 4 12198 - 12240 C 01/22/98 1-213" 4 12333 - 12376 C 01/22/98 1-2/3" 4 12610 - 12650 C 01/22/98 1-213" 4 12743 - 12786 C 01/22/98 I TOP OF WHIPSTOCK I PBTD 5-1/2" LNR, 17#, 13-CR, .0232 bpf, 10 = 4.892" SAFETY NOTES: 700 @ 10462' AND 900 @ 10566' *** CHROMETBG AND LNR*** . 2048' -14-1/2" OTIS HXO SSSV NIP, 10'" 3.813" I ST MO TVD 5 2985 2893 4 5721 5421 3 8073 7155 2 9533 8271 1 9905 8565 GAS LIFT MANDRELS OEV TYÆ VLV LATCH o CA-KBMG BK 42 CA-KBMG BK 39 CA-KBMG BK 39 CA-KBMG BK 37 CA-KBMG BK PORT OA TE -14-1/2" PKR SWS NIP. 10 = 3.813" -14-1/2" PX TIP SET (09/25/06) I H RIGHT HAND RELEASE LA TCH I -17-5/8" X 4-1/2" TIW HBBP PKR, 10 = 4.0" 9955' -14-1/2" PKRSWS NIP, 10= 3.813" I 9975' -14-1/2" PKR SWN NIP, MILLED 10 '" 3.80" 9987' -14-1/2" WLEG, ID == 3.958" I 9977' H ELMD TI LOGGED 07/14/91 -1 BKR OEP SL V W/3" PROFILE I MILLOlJf WINDOW 10292' - 10299' DA TE REV BY COMMENTS 06/09/91 HF ORIGINAL COMPLETION 01/22/98 HILDREr SIDETRACK COM PLETION 02/28/02 RNrrp CORRECTIONS 04/20/04 JLJ/KAK MILLED NIP 10 CORRECTION 09/25/06 JCMlPAG SET PX TIP@ 9922' OA TE REV BY 2-7/8" LNR, 6.16#, L-80, .00579 bpf, 10 = 2.441" COMMENTS PRUDHOE SA Y UNIT WELL: P-03A ÆRMIT No: 197-2280 API No: 50-029-22176-01 SEe 31, T11N, R13E BP Exploration (Alas ka) TIO 827x280 KJ:<,: P-03A (PTD #1972280) MIT Fonn ErrO. . Hi Jim. Attached is a revised MIT form for P-03A. Sorry about the confusion, please let me know if you have any questions. Joe Anders, P.E. Welllntegríty Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEnç¡íneer@bp.eom .....ç..,., .. II..\NS1 - . "~T~:J j~1'--'" ..J _.9:' tr:~ \_.:" ..:--:", '-?" From: James Regg (mailto:jim_regg@admin.state.ak.us] Sent: Monday, October 02, 2006 11:43 AM To: Hughes, Andrea Cc: Winton Aubert (E-mail); Bob Fleckenstein (E-mail); N5U, AOW Well Integrity Engineer; Admin AOGCC Prudhoe Bay Subject: Re: 01-11 (PTO #1770570) PBU P-03 (should be P-03A) It appears based on pressures that P-03A was evaluated with an MITT and an MITIA, although the remarks for each indicate both were MITIAs; please confirm the test results. Jim Regg AOGCC Hughes, Andrea wrote: Jim, Winton and Bob, Please see the attached MIT forms for the following wells. NGI-01 (PTO #1750480) MITIA and MITOA for variance, witness by AOGCC representative Chuck Scheve NGI-10 (PTO #1760690) MITIA and MITOA for variance, witness by AOGCC representative Chuck Scheve. The plan forward is to change out the tree and repeat the MITIA. 01-11 (PTO #1770570) MITIA for evallAxOA communication AGI-05 (PTO #1930020) MITIA for variance, witness by AOGCC representative Chuck Scheve NGI-13 (PTO #1780910) MITIA for variance, witness by AOGCC representative Chuck Scheve. The plan forward is to perform SSSV work, reset the IBP, and repeat the MITIA. P-03 (PTO #1972280) MITT and MITIA for eval TxlA communication. Both tests passed, indicating no lof2 10/23/20064: 15 PM Rb: P-U3A (PID #1972280) MIT Form Errors . . communication to liquid. The plan forward is to pursue a variance for slow TxlA communication. «MIT PBU NGI-01,10 09-18-06.xls» «MIT PBU 01-11 09-19-06.xls» «MIT PBU AGI-05 09-19-06.xls» «MIT PBU NGI-13 09-18-06.xls» «MIT PBU P-03 09-25-06.xls» Thank you, Andrea Hughes (Filling in for Anna Dube) Well Integrity Engineer Office: (907) 659-5102 Pager: (907) 659-5100 x1154 PBU P-03A Content-Description: MIT PBU P-03A 09-25-06.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 2of2 10/23/20064: I 5 PM . . 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;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERA TOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / P pad 09/25/06 Andrea Hughes ~ ~... ð- d-' \~\ Packer Depth Pretest Initial 15 Min. 30 Min. WellIP-03A I Type Inj. I N TVD I 8,679' Tubing 3,100 3,025 3,000 Interval 0 PTD.I1972280 I Type test I P Test psi 2170 Casing 160 340 350 350 P/F/ P Notes: MIT-Tubing OA 900 900 900 900 Well I P-03A I Type Inj. 1 N I TVD I 8,679'1 Tubing 3,000 575 575 575 Interval 0 P.T.D./1972280 I Type test I P I Test psil 21701 Casing 350 3,000 3,000 3.000 P/FI P Notes: MIT-IA I OA 900 900 900 900 Weill ! Type Inj.1 I TVD I Tubing I I I Interval P.T.D.I I Type test I I Test psi I Casing I I I P/F Notes: I OA I Weill I Type Inj.1 I TVD I Tubingl I I Intervall PTD. I Type test I I Test psi I Casing I 1 1 P/Fl Notes: OAI I 1 I Weill / Type Inj.! TVD / Tubing I Intervall P.T.D. I Type test/ / Test psi! Casing I P/Fl Notes: OA I I TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer SUlVey A = Temperature Anomaly SUlVey D = Differential T emperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= other (describe in notes) MIT PBU P-03A 09-25-06-1.xls MEMORANDUM State of Alaska Alaska Oil and Gas Consen'ation Commission TO: Jim Regg 1J 7 I'?~I P.I. Supervisor f-..,t1? 7 L) L'4 DATE: Thursda). July 22. 2004 SllBJ ECT: f\kchamcallmegrll)' T es!s BP EXPLORA TlON (ALASK.A I fNC FROI\1: Lou Grimaldi Petroleum Inspector P-03A PRUDHOE BAY UNIT P-03A Src: Inspector Re\'iewed B\': PJ. Supr\' 'jsr...:- Comm NON-CONFIDENTIAL \Vell Name: PRUDHOE SAY UNIT P-03A Insp Num: mi!LG040716090854 Rei Insp Num: API \Vell Number: 50-029-22176-01-00 Permit Number: 197-228-0 Inspector Name: Lou Grimaldi Inspection Date: 7/16/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. \Ve II I P-03A Type (nj. I P TVD 915'¡ IA 500 ~530 ~525 ~520 P.T. I 19n280 TypeTest I SPT Test psi 21695 01\ 2ú 20 20 20 Inten'al onŒR PIF p Tubing .¡60 2530 2525 2520 Notes: Combo f\IIT pTlor to Sundry application. Thursday. July 22.2004 Page 1 of I Re: FV~,PBU injector P-03A Subject: Date: From: Organization: To: CC: Re: FW: PBU injector P-03A Tue, 31 Dec 2002 15:03:12-0900 Jim Regg <jim_regg~admin.state.ak.us> AOGCC }q7- zz 6 "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer~BP.com> 'Tom Maunder' <tom_matmder~admin.state.ak.us>, Admin AOGCC Prudhoe Bay <aogcc_prudhoe_bay@admin. state.ak.us>, Winton G Aubert <winton aubert~admin.state.ak.us> Brandon - Thanks for calling about the need for a sundry application and for clarifying BP's intentions regarding P-03A. You indicated that the well is currently shut in. Additiona diagnostics are planned for the well at this time; you further indicated the lack of water at P-pad means there are no plans to inject water. In lieu of a sundry application at this time (approving continued injection), you should continue with diagnostics that will help delineate the specific well work needed to restart MI injection (the real utility for P-03A per your message below). Thank you for adding the Well P-03A to the monthly injection well monitoring report. We would appreciate a brief status update of the diagnostics weekly - simple email message would be sufficient. Please note that any work to repair the well will require a sundry application and approval from the Commission. I hope this clarifies our expectations for P-03A. Feel free to contact me if you need to discuss further- I will be back in the office Thursday, 1/2/03. Happy New Year. Jim Regg "NSU, ADW Well Integrity Engineer" wrote: Jim,Per our conversation this afternoon, this is a note to clarify our plan forward With WAG injector P-03A. The MIT-IA failed on 12/06/02, confirming that we have TxlA communication. We do not wish to pursue a sundry at this time because this section of the field, currently receives very little water for injection; P-03A would likely remain shut in if limited to PWI only. We would like to continue our diagnostic work as this well's real utility is in its MI pattern. Our plan forward is to check the PO's again for evidence of communication. If that does not pinpoint the problem, further diagnostic work may include replacing the dummy gas lift valves or displacing the tubing with nitrogen and running a video log to identify liquid entry. This well is currently shut in, and we have no intentions of bringing it back online without first contacting you. Per your request, we will also add this well to the list of monthly injection monitors we send you. If you have any additional questions, please e-mail or call the Well Integrity Engineers at 659-5102. Thank you.Brandon McNerlin659-5157 ..... Original Message ..... From: Tom Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Monday, December 16, 2002 1:34 PM To: NSU, ADW Well Integrity Engineer Subject: Re: FW: PBU injector P-03A Brian, 1 of 3 12/31/2002 3:05 PM Re: FW:,,pBU injector P-03A This acknowledges receipt of your most recent message regarding P-03A. I went back and checked the messages I had and it appears that your latest work has confirmed the communication. What in the past looked like just a leak to gas (MI) now appears to have a leak to water as well. Based on the information you have established, it is appropriate to apply for the sundry. Prior to the most recent work, the leak was suspected but not confirmed. You now have confirmed it. If the decision is to patch the leak to effect repair, then the sundry can be canceled. However, based on the information you have in hand, it is appropriate to submit the sundry paperwork. Please plan to submit it before year end. Please call with any questions. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom, P-03A (PTD 1972280) is a WAG injector exhibiting slow IA repressurization while on MI. This well was shut in as of 12/02/02. I wanted to update you on the results of the failed MITIA on 12/6/02. This is the second MITIA, and it was performed due to the high IA Pressure Build Up rate observed on 12/01/02. The first MITIA on 11/23/02 had passed, but with less differential pressure. Recent Well Events:> 11/23/02: MITIA to 3000 psi- passed > 12/01/02: lAP Built Up from 450 psi to 2250 psi overnight. > 12/06/02: MITIA to 3000 psi FAIL with 2700 psi differential between IA and tubing. LLR=0.4gpm.We will continue to evaluate P-03A to find the leak source. The current plan is to return the well to water injection and pursue a sundry to allow cOntinued water injection only if the leak can not be repaired. We'll keep you informed of the evaluation progress. Please call Kevin Yeager or Joe Anders at 659-5102 if you have any questions concerning this data or the plan forward.Thank you.Bryan McLellanWells P.E.(907) 659-5157 ..... Original Message ..... From: NSU, ADW Well Integrity Engineer Sent: Sunday, December 01, 2002 3:44 PM To: AOGCC Tom Maunder (E-mail) Subject: PBU injectors 14-35i, P-03Ai Hello TomP-03Ai (PTD 1972280)WAG Injector on PWl as of 11/19/02. I wanted to update you on the status of our diagnostic plan per our last note dated 11/25/02. We have monitored IA pressure build up rates over the last week following a Passing MIT-IA to 3000 psi on 11/23/02. > 11/26/02 T/IlO - 1900 / 2150 / 300 - Bled IAto 450 psi and monitor for 1 hr with no change. Final pressures 1900 / 450 / 100> 11/27/02 T/IlO = 2000 / 550 / 0 > 11/29/02 T/IlO - 2010 / 1500 / 120> 11/30/02 T/IlO = 2250 / 2250 / 200 - Bled IA from 2250 to 450 psi. Final pressures 2250 / 450 / 200> 12/01/02 T/IlO -- 1900 / 2250 / 350We plan to conduct a second MIT-IA to 3000 psi. This procedure will have the well shut in and the tubing bled off to test the IA with at least 2000 psi differential over the tubing. Again, we will send you a note with the results and plan forward. Please let me know if you disagree or have questions with our plans outlined above. Preston EvansWell Integrity Engineer695-5102 Jim Regg <jim_regg~admin.state.ak.us> Petroleum Engineer AOGCC Administration SGANNEB JAN g 201i3 12/31/2002 3:05 PM Re: FW: PBU injector P-03A Subject: Re: FW: PBU injector P-03A - (% Date: Mon, 16 Dec 2002 13:34:10 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> Brian, This acknowledges receipt of your most recent message regarding P-03A. I went back and checked the messages I had and it appears that your latest work has confirmed the communication. What in the past looked like just a leak to gas (MI) now appears to have a leak to water as well. Based on the information you have established, it is appropriate to apply for the sundry. Prior to the most recent work, the leak was suspected but not confirmed. You now have confirmed it. If the decision is to patch the leak to effect repair, then the sundry can be canceled. However, based on the information you have in hand, it is appropriate to submit the sundry paperwork. Please plan to submit it before year end. Please call with any questions. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom, P-03A (PTD 1972280) is a WAG injector exhibiting slow IA repressurization while on MI. This well was shut in as of 12/02/02. I wanted to update you on the results of the failed MITIA on 12/6/02. This is the second MITIA, and it was performed due to the high iA Pressure Build Up rate observed on 12/01/02. The first MITIA on 11/23/02 had passed, but with less differential pressure. Recent Well Events:> 11/23/02: MITIA to 3000 psi - passed > 12/01/02: lAP Built Up from 450 psi to 2250 psi overnight. > 12/06/02: MITIA to 3000 psi FAIL with 2700 psi differential between IA and tubing. LLR=0.4gpm.We will continue to evaluate P-03A to find the leak source. The current plan is to return the well to water injection and pursue a sundry to allow continued water injection only if the leak can not be repaired. We'll keep you informed of the evaluation progress. Please call Kevin Yeager or Joe Anders at 659-5102 if you have any questions concerning this data or the plan forward.Thank you.Bryan McLeilanWells P.E.(907) 659-5157 ..... Original Message ..... From= NSU, ADW Well Integrity Engineer ~ent-' Sunday, December 01, 2002 3:q~. PM To-' AOGCC Tom Maunder (E-mail) Subject-' PBU injectors :!.4-35i, P-03Ai Hello TomP-03Ai (PTD 1972280)WAG Injector on PWI as of 11/19/02. I wanted to update you on the status of our diagnostic plan per our last note dated 11/25/02. We have monitored IA pressure build up rates over the last week following a Passing MIT-IA to 3000 psi on 11/23/02. · 11/26/02 T/I/O = 1900 / 2150 / 300 - Bled IA to 450 psi and monitor for 1 hr with no change. Final pressures 1900 / 450 / 100 11/27/02 T/I/O = 2000 / 550 / 0 · 11/29/02 T/I/O = 2010 / 1500 / 120> 11/30/02 T/I/O = 2250 / 2250 / 200 - Bled IA from 2250 to 450 psi. Final pressures 2250 / 450 / 200> 12/01/02 T/I/O = 1900 / 2250 / 350Ne plan to conduct a second MIT-IA to 3000 psi. This procedure will have the well shut in and the tubing bled off to test the IA with at least 2000 psi differential over the tubing. Again, we will send you a note with the results and plan forward. Please let me know if you disagree or have questions with our plans outlined above. Preston EvansWell Integrity Engineer695-5102 Tom Maunder<tom maunder~,admin.state.ak.us> I Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2002 1 of 1 12/16/2002 1:34 PM Re: P-03A (PTD 1972280) slow T x IA comm while on MI Subject: Re: P-03A (PTD 1972280) slow T x IA comm while on MI Date: Mort, 18 Nov 2002 09:31:21 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "NSU, ADW Well Integrity Engineer" <NSUADWWelllntegrityEngineer@BP.com> CC: "- Jim Regg AOGCC (E-mail)" <Jim_Regg@admin.state.ak.us>, "- Winton Aubert (E-mail) ' 'AOGCC (E-mail)" <Winton_Aubert@admin.state.ak.us> John, Thanks for the notification. It is appropriate to have converted the well back to water. Your diagnostic plan is appropriate as well. In the interim, please put this well on the monitoring list. Keep us informed about the diagnostics. This behavior is not unusual. A standard MIT will show integrity, but when the well is converted to MI a slow leak shows up. The 700 psi build up in one day is a little quick. Good luck with the diagnostics. Tom Maunder, PE AOGCC "NSU, ADW Well Integrity Engineer" wrote: Hi Tom/Jim/Winton,ln mid October of this year we began a cycle of MI injection into P-03A. The well had been shut-in after a water injection cycle since earlier in 2002 (see attached injection and TIO plots). Since returning the well to injection the IA has slowly and steadily shown pressurization of up to 2250 psi on Saturday, November 16th. After the IA reached 2250 psi on 11/16 the pressure was bled to 1500 psi. However, on 11/17 the pressure had again increased to 2200 psi. As of Sunday, November 17, 2002 this well has been swapped back to water injection. Previously when this well was on MI it also experienced slow T x IA communication, but subsequent MITIA's passed.A brief history of events are outlined below~ 03/21/01: DSO REPORTS HIGH lAP (MI) > 03/25/01: MITIA PASSED to 2500 psi. > 05/18/01: MITOA Failed 3.6 gpm @ 1320 psi, PPPOT-TBG Failed, PPPOT- lC Passed > 07/02/01: DSO called lAP tracking injection pressure > 08/02/01: Bled lAP 2350 > 500 > 09/17/01: MITIA to 2500 psi Passed > 07/31/02: APE requested PO test for WAG injection > 08/01/02: PPPOT-T Passed to 5000 psi. > 11/16/02: DSO bled IA from 2250 to 1500 psi. > 11/17/02: DSO bled IA from 2200 to 1750 psi. Swap back to water injection. Our plan forward for this well is as follows:l. Leave on water injection.2. Repeat the MITIA to assure tubing integrity.3. Evaluate for continued water injection and evaluate options to stop the slow T x IA communication when on MI injection. Please let me know if you have any questions or if you would like us to take a different approach.Thanks, John Cubbon 659-5102 Mobil: 943-1154 Pager: 659-5100, xl 154 i Tom Maunder<tom maunder~admin.state.ak.us> .! Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of I 11/18/2002 9:31 AM rm~ M~:~~ tJ~~ rms cov~ ~s - BEEN ON OR BEFORE PL E M .A T E IA L U N W DER THIS M A~RKER. Well Report CC.~p. 01 /21 //1998 PRUDHOE BAY UNIT P-03A Completion Status: WAGIN Current Status 029-22176-01 197-228-0 BP EXPLORATION MD 1290 ~'/TVD 09154 Name Interval Sent Received BO 8271 r.~''/' 1,14-16 SPERRY OR 3/11/98 3/11/98 8273 /...R"~-8 SPERRY OR PB1 1/13/98 1/14/98 8274 ~i13 SPERRY GR PB2 3/11/98 3/11/98 8374 / 1 SCHLUM IES PB1 , 5/18/98 5/22/98 CMT MAP AL 10150-10560 ~ . '/~ 4/16/98 4/21/98 IEL/GR ~.!NAL 10165-12390 12/30/97 1/6/98 NGP-MD ~FINAL 10308-12904 . 3/18/98 3/18/98 · NGP-MD I~/'FINAL 10309-12510 PBI. 3/18/98 3/18/98 NGP-MD 'L FINAL 10308-10604 PB2 3/18/98 3/18/98 NGP-TVD ~" FINAL 8873-8959 3/18/98 3/18/98 NGP-TVD 14~' F1NAL 8873-8941 PB1 3/18/98 3/18/98 NGP-TVD ,L FINAL 8873-8972 PB2 3/18/98 3/18/98 SRVY CALC ~ BP 10287.7-12904. 3/9/98 3/9/98 SRVY CALC /~ BP 10287.7-12510. PB1,/~.LJq~. ~/1['3 ~, 3/9/98 3/9/98 Daily Well Ops )),/,~ 1777-- yo~ a~/]-j) Are Dry Ditch Samples Required, yes ~__~..And Receive~ Was the well cored? yes fi~. ..... Analysis Description Recei~no----- Sample Set # Comments: Monday, January 10, 2000 Page 1 of 1 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 111015 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Prudhoe Bay (Cased Hole) 4/21/98 Well Job # Log Description Date BL RF Sepia LIS Tape A-04 ~r. '~'~-~"~ ~ 98187 RST 980406 I I 1 F-11 " 98065 CNL 970808 1 I 1 K-05A 97522 PDK-100 971021 1 C- 16 TEMPERATURE LOG 980405 1 1 D- 25 PRODUCTION PROFILE 980322 1 1 G-03 A FLOWING PRESSURE SURVEY 980401 1 1 H 29 A CALIPER LOG 980331 I 1 M- 03 ~ t ¢..., INJECTION PROFILE 98041 2 I 1 P-03A txl c.... CEMENT MAP LOG 980318 I 1 R-32A I J. J ~ CEMENT MAP LOG 980317 I 1 S-21 PRODUCTION PROFILE 980329 I I __ S-21 DEFT 980329 I 1 --- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received b~~k-') ¢ · 5/18/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11177 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape c~-"~-~t-~ P-03A PB1 ~ '~...~t~ 98194 INDUCTIONELECTROLOG/GR 980102 1 -- ---- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center MB3~3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Date Delivered: Schlumberger GeoQuest 500 W. International Airport Road Anchorage, Alaska 99618-1199 Received by:~. ~XJ~~ STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM' ;SION WELL Cfb-~'PLETION OR RECOMPLETION REPOFffF~AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection ~¢~'~(~ 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 97-228 3. Address 8. APl Number P.O. Box196612, Anchorage, Alaska 99519-6612 50-029-22176-01 4. Location of well at surface ?'--~,,::;:.::..~ ....... , ~, 9. Unit or Lease Name 2594' NSL, 2020' EWL, SEC. 31, T11N, R13E / ~" '"'~":-'-?'!~.,- ? '¢ir~--,--; Prudhoe Bay Unit A ttopofproductiveinte~al¢ ~ZZ 2 ~~ j ~~' ~~ ~ 10. Well Number 2624' NSL, 4380' EWL, SEC. 32, T11 N, R13E " P-03Ai 3482' NSL, ~42' EWL, Sec.31 T11N, R13E ' ": ...... ~'.'¥~:':: .... ~ .... Prudhoe Bay Field/Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation an8 Serial No. Pool KBE= 91.54~ ADL 028288 12. Date Spudded12/25/97 I13' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'll 5' Water depth' if °ffsh°re I16' N°' °f c°mpleti°nsl/19/98 1/21/98 N* MSL O ne 17. Tptal Depth (MD+TVD) ~18. Plug Back Depth (MD+TVD)119. Directional Su~eyl 20. Depth where SSSV set~l. Thickness of PermafrOSt ~,~ FTI 10589 9217... FT1 ~¢S ~No I 2048 MD/ 1900'(Approx.) Type Electri~ ~ ~ther Logs Run BHCS/GR, GR/SP Induction 23. CASING, LINER AND CEMENTING RECORD CASING S~ING DEPTH HOLE SIZE WT. PER FT. GRADE ToP, BOSOM SIZE CEMENTING RECORD AMD~T ~UL~ 2 7/8" 6.16~ L-80 9998 ~ 12904 3 3/4" 134 c.f. cement 24. Pedorations open to Production (MD+TVD of Top and BoSom 25. TUBING RECORD and interval, size and number) SIZE ~ DEPTH S~ (MD) PACKER S~ (MD) MD TVD 12786-12742 8944-8944 12654-12610 8943-8945 26. AC~D, F~CTURE, CEMENT SQUEEZE, ~C. 11890-11935 8943-8945 DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11956-12000 8945-8949 12197-12240 8951-8951 12333-12376 8951-8950 27. PRODUCTION TEST D IGI kl A I Date First Production [Method of Operation (Flowing, gas lift, etc.) ~ t ~ I ~ I t ~ I 2/15/98 I !Date of Test 4ours Tested PRODUCTION OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO I FOR TEST Flow Tubing Casing Pressure DALCU~TED OIL-BBL GAS-McF WATER-BBL O~b CRAWl-APl (CORR) ;Press. ~4-HouR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 30. 29. Geologic Mark.= _.- ....... Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. TSAD 10375 8930 TSHU 10244 8838 TSGR 10217 8816 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 ?/i--,¢_~ (Z~:_~D---- ~' Title CID Technical Assistant Date Prepared By Name/Number: Theresa Mills 564-5894 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage 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 I~ ~Ji ~=~ ! KB. ELEV = 91.54' TREE: 4 1/16" - 5M CIW WELLHEAD:11"- 5M FMC _r'U~'~_ BF. ELEV=56.05' ACTUATOR: OTIS SSSV LANDING NIPPLE3. I 2048' I O (OTIS "HXO")(3.81 ID) CMT'd-- II I 10 3/4", I 2703, ~ . a i~ i GAS LIFT MANDRELS 45.5#/~,I I ! CAMCO KBMG ( W/I"BE LATCH] NT-80 BTRS N-° MDfBKB~ -R/DSS 5 2985' 2893' I KOP: 3500' I 4 5721' 5421' MAX ANGLE: 45° @ 6215' 3 8073' 7155' 1 9905' 8565' i 4 1/2", 12.6#/ft, 13CR, TDS CHROME TUBING TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT (PARKER) (3.813" ID) ,CHROME TBG & / Right-hand release I 9932' latch ,5 1/2" LINER 1'~;~r--75/8" TIWPAOKER (HB-BP) (4.00" ID) I 9933' I 41/2", 12.6#/ft, 13Cr II I ~ ~. TAILPIPE ~ ~(PARKER) (3.813" ID) I 9955' I /! I 1% 41/2 .... SWN"NPPLE , TOP OF TIW I 9983' ~ ~- I~ \. : (PARKER) (3.80" ID) I 9975 7 5/8", 29.7#/ft, , , .J"'~ -'~, 4F-'~DCVLEGI9987' NT-95HS, 110,252' J ~al t.." (MOD. BAKER) I NSCC / i MARKER JOINT I NONE I I 2 7/8" 6.16#/ft L-80 ST-L Liner ~ I I J Top at 10 254' I ~ I Baker Deployment Sleeve I Capa;~55 BbVft. I w/3" GS Profile ..~,,I, ~ Set at 10254' ELMD Window 10292' to 10299' ---- ~\ ~ SIDETRACK PERFORATION SUMMARY ~ ~ ~,. Latch Collar at 12838' MD, SIZE SPF INTERVAL O ~EN/SQZ'D "-' ..... '- 1.69 4 '1890-11935 OPEra"' ~',I Driller TD at 12904' EkVD. 1.69 4 ;1956-12000 I OPEN I 2 7/8" 6.16#/ftL-80 STL Liner set at 1.69 4 2198-12240 ~ OPEN I 12904' ELMD. Max angle 101 at 1.69 4 2333-12376 OPEN I __ 10634' MD, MDLS 30 deg/100ft at 1.69 4 2610-12650 OPENI~ [--=10800' MD 1.69 4 2743-12786 OPEN : ~ I -; !:~CTD HORIZONTAL SIDETRACK 5 1/2", 17#/ft, 13Cr,'1 1 -- "-'-- 'U,O/~'I :L4S DATE REV. BY COMMENTS PRUDHOE BAY UNIT 6-09-91 H F INITIAL COMPLETION WELL: P-03ai (12-32-11-13) 7-15-91 EPT INITIAL PERFORATIONS 10-8-91 A. TELL PRE FRAC/PERFS APl NO: 50-029-22176-01 10-7-92 Eckstein Add Perfs SEC 31: T11 N: RG13E 1-22-98 .ildreth CTD Horizontal Sidetrack BP EXPLORATION Well: P-03Ai Field Prudhoe Bay APl 50-029-22176-01 Permit 97-228 Accept Spud Release CTD Unit 12/25/97 12/26/97 1/21/98 Nordic ¢1 Date Day 12/25/97 1 Accept rig at 04:00. NU BOP Depth 12/26/97 2 Pressure Test BOPE. RIH with Baker window milling BHA ¢1. Mill SWN nipple to 3.80". RIH and mill window from 10293 - 10298.4 ft. Very difficult getting mill to start milling, Many stalls. POOH. M/U Baker formation mill and string reamer. Laid out 1 it. Of tubing to change fatigue depth on CT. Tag SWN nipple and mill SWN with 3.80" string reamer. 12/27/98 3 10548 , _,. Tag SWN nipple and mill SWN with 3.80" string reamer. Mill window from 10293 - 10299 ft. Drill formation to 10308 ft. Ream window area clean. POOH. P/U Sperry MWD and Drilex 2.6 Deg. Bent motor. RIH with BHA ¢3. Test Sperry tools, OK. RIH. Turn well / pits over to used Flopro [415 BBLS]. Orient TF to 25 L. Drill build section from 10308 - 10548 ft. Orient TF to 45 L, for left hand turn 12/28/97 4 11,200 Orient TF to 70L. Drill horizontal hole from 10548 - 10787. Short trip to window. RIH drill 10787 - 10902 ft. Sperry MWD failed. POOH for new MWD tools. RIH with BHA #.4. Tie-in below window with BHCS/GR. Add 1 ft to CTD. RIH and drill from 10902 - 11200 ft. POOH to change motor 12/29/97 5 11,448 POOH. Change out motor and bit. RIH with BHA ¢5 [0.6 Deg motor]. Tie-in with GR. RIH and drill from 11200 - 11424 ft. Unable to build deviation as needed. POOH for motor. RIH with 1.0 Deg motor and Bit ¢IRR. Tie-in with GR. RIH and drill horizontal hole from 11424 - 11448 ft. Very slow progress. Unable to stall motor or get motor work. POOH. Bit was balled with clay. Change out MWD, motor and Bit. RIH with 1.0 Deg motor and HYC DS49 bit. 12/31/97 7 12,187 Change out motor and MWD at surface. RIH with BHA ¢8, [ 1.75 Deg motor and Bit ¢2RR ]. Tie-in with GR. Drill ahead as per revised Well Plan (building angle) from 11952-12082'. MWD stuck in GR loop. POOH for MWD. Change out MWD. RIH with BHA ¢9. Tie-in, add 1.0'. RIH to 11436' and set down. Spent 2 hours to ream 11420-50' clean. RIH. Tag bottom at corrected depth of 12086'. Drill to 12152' and stop to get survey. Stuck CT while PUH at 12140'. Displace wellbore to new FIo Pro and came free. Drill from 12152-12187'. 1/1/98 8 12,500 Drill horizontal hole from 12,187 - 12,310 ft. Short trip to window. Tie-in with BHCS/GR at window. RIH and drill horizontal hole from 12,310- 12,360 ft. Attempt to orient TF with no luck. Try all methods, not able to orient. Last valid directional survey at 12,336 ft. Drill ahead with TF and GR information only from 12,360 - 12,410 ft. Slow drilling started at 12,400 ft. Struggle to TD at 12500' while drilling rathole for float equipment. No valid survey last 150', GR questionable last 100'. Backream to window. Had tite spots at 11570', 11510' and 11430'. Attempt to tie-in at window and GR was shot too. POOH for MWD (NE at 0210 hfs 1/1/98). Change out MWD, motor and bit. RIH with BHA ¢10. 1/2/98 9 12,510 Continue RIH with BHA #10 to cleanout for logs. Tie-in with BHCS/GR, add 1 ft to CTD. (OE at 0730 hrs 1/1/98). RIH, Ream to TD of 12,510 ft BKB. Circulate up 4 directional surveys. Re-log MWD GR from 12,300 -12,500 ft. Good sand indicated. Made a wiper trip to window. Ream tight clays at 11,420 and 11,520 ft. RIH to TD. Circulate in new FIoPro and leave in open hole while POOH. LD BHA. Vac pits. FP CT with 2 bbls MeOH. ND BOPE and secure. Move DS/N #1 off well. Rig on Standby Rate at 2300 hrs 1/1/98. Set wellhouse with 45T crane. MIRU DS CTE #~. NU BOP's. Set Chuck Shack. MIRU Atlas. Rehead and test- found one open lead-fix. Prep to MU tool string. 1/3/98 10 12,510 MU logging tools (temp -40). RIH with Atlas GR/SP/Induction Electrolog on 1-3/4" CTE w/o pumping (MeOH in CT). Had wt loss at window, but RIH clean to 12397' where set down occurred. Log up hole at 50 FPM thru window (clean) and perform 200' repeat at window. POOH with logging tools while filling hole from backside with FIo Pro. At surface displace CT with additional MeOH to FP top 30' of wellbore. SI swab. LD logging tools. RDMO Atlas. Secure CTU. WOW (-42 deg F w/23 MPH wind, -102 CF) to RD CTU from 1800 hrs 1/2/98 '1/4/98 '11 '12,5'10 WOW to RD CTE Unit (-15 F, 25-35 MPH, -70-90 CF). Phz 1 Spine Rd, Phz 2 Pads and access rds. /5/98 WOW to RD CTE Unit (-15 F, 25-35 MPH, -70-90 CF). Phz 1 Spine Rd, Phz 2 Pads and access rds. '1/6/98 '12 '12,5'10 WOW to RD CTE Unit (-15 F, 23-27 MPH, -65-75 CF). Pick Blue shack off wellhouse. R/D CTU. Remove wellhouse with 45T crane. Move Nordic #1 over well. Nordic Rig off Stand- by at '13:30 Hrs. N/U BOPE. Pressure test BOPE (weekly test). M/U BHA (1° motor). RIH with BHA #11. Tie-in at window, add 1.0'. RIH and set down at 10390'. Drill and spud on 2.375" x 18" rubber hole finder and push to 10402'. Have recovered 1/3 of hole finder over shaker. '1/7/98 '13 '12,5'10 Drill and spud on Fish at 10402 ft. No progress. POOH. Cut off 104 ft of CT. Re-head. M/U 1.0 Deg motor with 3.75" O.D. Concave mill with 6" long full gauge body and lB Stabilizer lff behind mill. RIH with BHA#12. Mill on fish at 10402 ft. Mill to 10406 ft. Clean pick up but unable to RIH. POOH for bigger bend motor. Face of mill had milled metal. Change out motodmill. RIH with BHA #13 (1.75° motor/DS49 bit). RIH clean to 10410' and stalled. Drill and spud to 10411'-acted like drilling formation. POOH for bigger bend motor. Change out motor. RIH with BHA #14 (2.8° motor/DS49 bit). RIH clean to 10414' and set down. PU clean at 38K and RIH to 10404' and set down. PUH and spud thru and ream to 10450'-clean to here (got a chance now of not sidetracking). Backream thru bad spot. Spud in hole and set down at 10416'. Orient to various HS TF's with try with same result. '1/8/98 '15 '10,446 Trying to work past fish at 10415 ft. Spud past with pump on. Ream in hole to 10470 ft. Backream, overpull at 10399 ft. RIH to 10500 ft. Backream with overpull at 10398 ft. Ream in hole to 10410 ft, sat down. Ream down and clean hole to 10415 ft. Solid bottom. Spud 3 times with no luck. Drill on rubber at 10415 ft. Ream in hole to 10446 ft. Backream to 10320 ft. Clean hole. Ream down to 10600 ft, still in original hole OK. Backream, ream in hole and sat down at 10446 ft. Backream and ream in hole to 10896 ft, still in original hole, OK. Backream to window. Orient TF to 20L. Ream in hole and sat down at 10446 1~. RIH at several different toolfaces, unable to re-enter old hole, sat down at 10446 ft each time. Apparently sidetracked the old hole or drilled a ledge, starting at the fish at 10415 ft. Present TD or ledge at 10446 ft. PINHOLE LEAK IN CTAT 10300 FT. Pinhole caused by several reaming trips, trying to save old hole. POOH to change CT. L/O Drilling BHA. Purge CT with N2. Pull CT onto reel and secure it. Pick reel and LD. Weld worn bushing to reel flange/pin. Pick new reel and lower into reel house. 1/9/96 16 10597 Stab CT into injector head. Pump 1.25" ball thru CT. M/U CTC, pull test and press test. M/U MWD building BHA #15. RIH. Orient TF above window. Tie-in with BHCS/GR, add 2 ft. Ream open hole at varying speeds and TF to find original hole. No luck. Pump up survey from TD. Drill with building assembly at 16L from 10458 - 10505 ft. to enter old hole. Unable to enter old hole. Attempt to drill ahead to determine turn rate of this BHA, but can't get desired left TF. Drilled to 10597' at a TF bet/5L and 40L to verify separation from old wellbore. Built to 100 deg. Unable to get desired turn. Prepare to tie-in with RA and POOH for cement plugback 1/10/98 17 10599 Tie-in to BHCS/GR; add 6.5'. Flag pipe. POOH. L/D drilling BHA. M/U Cementing Stinger. RIH. Tie-in at Flag. RIH and tag TD at 10599 ft. P,/U DS Cementing Van. Generator on van failed. Repair frozen fuel pump. Held safety meeting. Deck engines failed on pump van. Water in fuel tank of van. Change out DS pump. Pressure test lines. Pump 5 BBL fresh water Spacer. Pump 10 BBLS, 17PPG, G, Slurry. Purge lines. Insert TIW dart. Pump 5 BBL fresh water behind and displace cement with FIoPro. Lay in cement from TD to WCTOC at 10040'. Shear dart at 2100 psi. CIP at 19:40. RIH jetting cement to 10304' (5' below window). POOH circulating. LD BHA. WOC. 1/11/98 18 10540 WOC. MU BHA #16 w/3.0 deg motor and M-09 bit. RIH. Correct to flag (-7'). Drill soft cement to 10321' (est TOC at 10305'). WOC (lab sample at 5100 psi). Drill soft to 10354'. WOC. Drill 50 FPH to 10395'. Orient to high side. Drill to 10,455' at 80 FPH. Survey at 10,381' indicates old hole. Survey at 10,403' indicates we're sidetracked. PUH and tie-in (add 3'). Drill to 10540'. Not getting desired build. Projected inclination at bit is 88 deg; 23' below the line 1/12/98 19 11,167 Drilled 10540' - 10700'. Short trip to window. Displaced well with new FIo-pro. Drilled to 10860'. Short trip to window. Drilled to 11055'. Shod trip to window. Tie-in (add 22'). Drilling ahead at 11167' MD, 8945' TVD, 90 deg 1/13/98 20 11,685 Drill Horizontal left turn from 11167 - 11204 ft with 3.0 Deg motor. Short trip to window. RIH, clean hole. Drill from 11204 - 11275 ft. POOH for 1.0 Deg motor. Ream tight hole from 11110 - 11270 ft. POOH. RIH with 1.0 Deg bend motor. Tie-in with BHCS/GR. Ream in hole, Clean hole. Orient TF. Drill horizontal hole from 11275 - 11434. Short trip to window. Drill horizontal to 11530'. Pump pressure fell off, losing returns (50%). PUH to window. Losses at 25%. Tie- in (add 14'). Ream in hole. Drill horizontal to 11685'. Losses at 15%. 1/14/98 21 12,174 Drill horizontal hole from 11685 - 11695 ft. Shod trip to window. Drill from 11695 - 11855 ft. Short trip to window. Tie-in with BHCS/GR, add 12 ftto CTD. RIH. Drill from 11855 - 12030 ft. Short trip to window. MWD failed. POOH, change out Sperry MWD. TIH. GR log for correlation. Orient toolface. Drill to 12174'. Shod trip to clean hole. 1/15/98 22 12,763 Finished wiper trip. Drilling. Short trip to window at 12209' Tie-In, corrected +17.5'. TIH. Tagged bottom, drilling. Having to pump up survey every 30' String weight while drilling at 500# to 3000#. Drilling, Orient TF and drilling. Wiper trip to window at 12400' Clean. Drilling, Survey, Drilling Orient at 12450' to make RH turn to target. Drill ahead with short trips to clean. GR log for correlation on short trips to window. Drill to 12763'. 1/16/98 23 12,904 Finished Wiper trip. 'Orient TF and back to drilling. At 12809' orient Tfto Iow left to dop TVDss to 8955 interval. Drilling, Worked air out of mud system. Drilling. TD well at 12890' (uncorrected). Survey, Wipe trip. Tie in at window. (+17'). Flagged pipe at 10323' EOP at 10261' Mechanical @ 10249'. TIH and confirm TD. Tagged at 12896' Drilled to 12904' TD. TD well. POOH to run liner. Repainted flag at 10323'. White Flag at 7500' EOP. OOH and RD BHA. Hold Safety Meeting. PU 2 7/8" liner and running equipment. Make up Baker CTLRT and BHA. Install CT Connector. Pull test to 35,000#, pressure test to 3500 psi. Displace MeOH from CT. TIH w/liner. 1/17/98 24 12,838 TIH with Liner. TIH went good till 12633' and excessive drag. PU SW at 43,500#' Work liner to bottom. DS software shutting down injector head. Re-boot computer. Work liner to bottom. By-passed override button. Work liner to bottom. Tagged bottom at 0900 hrs at 12904'. Cir. and condition mud while waiting on vac trucks from Peak. Displaced FIo-Pro with 2% KCL. Dropped 5/8" Delron Ball and displace the CTLRT. (Liner Stuck on Bottom at 12904'). Displaced with 50 bbl KCL and released at 2100 psi, PU and set 1 Ok on liner. Circulate and held safety meeting. Displace hole w/2% KCI water. Pump 26 Bbl. Cement. Drop dart and displace w/2% KCI. Dart on seat at calculated displacement, sheared at 3100 psi. Pump liner wiper plug, on seat at calculated displacement. Pressure to 2500 psi. Check floats, held OK. Pressure to 500 psi and pull out of liner top. Circulate and clean up liner top. Circulate bottoms up. Cement returns to surface. POOH. PU nozzle and 1 ¼" CS Hydril clean out string. TIH, tag up at 12760'. Wash in hole. Washing very hard. Appears to be cement on bottom side of hole. 1/18/98 25 12,838 Unabke to Jet cement out below 12776' Checked depth and confirmed 12776' with drilling flags. Layed in 25 bb1150k new FIo-pro. POOH. PT Liner with nozzle at 3651' at 2500 psi lost 345 psi in 1 min. Released pressure. POOH. Stood all Hydril in derrick. Re-tested liner lap and lost 325psi in 2 min. using 2500 psi test pressure. TIH to squeeze liner. Pump 5 Bbl. Cement. Close choke and bullhead 1.5 bbl. Cement away at 3200 psi. Open choke and begin to ramp up pressure. Circulate with 1:1 returns while holding 3000 psi backpressure. Stop pumps and close choke. Holding 3050 psi-Solid. Wash in hole contaminating cement. Hold 500-1000 psi backpressure while washing. POOH, WOC 1/19/98 26 12,838 Finished LD milling BHA. Hold Safety meeting. PU/MU Gun run #1, run 40 stds CSH. TIH. Tagged at 1058'. PUH took 10 to 12kto pull free. Tried working guns in hole. Unable. POOH, Stand CSH in Derrick, Hold Safety Meeting and LD Perf guns. PU Clean out BHA ,TIH. Clean out to Latch Collar at 12838'. Start POOH. Repair Tension Cylinder on Injector Head. Finish POOH. 1/20/98 27 Finished LD milling BHA. Hold Safety meeting. PU/MU Gun run #1, run 40 stds CSH. TIH. Tagged at 1058'. PUH took 10 to 12k to pull free. Tried working guns in hole. Unable. POOH, Stand CSH in Derrick, Hold Safety Meeting and LD Perf guns. PU Clean out BHA ,TIH. Clean out to Latch Collar at 12838'. Start POOH. Repair Tension Cylinder on Injector Head. Finish POOH. 1121198 28 Laying down CSH. LD BHA. Hold Safety meeting. PT Tools to 4000 psi. PU Gun Run #1. TIH, tag up, correct depth (+2'). Position bottom shot at 12786'. Perforate interval 12786'- 127'42' and 12654'-12610'. POOH. LD guns. (Fired) PU Gun Run #2, CSH tubing. TIH. Placed bull plug at 12377' Perforated 11890' to 11935'; 11956' to 12000'; 12197.8' to 12240'; 12333' to 1237'6' POOH. Stand CSH in derrick. LD Gun Run #2. RU to displace FIo-Pro out of wellbore 1/22/98 29 RU nozzle to displace wellbore with Sea water. TIH, displace hole w/seawater. Freeze protect top 2000' of well w/MeOH. Purge CT w/N2. Clean pits, ND BOP. Release Rig - 18:00 hr. 1/21/98 SURVEY CALCULATIONS Coordinates provided 'in: TRUE and GRID relative to Wellhead and ALASKA STATE PLANE Company: 'BP' EXPLO.RAT][O'N ALASKA Rig: D/S CT UnR #7 AFE No: 4P1075 W~n,~ .P4)~A Field: Prudhoe gay WOA BHI Rep: Howar{~ Wagon:er C~ ~lation Method: M[n:[nmm Curvature Mag..Declination.: 28.14t} Job Sta~ Date: 27-Dec-98 ve~icai Sect. Plane: 323.639 TRUE 322..64 GRID Grid Correction: 0..999 Job ~End Date: Su~ Measured. From: MD from RK'B, Total Correction: 27. ~4~. DLS per ( ft / m ) TVI) from Sea i[evel. (9 LS') , , I ,~1 , , , , , -~1 . , I , I ~DI , ,, i ' ASP Survey Meas. Course Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRID Coo.rds. - GR Coords. - No. Depth Length Angle Azi. TVD Section N(+)/S(-) N(+)/S(-) A.zi. N(+)/S(~) N(+)/s(-) N(+)/S(-) N(+)/s(-) (ft) (deg) i, (deg) (ft) TRUE °/100R. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) Tie-in 10287.7 0.0 35.13 117.75 8873.66 -2100.85 '0.00 '145.15 3740.67 116.75 '~10.35 ~37.58 '594753'~.'7 635039.6 2 10290.0 2.3 35.07 117.70 8875.54 -2102.03 2.89 144.5'3 3741'.84 1i6.70 209.76 3738.76 '5947532.1 6~5040.7 3 10300.6 10.6 37.00 116.00 8884.12 -2107.60 20.51 141.72 3747.40 li5.00 207.04 3744.37 '5947529.4 635046.4 4 10320.7 20.1 39.30 113.00 8899.92 -2118.44 14.69' '136.58 3758.70 112100 202.'10 3755.76 5947524.4 ' 635057.7 5 10353.2 32.5 46.32 108.00 8923.76 -2136.87 23.98 128.92. 3779'.39 107.00 194.79 3776.57 594751'7.1 635078.6 6 10381.2 28.0 52.62 105.61 8941.95 -2153.88' 23.41 122.79 3799.75 104161 189.02 3797.04 5947511.4 635099.0 7 10399.0 17.8 57.48 103.15 8952.14 -2165.17 29.56 119.17 3813.88 102.15 185.65 3811.23 5947508.'0 635113.2 8 10417.3 18.3 60.29 107.00 8961.60 -2177.42 23.66 115.09 3829.00 106.00 181.84. 3826.42 5947504.2 635128.4 - '> 10435.8 18.5' 66.40 106.10 8969.89 -2190.60 33.31 110.39 3844.84 105.10 177.41 3842.34 5947499.8 635144.3 10 10469.1 33.3 78.90 108.20 8979.81 -2216.11 38.01 101.02 3875.15 107.20 168.57 3872.81 5947490.9 635174.8 11 10497.6 28.5 86.20 103.30 8983.50 -2238.39 30.76 93.36 3902.32 102.30 161.39 3900.11 5947483.7 635202.1 12 10531.3 33.7 91.92 102.10 8984.05 -2263.83 17.34 85.96 3935.18 101.10 154.56 3933.09 5947476.9 635235.1. 13 10571.9 40.6 100.90 96.20 8979.52 -2292.58 26.41 79.53 3974.95 95.20 148.83 3972.97 5947471.2 635275.0 14 10604.0 32.1 108.47 93.33 8971.39 -2313.00 25.12 76.94 4005.87 92.33 146.78 4003.92 5947469.1 635305.9 Proposal Calculations Coordinates provided in: GRID relative to Wellhead and ALASKA ~ q[ A .rE, PLAN Company: BP ExpiCn'a.tion Rig: Dowelt/N~rdic #1 Well: P-03A Field: Prudh,.oe Bay Calculation Method: Mh~;~mnm Cnrvamre Mag. Declination: 28.140 Vertical Sect. Plane: 323~63~1 TRUE Grid Correction: 0,.999 Vertical Sect. Plane: 322.640 G.R[D Total Correction: 27.141. Measured Depth from: RKB R~ Height: 0,0 True Ve~ical. Depth: Sea level Job N°: AFE N'o: BHI Rep: Job Start Date: JOb End Date: DLS per (ft/m): 'i'h&'"' GRID subsea ......... C~;0rds. -"'GRID ' .(':~,n-.,~l,~'./' AS tii~'' ''' Dogleg 1ooi Face Vertical Build Turn' Angle Azi. TVD N(+)~S(-) E(+)/W(-) ~' ~)~.'~'~)'~,} ~ ~.) IE~{~)/W'{.,.) Section (deg) (deg) fit) Lat. (Y) Dep. (X) L:,~'. ('/~: De~.'),~ {X) ~e~100tt) from 0,0 ~eg/100ft) (Deg/100R) .... 35.13 1;~16.~ 8873~'~0 2'i'0.'4b 3737.60' "~',~47:~:~'~.~'~/.? ~:,~?,:~'~>y~y.~'~;.o¢~ .....0~00 ' 0.00 -21~0.82 0.000 0.00 ......... 35.05' i16170" '8875.58 '209.81 37,~8.78' ' . ........... (>,~.:>~d~.~./~, I 2.89 0.00 -2102.01 -2.609 -2.17 37.00 115.()0 ~8'84.1~ 207.09 : 744.~9 ~,::~,~" ~'"~, ~,,~: _,: ~., ®,,, %5~>46.393 20.51 0.00 -2107.57 18.208 -16.04 39'.30' ' i~2.00' ' 8895'.96 2i')2.15 3755'.78 5q>.~7524.447' '}:>%~'>~' 77~) 14.69 0.00 -2118.41 11.443 -14.93 ......... 46.321()7.00 8~3.79 194.84 3~76.59 5<>.475 ~ 7_ ~.4:~ ,:~'~(>7~ 5c);: 23.98 0.00 -2136.85 21.600 -15.38 52.62 104.6'1 8941.98 189.07 3797.06 '?.>.:g% ~ ~. :~'7 [~'.,/:[~ ~.>~;') o¥'~; 23.41 0.00 -2153.86 22.500 -8.54 57.48 ' i02'.15 8952.18 '185.71 3811.25 q~>..:~.75¢>s.() ~'3~;.:~.x~';.'25':~ 29.56 0.00 -2165.14 27.303 -13.82 ,, ,, , , ,, .... 69.70 104.96 8972.16 176.23 385(.).34 ~9:~74%~.52~ ~:,';q g 52.:42 27.72 0.00. -2196.40 27.156 6.24 76.64 107.25 8980.26 168.79 3876.()7 'n".~'~.~dt.<>:*g5.'('?,5~.~"~'~?;'.7() 25.99 0.00 -2217.92 24.786 8.1~ 83.76 107.95 8985.23 160.09 39(')3.48 5 :~:~.Td.? 2,: t~'26'?~ ~ 2 .~:.z~ 7t 24.50 0.00 -2241.47 24.384 2.40 , 91.58 11(.).23 8986.43 150.43 3931.4() ~:<~ ~4":'~ ~'>,q ~"5523'.;.~:~;'q 27.52 0.00 -2266.09 26.419 7.70 95.62 108.48 8985.05 143.15 3952.11 5':~}.47. k;5..,tS~;~ (':55'25.'~,. I t.~ 20.01 0.00 -2284.44 18.364 -7.95 97.03 104.26 8982.02 135.45 3978.33 <~' ~'z :~ '~ ..... ~'-" ..... :';~ -2306.48 5.127 -15.35 .... ,.~, ,..,., ...... ~,~ .~,,~=.,,. .... : 16.09 0.00 97.38 96.35 8978.41 13(.).36 40()6.32 ....... s~.~4';'4 ~ * ' qX ,, ' ', q~,." ,,"<, .... . ,- ~ :,' 27.37 0.00 -2327.51 1.220 -27.56 / ~ ~ ~ ....... 97.03 87.91 8974.39 129.18 40,~8.02 :%.47d5 ~ .-.~ ~(,'. ~:'~'i ~.~: ~" i~ 26.19 0.00 -2347.68 -1.094 -26.38 95.17 79.86 8971.33 132.23 4066.47 5"¢-'~ 7~5,~ .5.~ ~ ('553 5~;..-~? 28.53 0.00 -2362.52 -6.458 -27.95 94.66 72.97 8968.68 139.46 4(.)96.37 5~.,,-; 7d4-; [ .'75) .~:-;?,.53 ? S.i¢75 22.28 0.00 -2374.92 -1.650 -22.30 95.98 63.12 8965.63: 151.65 4126.63 5~'~47,.~ ?'?~.;.~5*.~,.?.%2~,.:'~,2(, 30.17 0.00 -2383.59 4.024 -30.03 95.98 55.57 8962.49 166.90 4152.36 5'-.~d 74.~;:.:.20 ?. ,:',554 }-[. ;~4~ 24.95 0.00 -2387.08 0.000 -25.08 95.10 46.(')7 8959.79 184.43 4173.86 5~:.-q75 .'>.'72~ ,:'?,5,475 :,:<~ 34.04 0.00 -2386.20 ~3~!54 -34.65 ...:,-, .....--: ,.,..... 4 92.98: 31.25 8956.15 ~' '- =_4._~> 4205.79 29.05 0.00 -2373.84 -28.83 88.77 16.37 8955.29 275.52 4228.36 5'-~ ~.77t. 7.~¢2;~'~t">5555t,:.3,5 ~ 27.56 0.00 -2346.87 -7.504 -26.52 87.89 8.99 8956.16 304.66 4234.92 5947(;2".,.:~':;:~ ~;',5553(,.<,:' !V 24.85 0.00 -2327.68 "'-2.943 -24.68 90.70 3.18, 8956.54 335.66 4238.22 5').-~. 7(~57.'.;'55~:.; 55-:i-: .~.22:~- 20.68 0.00 -2305.05 9.006 -18.62 94.31 351.05 8954.85 374.10 4236.29 _,~': ....~ ~r,, ,,,..... '~," ~',... c,, .~ -~ 5; ~..r' ,:> ': 32.75 0.00 -2273.32 9.352 901.22 95.36 341.74 8952.34 402.83 4229.34 5':>~ ~.7'725. ill! (':5 q5'3 t .Sd ~ 31.43 0.00 -2246.27 3.535 -31.35 93.87 332.6(I 8949.68 433.l I 4216.59 5~.~.~ 7755..'~ i3 6755 i ~.5~( 27.97 0.00 -2214.46 -4.515 -27.70 91.93 325.57 8948.38 455.12 4203.41 59.17777.d !~{ ,:;755{:.5.:i I ~ 28.34 0.00 -2188.97 -7.549 -27.35 92.46 311.33 8946.47 492.04 41.70.69 .5::).17~j f ,'.I.3:.1.0 .';:.~,.?172 (".~ 28.77 0.00 -2139.77 1.071 -28.77 Meas. Depth 10287.70 1.0290.00 10300.60 10320.70 10353.20 10381.20 10399.00 10444.00 10472.00 10501.20 10530.80 10552.80 10580.30 10609.00 10641.00 10669.80 10700.70 10733.50 10763.60 10791.50 10842.90 10899.00 10928.90 1096O. 10 10998.70 11028.40 11061.40 11087.10 11136.60 Meas. Incl. GRID Subsea Coords. - GRID ~.,.(.,,,,~.r ......... ~ - AS~~Dogleg Tool Face Vertical Build Turn Depth Angle Azi. TVD N(~-)/S(-) E(+)/W(-) 'N (+~/S(-'~ t:~!4+)/'¥¥(.~) Section (deg) (deg) (ft) Lat. (Y) Dep. (X) L:~'~'~, (¥)~ .Dep~ (X~) (Deg/100t~) from 0,0 ~eg/100ft) (Dcg/100ft) 11158.10 93.52 305.53 8945.35 505.38 4153.~8 5 %~%27.~5~0 ~35,455.~%~ 27.39 0.00 -2118.96 4.930~ -26.98 11182.50 93.34 298.32 8943.89 518.25 4133.22 59.4'7~.¢.1~.~.'~. 55 J (:~.35:.:~.35.2 [9 29.51 0.00 -2096.20 -0.738 -29.55 11216.00 93.08 296.91 8942.01 533.75 4103.58 5('.)4'7~,~56.6~:5; 5 ('33:%405.5~¢2 4.27 0.00 -2065.89 -0.776 -4.21 11250.50 90.09 296.85 8941.06 549.35 4072.82 59,.::[ 7~¢'~z ~ ..c'3,':~ 5 (':~55.3%.?:;25 8.67 0.00 -2034.84 -8.667 -0.17 11285.70 87.10 298.85 8941.92 565.78 4041.72 5t)47f~;g'& (?~.~ ~~';35~,~43.'7 ~ (; 10.22 0.00 -2002.89 -8.494 5.68 ,,, ,,, 11308.60 85.87 300.25 8943.33 577.05 4021.83 59.'-~.7 ~.;9'.), ~35 ?~ (:.,3532~"~.f'33.3 8.13 0.00 -1981.87 -5.371 6.11 11349.40 83.94 304.12 8946.95 598.69 3987.45 59¥7'92(.~.993 (~.~ 35'2 g 9 .,,:~.,:'4,,'~ 10.57 0.00 -1943.80 -4.730 9.49 11376.10 84.20 306.76 8949.71 614.09 3965.81 .%.~!"7~ ~3.,;~ ~:;'(;~ (:,35¢2(';7.~;'[ '~: 9.88 0.00 -1918.44 0.974 9.'89 .>.~...~,, ..,~..~..4, ~. ~,.:,:~z~4t~.~. b.~. 21.72 0.00 -1891.01 -2.191 11404.40 83.58 312.91 8952.72 632.11 3944.21 '~'"' ''':''~: ~ ':..... ' ....... ' '~ '~ 2 i.73 1'1440.50 83.58 308.52 8956.76 655.50 391.7.03 5%7'~)?'"7 ;7~')~ ¢35:2 ~9.(~.3(.) 12.08 0.00 -1855.92 0.000 -12.16 11475.60 87.01 309.57 8959.64 677.53 3889.87 59.':~ 79~:)q:;.~:~4 4%5 [~ 9 ~: ..~;(i,('3 10.22 0.00 -1821.92 9.772 2.99 , '11510.'10 89.91 310.05 8960.57. 699.61 3863.38 5;~;),::[~ 21.9I'2' ~'>~:~5~(?,~;.?,77 8.52 0.00 -1788.30 8.406 1.39 11544.50 88.95 307.46 8960.91 721..14 3836.55 5 %~(3z~3 ...,.[.4.?, ~:;35 [3~.555 8.03 0.00 -1754.91 -2.791 -7.53 11572.70 89.03 304.65 8961.41 737.74 3813.76 ::~ 9~:~[0(~.(~.(.?:~(:~ (;35 ~[ 5.'7(~,2 9.97 0.00 -1727.89 0.284 -9.96 11601.70 89.50 303.37 8961.78 753.96 3789.73 59~:~(~'76.255 (.;35(~9 t .725 4.70 0.00 -1700.41 1.621 -4.41 11638.60 90.62 302.36 8961.74 773.98 3758.73 :~.:~z~.8[)%.279 (~35(.~(3(;,. 73:2 4.09 0.00 -1665.69 3.035 -2.74 g~ ,, .~., ,. 11668.30 92.75 301.68 8960.87 789.72 3733.56 .?:).4'~'~ :~* ~)[~t; (;3'5[.~35.5 ..~5'3 7.53 0.00 -1637.91 7.172 -2.29 11698.30 88.50 301.90 8960.54 805.52 37()8.(')7 5~).4~ ~ 27.~?~ ~. i~ ~'~:3%. ~ ().(.~'71 14.19 0.00 -1609.88 -14.167 0.73 11724.10 86.84 30'1.70 8961.59 819.10 3686.1.6 59~ ~8'141.4(~2 ~5::4q~,~4. [ ~";,3 6.48 0.00 -1585.79 -6.434 -0.78 11778.70 86.44 299.00 8964.79 846.64 3639.13 :5~;.4 g ~ (~?;. %0 ('~?[ 9-:~. ~. ~ i;'~. 4.99 0.00 -1535.36 -0.733 -4.95 11808.30 84.40 299.00 8967.15 860.94 3613.33 5%>; ~ 583..2~'N. ~>3.:~'.~t 5.32(; 6.89 0.00 -1508.33 -6.892 0.00 11846.30 84.28 298.7('.) 8970.90 879.19 3580.20 5 %.'~32(') [ .4 9()~,3.':[~82.2~.35 0.85 0.00 -1473.73 -0.316 -0,79 11876.00 82.00 300.50 8974.45 893.75 3554.57 ~ :,-.' '[ ~.~x' ! ~.~?:':~5.1 (' ,.:[.E ~t-.~:~:,g 9.75 0.00 -1446.60 -7.677 6.06 11906.10 81.40 301.30 8978.79 909.05 3529.01 59,.:f.~,2.?~ I, 34~} ~;3,::~.~;:~ [..() 1 3.30 0.00 -1418.93 -1.993 2.66' 1'1932.20 82.10 .,01.50 8982.54 922.5l _~506. )6 .>"t~ ~'4"~ J.....~.,, ~.,...~. ,'~.~. ,~.~,~'~ ('? 34 :~ ()~'C;;::(>.,:.~. 2.79 0.00 -1394.86 2.682 0.77 11960.40 84.70 301.30 8985.78 937.10 3483.06 5 (3~i.:3~25 ':..~, :'~ v'5 ('45 ,'-!.,7 ¢ :~,.~.~? 59.25 0.00 -1368.75 9.220 -0.71 11990.40 88.60 298.4O 8987.53 952.0O 3457.09 5'.'..', ~27.. ~.. 3',.~.) ~ :. 3.'~ '75'"..;'. (3~7' 16.19 0.00 -1341.15 13.000 -9.67 12042.20 91.80 293.40 8987.35 974.62 3410.51 5~;-:~:;2 %.4;~' 1 (~ ('}3.~'7 ~2.5 ~'~. 11.46 0.00 -1294.91 6.178 -9.65 12089.70 92.20 287.80 8985.69 991.31 3366.09 59.:~',~ 5 ~ 3.(3 ~ 2 4<,34 ~:'~.::,~.: ;9~; 11.81 0.00 -1254.68 0.842 -11.79 12119.00 93.90 283.90 8984.13 999.30 3337.95 5';:~.~332 [ .¢~()2 (', 3-.t f':,39.95.4 14.50 0.00 -1231.26 5.802 -13.31 12149.90 93.34 28().90 8982.18 1005.92 3307.84 59'~! ~%2~:..22.3 ~%..1.{'~;()v.~43~.' 9.86 0.00 -1207.72 -1.812 -9.71 12182.00 95.00 272.()0 8979.84 1009.52 3276.o6 5'i.)-~S:~ 3 I,[¢[ 9~,~45'7b.0~':;~ } 28.13 0.00 -1185.58 5.171 -27.73 12211.00~ 98.10 27O.40 8976.54 1010.12 3247.26 59-4.:~.~ 32 ...I.2 i~ (",345 [¢:.2~.'(~ 12.01 0.00 -1167.62 10.690 -5.52 12241.00 98.60 276.()0 8972.18 1011.78 3217.64 ?).:~->;.77,.-i-,(¥?'~ ¥3.1.3'!9',.57,? 18.54 0.00 -1148.33 1.667 18.67 12307.40 95.80 288.10 8963.82 1(.)25.52 3153.35 5 :;~;S;:3-~'7.?:2:4~:.34 [55.34:', 18.56 0.00 -1098.39 -4.217 18.22 12336.40 96.59 293.40 8960.69 1035.73 3126.40 ~%~'. 75:~.:"~ 4 <.: 3~.i..,,:271. ~;.:': 18.37 0.00 -1073.92 2.724 18.28~ 12376.60 99.30 301.4(') 8955.13 1054.03 3091.08 59~:~ ~.37(:,.~:;) i¢54 iq ?:Ts.t 77(, 20.83 0.00 -1037.95 6.741 19.90 12412.50 97.10 31o.90 8950.00 1074.97 3062.43 5'~4:9577.272 (,?.-~ 3.:-, :I.-"~25 26.90 0.00 -1003.91 -6.128 26.46 12445.40 95.70 316.30 8946.33 1097.5l 3038.76 5:)-.~ ~:~:~. ~ 9.~z. i 2 ~%-4.5--~-().%~: 16.86 0.00 -971.64 4.255 16.41 12485.40 94.32 319.3() 8942.83 1127.03 3012.00 5 %',?,.'~-'4 ?. 32 ~; ~"~343 ~ 3.'~% 8.23 0.00 -931.94 -3.450 7.50 12510.00 93.47 321.15 8941.16 1145.89 2996.30 5':2.", >~,,.*~>',:~. '~ ~::(':, ' ~'&i 2':)3.2'.,'7 8.26 0.00 -907.42 -3.455 7.52 S UR VIE¥ CA LCULA T I ON S Coord. inates provided 'in: TRUE and GRID relative to Well. head and ALASKA STATE PLANE Company: iBP EXPLO. RAT.[ON: ALASKA Rig: D/S CT Unit #7 AFE No: 4P~ (~75 W~"-,, [?-t).3A. Field: Prml:h~e ~ay WOA BHI Rep: Howa. r{~ Wagon:er C..Jlation Method: :M:inh~mm Curvature 1Mag..Declination: 28,].4t} Job Start Date: 27-Bec-98 Vertical Sect. Plane: :1 {~8l, (~l~J 9 TRUE 307',1 GRID Grid Correction: {1} .l~J ~) 9 Job End Date: Su~ Measured From: MD from ~Kg, Total Correction: 27,14~. :DLS per ( ft / m ) ~D. from Sea level. I Survey Meas. Course Incl. TRUE Subsea Ve~ical DLS Coords. - TRUiE GRID Coords. - GRID Coords. - ASP No. Depth Length Angle Az[. TVD Section N(+)/S(-) N(+)/S(-) Azi. N(+)/S(-) N(+)/S(-) N(+)/S(-) N(+)/S(-) (ft) (deg) (de~) (ft) TRUE °/100~. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y)l Dep. (X) Tie-in 10287.7 0.0 35.13 117.75 8873.66 -2854.14 0.00 145.15 3740.67 116.75 210.35 3737.58 5947532.7 635039.6 2 10290.0 2.3 35.07 117.70 8875.54 -2855.44 2.89 144.53 3741.84 116.70 209.76 3738.76 5947532.1 635040.7 3 10300.6 10.6 37.00 116.00 8884.12 -2861.56 20.51 141.72 3747.40 115.00 207.04 3744.37 5947529.4 635046.4 4 10320.7 20.1 39.30 113.00 8899.92 -2873.62 14.69 136.58 3758.70 112.00 202.10 3755.76 5947524.4 635057.7 5 10353.2 32.5 46.32 108.00 8923.76 -2894.63 23.98 128.92 3779.39 107.00 194.79 3776.57 5947517.1 635078.6 6 10377.3 24.1 52.40 105.40 8939.45 -2911.64 26.52 123.68 3796.90 104.40 189.87 3794.17 59475'12.2 635096.2 7 10403.6 26.3 56.90 99.80 8954.67 -2930.97 24.37 119.04: 3817.82 98.80. 185.59 3815.17 5947507.9 635117.2 8 10431.9 28.3 64.00 96.60 8968.62 -2952.28 26.94 115.55 3842.17 95.60 182.53 3839.58 5947504.9 635141.6 ~.2; 10461.7 29.8 71.10 94.40 8979.99 -2975.46 24.78 112.93 3869.56 93.40 180.38 3867.02 5947502.7 635169.0 ~10 10489.1 27.4 77.10 92.20 8987.50 -2997.08 23.22 111.42 3895.86 91.20 179.33 3893.33 5947501.7 635195.3 11 10529.9 40.8 85.80 90.00 8993.56 -3029.27 21.98 110.66 3936.16 89.00 179.27 3933.64 5947501.6 635235.6 12 10565.7 35.8 92.90 88.90 8993.96 -3057.20 20.07 111.00 3971.93 87.90 180.24 3969.40 5947502.6 635271.4 13 10600.8 35.1 99.10 81.70 8990.29 -3082.80 26.98 113.85 4006.68 80.70 183.69 4004.10 5947506.0 635306.1 14 10634.3 33.5 101.00 74.70 8984.44 -3104.03 21.34 120.58 4038.95 73.70 190.98 4036.24 5947513.3 635338.2 15 10671.7 37.4 98.40 65.20 8978.12 -3123.45 25.98 133.21 4073.53 64.20 204.22 4070.60 5947526.6 635372.6 16 10703.9 32.2 93.10 56.00 8974.89 -3135.68 32.84 148.93 4101.40 55.00 220.42 4098.18 5947542.8 635400.2 17 10736.0 32.1 93.10 48.10 8973.15 -3143.40 24.57 168.63 4126.65 47.10 240.55 4123.09 5947562.9 635425.1 18 10768.3 32.3 94.10 40.40 8971.12 -3146.86 23.99 191.70 4149.13 39.40 264.01 4145.16 5947586.4 635447.1 19 10800.7 32.4 93.34 30.40 8969.02 -3145.33 30.89 218.02 4167.83 29.40 290.66 4163.41 5947613.0 635465.4 20 10829.7 29.0 92.40 24.00 8967.56 -3139.86 22.28 243.77 4181.06 23.00 316.63 4176.19 5947639.0 635478.2 21 10862.0 32.3 91.93 14.00 8966.34 -3129.31 30.97 274.25' 4191.56 13.00 347.29 4186.15 5947669.6 635488.1 I I Survey Meas. Course Incl. ~rR[L" "1 7, Subsea Ve~ical DLS Coords. - TRUE G,iRID Coords. - GRID C{}ords. - ASP No. Depth Length Angle Azi. TVD Section N(+)/S(-) N(+)/S(-) AzL N(+)/S(-) N(+)/S(-) N(+)/S(~ N(+)/S(-) (~) (deg) (deg) (ft) TRUE °/100N. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y), ,Dep. (x) 22 10900.0 38.0 90.70 2.80 8965.46 -3110.52 29.64 311.77 4197.10 1.80 384.90 4191.03 5947707.3 635493.0 23 10930.0 30.0 93.30 354.30 8964.41 -3091.45 29.61 341.71 4196.34 353.30 414.83 4189.75 5947737.2 '635491.7 24 10963.0 33.0 96.00 344.70 8961.73 -3066.81 30.12 374.01 4190.36 343.70 447.02 4183.21 5947769.4 63'5485.2 25 10992.9 29.9 96.10 336.90 8958.58 -3041.81 25.94 402.07 4180.59 335.90 474.90 4172'.95 5947797.3 635474.9 26 11027.0 34.1 96.90 329.00 8954.71 -3011.09 23.14 432.22 4'165.19 328.00 504.78 4157.03 5947827.1 6354~9.0 27 11072.8 45.8 97.10 321.80~ 8949.12 -296'7.72 15.61 469.61 4139.40 320.80 541.72 4130.59 '5947864.1 635432.6 28 11106.2 33.4 94.90 315.50 8945.63 -2935,08 19.88 494.53 4117.46 314.50 566.25 4108.22 5947888.6 635410.2 29 1111'3.8 7.6, 93.50 313.70 8945.07 -2927.55 29.95' 499.85 4112.06 312.70 571.48 4102.73 5947893,8 635404.7 _ ~,~ 11147.1 33.3 89.70 304.80 ,8944.14 -2894.31 29.05 520.89 4086.32 303.80 592.06 4076.62 5947914.4 635378.6 ~ 11179.9 32.8 90.20 294.80 8944.17 -2861.89 30.53 537.17 4057.89 293.80 607.84 4047,92 5947930.2 635349.9 32 11217.6 37.7 93.08 286.00 8943.09 -2826.03 24.55 550.29 4022.61 285.00 620.34 4012.41 5947942.7 635314.4 33 11249.5 31.9 93.60 274.50 8941.22 -2797.92 36.03 555.95 3991.32 273.50 625.45 3981.03 5947947.8 635283.0 34 11290.2 40,7 93.70 266.10 8938.63 ~2765.86 20.60 556.16 3950.74 265.10 624.96 3940.45 5947947.3 635242.4 35 11330.0 39.8 90.90 261.40 8937.03 -2737.43 13.74 551.83 3911.23 260,40 619.94 3901.02 5947942.3 635203.0 36 11368.1 38.1 91.80 262.50 8936.13 -2711.04 3.73 546.49 3873.51 261.50 613.95 3863.40 5947936.3 635165.~'" 37 11406.4 38.3 90.70 267.50 8935.30 -2683.10 13.36 543.16 3835.38 266.50 609.95 3825.34 5947932.3 635127.~' 38 11435.9 29.5 88.60 268.60 8935.48 -2660.52 8.04 542.15 3805.90 267.60 608.43 3795.88 5947930.8 635097.9 39 11465.8 29.9 88.10 267.30 8936.34 -2637.67 4.66 541.08 3776.03 266.30 606.84 3766.03 5947929.2 635068.0 40 11491.1 25.3 87.00 263.90 8937.42 -2619.04 14.11 539.15 3750.83 262.90 604.46 3740.87 5947926.8 635042.9 41 11528.6 37.5 87.30 261.00' 8939.28 -2592.86 7.77 534.22 3713.71 260.00 598.89 3703.84 5947921.2 635005.8 42 11569.6 41.0 90.10 266.80 8940.21 -2563.49 15.70 529.87 3672.97 265.80 593.83 3663.19 5947916.2 634965.2 43 11600.0 30.4 91.50 269.40 8939.79 -2540.21 9.71 528.86~ 3642.60 268.40 592.29 3632.83 5947914.6 634934.8 44 11654.4 54.4 91.40 274.00 8938.41 -2496.45 8.46 530.47 3588.25 273.00: 592.96 3578.47 5947915.3 634880.5 45 11687.3 32.9 90.62 278.90 8937.83 -2468.45 15.08 534.17 3555.58 277.90 596.08 3545.73 5947918.4 634847.7 ~ 11723.8 36.5 89.00 281.90 8937.95 -2436.14 9.34 540.76 3519.68 280.90 602.04 3509.73 5947924.4 634811.7 47 11755.7 31.9 88.33 286.10 8938.70 -2407.03 13.33 548.47 3488.74: 285.10 609.21 3478.66 5947931.6 634780.6 48 11794.5 38.8 87.50 290.90 8940.11 -2370.52 12.55 560.77 3451.98 289.90 620.87 3441.69 5947943.2 634743.7 49 11827.6 33.1 87.50 294.60 8941.55 -2338.63 11.17 573.55 3421.49 293.60 633.12 3410.98, 5947955.5 634713.0 50 11873.7 46.1 87.70 298.80 8943.48 -2293.49 9.11 594.24 3380.35 297.80 653.09 3369.49 5947975.4 634671.5 51 11909.4 35.7 88.70 303.70 8944.61 -2258.08 14.00 612.75 3349.86 302.70 671.06 3338.67 5947993.4 634640.7 52 11943.8 34.4 87.40 306.30 8945.78 -2223.75 8.45 632.46 3321.70 305.30 690.29 3310.17 5948012.6 634612.2 53 11970.6 26.8 85.60 307.60 8947.41 -2197.01 8.28 648.54 3300.32 306.60 705.99 3288.52 5948028.3 634590.5 54 12011.3 40.7 86.10 306.30 8950.36 -2156.42 3.41 672.94 3267.88 305.30 729.82 3255.66 5948052.2 634557.6 55 12058.7 47.4 89.50 302.90 8952.18 -2109.16 10.14 699.83 3228.90 301.90 756.02 3216.22 5948078.4 634518.2 56 12096.6 37.9 90.20 298.80 8952.28 -2071.57 10.97 719.26 3196.37 297.80 774.88 3183.36 5948097.2 634485.3 57 12128.1 31.5 90.70 295.40 8952.03 -2040.66 10.91 733.60 3168.34 294.40, 788.74 3155.07 5948111.1 634457.1 58 12166.5 38.4 90.70 290.90 8951.56 -2003.57 11.72 748.70 3133.04 289.90 803.21 3119.52 5948125.6 634421.5 Survey Meas. Course Incl. TRUE Subsea Vertical DLS Coords. - TRUE GRtD Coords. - GRID Coords. - ASP No. Depth Length Angle Azi. TVD Section N(+)/S(-) N(+)/S(-) A×L N(+)/S(-) N(+)/S(-) N(+)/S(-) N(+)/S(-) (ft) (deg) (deg) (ft) TRUE °/100~. Lat. (Y) Dep. (X) (deg) Lat. (Y) Dep. (X) Lat. (Y) Dep. (X) I I I 59 12190.3 23.8 89.80 288.60 8951.46 -1980.98 10.38 756.74 31'10.64 287.60 810.86 3096.98 5948133.2 634399.0 60 12220.1 29.8 89.40 284.60 8951.67 -1953.26 13.49 765.25 3082.09 283.60 818.87 3068.29 '5948141.2 634370.3 61 12248.9 28.8 89.50 283.10 8951.94 -1927.01 5.22 772.14 3054.13 282.10 825.28 3040.21 5948147.6 634342.2 62 12281.2 32.3 90.30 279.00 8952.00 -1898.24 12.93 778.33 3022.43 278.00 830.91 3008.41 5948153.3 634310.4 63 12323.8 42.6 92.13 278.00 8951.10 -1861.21 4.90 784.62 2980.31 277.00 836.47 2966.19 5948158.8 634268.2 64 1'2370.2 46.4' 90.09 270.70 8950.20 -1822.67 16.33 '788.14 2934.09 269.70 839.18 2919.91 5948161'.5 634221.9 65 :1'2398.6 28.4 90.43 267.00 8950.07 -1800.68 13.08 787.57 2905.70 266.00 838.11 2891.54 5948160.5 6341'93.5 66 12428.2 29.6 90.80 261.90 8949.75 -1779.27 17.27 784.71 2876.25 260.90 834.74 2862.14, 5948157.1 634164.i 2' ~ '12468.6' 40.4 91.30 262.30 8949101 -1751.21 ,, 1.58 779.15 2836.24 261.30 '828.49 2822.23 5948150.8 634124.2! 12503.2 34.6 91.40 267.40 8948.19 -1726.03 14.74 776.05 2801.80 266.40 824.78 2787.86 5948147.1 634089.8 69 12541.4 38.2 '91.60 274.30 8947.19 -1695.65 18.06 776.61 2763.64 273.30 824.68 2749.69 5948147.0 63405'1.7 70 12603.3 61.9 91.00 280.10 8945.79 -1642.57 9.42 784.37 2702.27 279.10 831.37 2688.20 5948153.7' 633990.2 71 12630.7 '27.4 91.70 284.40 8945.14 -1617.93 15.90 790.18 2675.51 283.40 836.71 2661.34 5948i59.1 633963.3 72 12668.3 37.6 92.00 289.50 8943.92 -1582.89 13.58 801.13 '2639.57 288.50 847.03 2625.21 5948169.4 633927.2 73 12713.5 45.2 88.70 291.70 8943.65 -153'9.79 8.77 817.03 2597.27 290.70 862.19 2582.64 5948184.5 633884.6 74 12738.2 24.7 88.50 2'93.50 8944.25 -1516.00 7.33! 826.52 2574.48 292.50 871.28 2559.69 5948193.6 633861.7 75 12776.2 38.0 89.50 291.90 8944.92 -1479.37 4.96 841.18 2539.43 290.90 885.33 2524.39 5948207.7 633826.4 76 12806.2 30.0 89.50 292.00 8945.18 -1450.55 0.33 852.39, 2511.60 291.00 896.05 2496.37 5948218.4 633798.4 77 12838.9 32.7 84.90 290.90 8946.77 -1419.27 14.46 864.33 2481.21 289.90 907.46 2465.78 5948229.8 633767.8 78 12868.4 29.5 79.30 291.90 8950.83 -1391.29 19.28 874.99 2454.02 290.90 917.64 2438.40 5948240.0 633740.4 79 12904.0 35.6 73.46 291.84 8959.21 -1358.09 16.41 887.87 2421.92 290.84 929.96 2406.08 5948252.3 633708.1 State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Transmittal of Final Prints. Please sign and return copy to: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 03-Jan-98 Well Nam~ ....... Services Bluelines R/F Sepia Film P-__03 A Induction Electrolog/GR 1 1 0,i . Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATI ON COM~HSSI ON 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 12. 1997 John McMullen Coiled Tubing Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-66 i2 Re; Prudhoe Bay Unit P-03Ai BP Exploration (Alaska) Inc. Permit No. 97-228 Sur. Loc. 2594'NSL. 2020'EWL. Sec. 31, TI 1N. R13E. UM Btmhole Loc. 3033'NSL, 1088'EWL. Sec. 32. T11N. R13E. UM Dear Mr. McMullen' Enclosed is the approved application for permit to rcdrill the above referenced well. The pcrmit to redrill docs not cxcmpt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and thc mechanical integrity (MI) of the injection ,,,,'ells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe. must be given so that a representative of thc Commission may witness thc tests. Notice may be given by contacting the Commission petroleum field inspector on thc North Slope pager at 659-3607. David W. Johnston Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosure Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA .... iL AND GAS CONSERVATION CL-,~:IMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work [] Drill [] Redrill Ilb Type of well [] Exploratory [] Stratigraphic Test [] Development Oil [] Re-Entry [~] DeepenI ' []Service [~ Development Gas E~]Single Zone E~]Multiple Zone 2'. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE= 91.54 Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box196612, Anchorage, Alaska 99519-6612 ADL 028288 ~'~ 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2594' NSL, 2020' EWL, SEC. 31, T11 N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 2624' NSL, 4380' EWL, SEC. 32, T11 N, R13E P-03Ai At total depth 9. Approximate spud date Amount $200,000.00 3033' NSL, 1088' EWL, Sec. 32, T11N, R13E December 15, 1997 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 151 'Proposed depth (MD and TVD) ADL 028289 @3033'I No Close Approach 2560 12,209', 9025'TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10,317 Maximum Hole Anqle 95° Maximum surface 3300 psig, At total depth (TVD) 3698@8800' psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4 2 7/8" 6.16# L-80 ST-L 1950 10,260 8855 12,209 9,025 85 c.f. 19. To be completed for Redrill, Re-entry, and Deepen Operations.RECEIVED Present well condition summary Total depth: measured 10674 feet Plugs (measured) true vertical 9287 feet - 3 1997 Effective depth: measured 10589 feet Junk (measured) true vertical 9217 feet ~0il& 6as Cons. t.;0~'t~ri~ssiorl Anchorage Casing Length Size Cemented MD TVD Structural BKB Conductor 110 20" 145 145 Surface 2668 10-3/4" 2790 C.F. permafrost 2703' 2611' Intermediate 10217 7 5/8" 1483 c.f. Class G 10252 8936 Production Liner 9983 5-1/2" 167 c.f. Class G 9983-10674 8719-9288 Perforation depth: measured 10356'-10372' 10380'-10398'ORIGINAL true vertical subsea8930'-8943',8950'-8965' 20. Attachments [] Filing Fee [] Drilling Fluid Program [] Property Plat [] Time vs Depth Pict [] BOP Sketch [] Refraction Analysis [] Diverter Sketch [] Seabed Rep Contact Engineer Name/Number: John McMullen 564-5247 Prepared By Name/Number: Theresa Mills 564-5894 ..... 21.1 hereby cert~//~ha/~t~/~.r,¢~i~ is true and correct to the best of my knowledge /__ Signed/¢)/'.~,~., (.~ //PC ~'~ //¢~n McMCen Title Coiled Tubing Drilling Engineer Date ~'P~" 7 y Commission Use Only Permit Number I APl Number I Appro, v¢l D~te I See cover letter °1 '7-, 50- 0 2 - I -7 01 I Ifor other requirements C~ns of,Acp'~mples Requir_[.c.~L [] Yes ~ No Mud Log Requirec~[] Ye~~__ ~~~"~.~ H~eMe~ures ,l~Yes [] No DirectionalSurveyRequired~[] ~ [ ~~Re~~.?'~j,~roCuref~'~-~F'BOPE 2M ' ~'s-~ ; X~; 5M; by or~e0rl~i 15M / / .A_pproved Commissioner the commission Date ! )/.12/~i~7 Form 10-401 Rev. 12-01-85~ Submi' ~-~ :ate BPX P-03ai CTU Sidetrack Summary of Operations: This sidetrack is designed to improve injection conformance by abandoning the existing injection interval and completing a new injection interval in Zone 4. This sidetrack will be conducted in two phases. Phase 1: Set whipstock and abandon existing perfs. Set permanent whipstock at about 10,300' ELMD. - Using service coil, plug the existing perforations by the downsqueeze method from the top of the whipstock. The cement plug will then be pressure tested with AOGCC witness. Phase 2: Drill Directional Hole: - Directional drilling coil tubing equipment will be rigged up and utilized to mill the window and drill the directional hole as per attached plan to planned TO of 12,209' MD (9,025' TVDss). Mud Program: - Phase 1: Seawater - Phase 2: FIo-Pro (8.8 - 8.9 ppg) Casing Program: DEC - 199 ' Naska 0il & Gas Cons, ~issi0n ~ch0rage - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,260' MD and cemented with approx. 15 bbls. cement. This will place the top of the 2 7/8" liner within the existing 5 1/2" liner. The well will then be perforated with coil tubing conveyed guns. The depth of the top of the cemented 2 7/8" liner is planned to allow for a future Sag R. sidetrack. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,317' MD (8,898' TVD ss) - TD: 12,209' MD (9,025' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging - ^ Gamma Ray Icg will be run over all of the open hole section. - CTE-Line will be used to run GR/Induction logs at TD. P-03 o Verl¢~l Secti¢~o Palt, l~(~stanc~,~(~t) 2,500 3,000 3,500 88oo! : I : ' il TSGR ~ 'TSAG 881688, 10,217 MD / i: ~ ;TSHU 883888, 10,244 MD '-_TSHU_.___t -__~. , . . . 8850 '7 5/8" Shoe 884588, 10,252 MD ~, Angle @ K.O.= 34 deg ~,8900 MD:10317 ~- ~ 37 deg ' -TSA 8950 / I 12209 TD 9050/ I T0¢~18:~'92 ff .... Marker Depths @Orig Wellbore TSAD 8930 I 8,9301ft TVD HoT I 8,9951ft TS~U I 8,8381ft TVD Kick Off 8,8981ft TVD I 10,317Jft MD Deprtr ~KO 3,773 ft 10,317I 1892 I 9,02SI MD KO Pt MD New Hole Total MD TVD TD DLS deg/100 Tool Face Length Curve 1 12 0 20 Curve 2 42 -20 147 Curve 3 28 -90 439 Curve 4 28 -105 90 Curve 5 8 -90 324 Curve 6 6 90 524 Curve 7 6 90 99 Curve 8 8 180 249 1,892 Drawn: 12/3/97 7:11 Plan Name: Case 101 1,500 P-03 2,000 2,500 3,000 3,500 4,000 X distance from Sfc Loc 4,500 5,000 IWellName P-03 I CLOSURE Distance 4,095 ft Az 83 deg NEW HOLE E/W (X) N/S (Y) Kick Off 3,752 203 TD 4,063 512 State Plane 635,365 5,947,834 Surface Loc 631,302 5,947,322 DLS deg/100 Tool Face Length Curve 1 12 0 20 Curve 2 42 -20 147 Curve 3 28 -90, 439 Curve 4 28 -105 90 Curve 5 8 -90 324 Curve 6 6 90 524 Curve 7 6 90 99 Curve 8 8 180 249 1,892 Drawn: 12/3/97 7:11 Plan Name: Case 101 TREE: 4 1/16"- 5M CIW WFII HFAF)' 11"-RM FMC, ,--03a Proposed Completion KB. ELEV = 91.54' sssv LANDING N,PPLE I 2048' 10 3/4", J 2703'1 4R KOP: 3500' MAX ANGLE: 45° @ 6215' 4 1/2", 12.6#/ft, 13CR, TUBING ID: 3.958" CAPACITY: 0.0152 BBL/FT CHROME TBG & L CMT'd NER GAS LIFT MANDRELS 5 2985' 2893' 4 5721' 5421' 3 8073' 7155' 2 9533' 8271' 1 9905' 8565' 1/2 .... SWS" NIPPLE 9922'1 Right-hand release TOP OF TIW I 9983' 51/2" LINER 7 5/8", 29.7#/ft, 1 10,252' NT-95HS, NSCC 2 7/8" Cemented Liner (10,260' Top of Whipstock (10,300') P & A Cement PERFORATION SUMMARY REF LOG: SWS - BHCS 6-9-91 TIE-IN LOG: SWS - GR/CCL 7-14-91 SPF INTERVAL (:~PEN/SQZ'D 10,356-10,372' 10,370-10,390' 10,380-10,398' 10,400-10,450' OPEN/7-15-91 OPEN/10-8-91 OPEN/7-15-91 Open 10/7/92 PBTD 5 1/2", 17#/ft, 13Cr, FL4S I 10~674' I'-- -- -- 7 5/8" TIW PACKER 9933'1 4 1/2", 12.6#/ft, 13Cr TAILPIPE 4 1/2 ....SWS" NIPPLE (PARKER) (3.813" ID) 4 1/2 ....SWN" NIPPLE (PARKER) (3.725" ID) 19955' I 9975' SWN = 9977' ELMD I 4 1/2" WLEG [ (MOD. BAKER) 9987' SAG R. SHUBLIK · ZONE 4 P;03ai CT Drilling & Completion BOP _z 22.5" 18"I 2 3/8" CT ~ I10,000psi ~ack-Off I Lubricator~ I 7 1/16" Annular 7 1/16" 5000 psi Blind/Shear 7 1/16" Pipe/Slip --~ 2 3/8" .7 ,. :, 6: .x s:o. oo. ,.s, '-1 Slips' ~II~B -~ [:~1 2 7/8" 7 1/16" Pipe ~ ~ 2 3/8" SWAB OR MASTER VALVE I STATE OF ALASKA ALASKA OIL KND GAS CONSERVATION COMMISSIO,,~ APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: ~ Abandon ,2 Suspend ~ Plugging ~ Time Extension ~ Perforate ~ Alter Casing ~ Repair Well ~ Pull Tubing ,'~ Variance ~ Other ~ Change Approved Program ~ Operation Shutdown ~ Re-Enter Suspended Well ~ Stimulate Plug Back for Sidetrack 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box196612, Anchorage, Alaska 99519-6612 Type of well: Development ~ Service Exploratory Stratigraphic 4. Location of well at surface 2594' NSL, 2020' EWL, SEC. 31, T11 N, R13E At top of productive interval 2624' NSL, 4380' EWL, SEC. 32, T11 N, R13E At effective depth 2624' NSL, 4380' EWL, SEC. 32, T11 N, R13E At total depth 2631' NSL, 940' EWL, SEC. 32, T11 N, R13E 6. Datum Elevation (DF or KB) KBE= 91.54 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number P-03i 9. Permit Number 91-72 10. APl Number 50- 029-22176 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10674 true vertical 9287 Effective depth: measured 10589 true vertical 9217 Casing Length Structural Conductor 110 Surface 2668 Intermediate 10217 Production Liner 9983 feet Plugs (measured) feet feet Junk (measured) feet Size Cemented 20" 10-3/4" 2790 C.F. permafrost 7 5/8" 1483 c.f. Class G 5-1/2" 167 c.f. Class G MD TVD BKB 145 145 2703' 2611' 10252 8936' 9983-10674 8719-9288 Perforation depth: measured true vertical 10356'-10372' 10380'-10398' subsea8930'-8943',8950'-8965' Tubing (size, grade, and measured depth) 4-1/2" 12.6" NT13CR80 Packers and SSSV (type and measured depth) Paker@9934' SSSV @2048' 13. Attachments ~.~ Description summary of proposal ~ Detailed operations program ~. BOP sketch 14. Estimated date for commencing operation December 10,1997 6. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Date approved John McMullen 564-5247 15. Status of well classifications as: ~_ Oil L~ Gas ,_~ Suspended Service Water Injection Prepared By Name/Number: Theresa Mills 564-5894 I hereby certify~rat th~fo.r.c/e~oir~ i§ tru/e and correct to the best of my knowledge Signed Title Coiled Tubing Drilling Engineer Commission Use Only Date (~-/~ /~'"~ Conditions of Approval: Notify Commissio~entative......~e/_.~.~.~ss PI~ BO'I~ ,?~__ ~l~catio~learance __ Approved by order of the Commission ~...~~~~ ,.__..,/~ Form 10-403 Rev. 06/15/88 ~. Commissioner Date submit'~n'-Cripl~cate · WELL PERMIT CHECKLIST COMPANY FIELD & POOL 0 / INIT CLASS WELL NAME P-'0~'~ GEOL AREA PROGRAM: exp [] dev [] redrll ,l~serv J~wellbore seg I ann. disposal para req ti UNIT# ~ [.(~,,~0 ON/OFF SHORE ADMINISTRATION 1. Permit fee attached ....................... .~__~N 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. (~N 5. Well located proper distance from drilling unit boundary .... (~:?., N 6. Well located proper distance from other wells .......... ~ N 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included .............. ~,.~N 9. Operator only affected party ................... fdPN 10. Operator has appropriate bond in force ............. .~ N 11. Permit can be issued without conservation order ........ (~ N 12. Permit can be issued without administrative approval ...... ~ N 13. Can permit be approved before 15-day wait ........... N ENGINEERING APPR DATE 14. Conductor string provided ................... ~r 15. Surface casing protects alt known USDWs ........... Y 16. CMT vol adequate to circulate on conductor & surf csg ..... Y 17. CMT vol adequate to tie-in long string to surf csg ........ Y 18. CMT will cover all known productive horizons .......... (~ N 19. Casing designs adequate for C, T, B & permafrost ....... (~N 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. (~ N 23. If diverter required, does it meet regulations .......... ,~-Y---N--¢~ 24. Drilling fluid program schematic & equip list adequate ..... (~ N 25. BOPEs, do they meet regulation ................ ~ N 26. BOPE press rating appropriate; test to '-~~ .. psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ (~ N 28. Work will occur without operation shutdown ........... ~ N 29. Is presence of H2S gas probable ................. N GEOLOGY DATE 30. Permit can be issued w/o hydrogen sul..~ures.~'''''~ .... Y N 31. Data presented on potent~sure zones ....... Y N 32. Seismic analysis~w gas zones ............. Y N 33. Seabed c~on survey (if off-shore) ............. Y N 34..,~name/phone for weekly.progress reports ....... Y N lexp~oratory only] REMARKS GEOLOGY: ENGINEERING: COMMISSION' RPC ~-t') BE~I?~II~) DWJ ~ I~ JDH ~ RNC CO C,o Comments/Instructions: HOW/Ijt - A \FORMS\chekhst rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER . . ....... SCHLUMBERGER ....... . COMPANY NAME : BP EXPLORATION (ALASKA) INC. WELL NAME : P-O3A PB1 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE . ALASKA API NUMBER : 500292217601 REFERENCE NO : 98194 Da~e~ LIS Tape VerificatiOn Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC REEL NAME : 98194 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, P-O3A PB1, PRUDHOE BAY, API# 50-029-22176-01 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC TAPE NAME : 98194 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, P-O3A PB1, PRUDHOE BAY, API# 50-029-22176-01 TAPE HEADER PRUDHOE BAY OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: RUN 1 98194 D CAIN S CRUMLEY WELL CASING RECORD 1ST STRING 2ND STRING P-O3A PB1 500292217601 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS 12-MAY-98 RUN 2 RUN 3 31 liN 13E 2594 2020 91.50 90.50 54.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 5.500 10299.0 LIS Tape Verific~='on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE LDWG FORMATTED OPEN HOLE INDUCTION ELECTROLOG DATA AQUIRED ON BP EXPLORATION'S P-O3A WELL. THIS DATA WAS LOGGED BY WESTERNATLASAND PROCESSED BY SCHLUMBERGER. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELTAIONS BETWEEN GRMAIN PASS #1 AND THE PDC GAMMA RAY, CARRYING ALL IEL CURVES WITH THE GR SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION ' O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE DIL $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 12390.0 10312.0 BASELINE DEPTH .............. 88888.0 12344.0 12362 12336.0 12350 12329.5 12343 12317.5 12332 12307.0 12321 12304.0 12317 12293.0 12307 12272.0 12283 12257.0 12269 12248.5 12259 12211.5 12223 12198.5 12213 12196.0 12208. .......... EQUIVALENT UNSHIFTEDDEPTH .......... CRCH ....... 88906.5 LIS Tape Verific~k~bn Listing Schlumberger Alaska Computing Center 12188 5 12182 5 12165 5 12152 5 12150 5 12149 0 12145 0 12139 5 12083 5 12074 5 12056 5 12039 0 12025.0 11989 0 11983 0 11930 5 11923 5 11918 0 11912 0 11909 0 11902 5 11897 5 11892 0 11865 5 11858 0 11854 5 11824 0 11821 5 11810 0 11794 0 11738 5 11733 0 11729 5 11723 5 11716 5 11711 5 11699.5 11696.0 11686.5 11666.5 11660.0 11640.5 11636.5 11632.5 11626.0 11620 0 11614 0 11596 5 11592 5 11572 5 11568 0 11556 5 11549 0 11538 5 11536 5 12199.5 12194.0 12174.5 12161.5 12158.5 12156.5 12154.5 12148.0 12092.5 12079.5 12057.0 12043.5 12026.0 11987.5 11981.0 11926.5 11922.0 11912.0 11906.0 11904.5 11898.0 11894.0 11888.5 11864.5 11856.0 11851.5 11821.0 11820.0 11811.0 11798.5 11748.5 11744.5 11740.5 11733.5 11727.0 11723.5 11711.0 11705.0 11700.0 11681.0 11672.0 11660.5 11654.0 11647.5 11644.5 11637.0 11632.0 11613.5 11611.0 11591.5 11586.0 11572.0 11563.5 11554.0 11553.0 13-MAY-1998 09:58 PAGE LIS Tape Verifica'u~on Listing Schlumberger Alaska Computing Center 11523.0 11541.0 11516.0 11534.0 11508.0 11524.0 11500.5 11514.5 11493.0 11507.0 11487.5 11502.5 11477.5 11494.0 11474.5 11488.5 11468.5 11483.5 11454.0 11467.5 11433.0 11446.5 11427.0 11439.0 11417.5 11432.0 11411.0 11426.5 11408.0 11423.5 11406.0 11418.0 11402.5 11413.0 11386.0 11395.0 11378.0 11387.0 11376.5 11384.5 11373.0 11381.5 11369.0 11376.5 11357.0 11366.0 11347.5 11356.0 11345.0 11353.5 11339.5 11345.5 11328.0 11335.0 11318.0 11326.0 11276.5 11286.5 11273.0 11283.0 11265.0 11273.0 11255.5 11263.5 11245.0 11254.0 11243.5 11253.0 11232.5 11240.5 11230.0 11236.5 11225.0 11234.0 11218.5 11226.5 11216.0 11223.5 11212.5 11219.5 11210.5 11218.5 11205.5 11213.5 11202.5 11210.5 11195.5 11203.5 11191.5 11198.5 11189.0 11196.0 11186.0 11193.5 11180.5 11186.0 11174.5 11181.0 11167.5 11176.5 11164.0 11173.0 11161.5 11169.5 11144.5 11153.5 11139.0 11147.5 11130.5 11138.0 13-MAY-1998 09:58 PAGE: LIS Tape Verific~6~on Listing Schlumberger Alaska Computing Center 11111.0 11108.0 11101 . 0 11097.5 11074.5 11068.0 11064.0 11054.5 11051.0 11048.0 11046.0 11039.0 11033.5 11028.0 11023.5 11014.5 11009.0 11006.0 10996.5 10989.0 10986.0 10979 5 10974 0 10972 5 10966 0 10957 5 10951 5 10948 0 10939.5 10937.5 10926.0 10917.5 10911.5 10901.0 10891.0 10886.0 10882.5 10879.5 10870.5 10864.0 10858.0 10847.0 10844.0 10837.0 10819.5 10814.5 10801.5 10796 0 10792 0 10788 5 10776 0 10774 5 10764 5 10760 5 10756.0 11119.5 11115.5 11104.5 11099.5 11080.5 11073 5 11071 0 11061 0 11057 0 11055 0 11052 0 11043.5 11041.5 11034.0 11028.0 11018.5 11012.5 11010.5 11002.0 10995.0 10993.5 10986.5 10980.5 10978.5 10971.5 10963.5 10959.0 10953 0 10946 0 10942 5 10929 0 10922 0 10917 0 10905 0 10892 5 10888.5 10886.0 10880.5 10872.5 10865.5 10861.0 10851.0 10848.0 10841.0 10824.5 10818.5 10804.5 10799.0 10794.0 10790.5 10779.0 10776.5 10769.0 10765.0 10759.5 13-MAY-1998 09:58 PAGE LIS Tape Verifica'~'~n Listing Schlumberger Alaska Computing Center 10749.5 10742.5 10738.0 10733.5 10728.5 10723.5 10720.0 10708.5 10703.0 10689.5 10682.5 10675.0 10665.5 10658.5 10656.5 10651 0 10643 0 10632 0 10630 0 10623 5 10620 5 10615 5 10609 0 10595 5 10594 5 10590 5 10586 0 1O58O 5 10578 0 10574 5 10571.0 10564.5 10561.0 10557.0 10550.0 10543.0 10535.5 10531.0 10528.5 10521.5 10506.0 10497.0 10494.5 10487.0 10479.0 10470.0 10466.0 10460.0 10452.5 10445.5 10435.5 10431.5 10423.5 10417.0 10411.5 10753.0 10745.0 10742.0 10736.5 10731.0 10726.5 10722.0 10709.5 10704.5 10691.5 10682.0 10676.5 10668.5 10660.0 10657.0 10652.5 10645.0 10633.0 10630.0 10624.0 10621.0 10616.0 10608.5 10596.5 10595.5 10589.5 10584.5 10580.0 10577.5 10574.0 10569.5 10562.5 10556.5 10554.5 10549 5 10544 5 10533 5 10531 0 10528 0 10522 5 10511 5 10502 5 10499 5 10493 0 10485 5 10475 0 10470 0 10465 0 10457 5 10453 0 10441 0 10435 0 10428 0 10420 0 10416 5 13-MAY-1998 09:58 PAGE: LIS Tape Verific~t~on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 10408.0 10404.0 10397.0 10394.0 10384.5 10380.0 10373.0 10363 5 10361 5 10358 0 10351 5 10343 5 10340 0 10337 5 10329 0 10325.5 10304.0 10299.5 10296.5 10291.0 10285.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 10411.5 10406.0 10400.5 10397.5 10387.5 10383.5 10375.5 10365.5 10364.0 10360 0 10353 5 10345 5 10342 5 10340 0 10330 5 10327 0 10305 5 10301 0 10296.5 10292.0 10286.0 101.0 RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS OPEN HOLE DECIMATED, CLIPPED AND DEPTH SHIFTED MAIN PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SBT TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 28 4 66 1 5 66 6 73 7 65 8 68 0,5 9 65 FT 11 66 36 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 8 TYPE REPR CODE VALUE 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 1 1 1 4 68 0000000000 GR IES GAPI 189683 O0 000 O0 0 1 1 1 4 68 0000000000 SN IES OHMM189683 O0 000 O0 0 1 1 1 4 68 0000000000 SP IES MV 189683 O0 000 O0 0 1 1 1 4 68 0000000000 TENS IES LB 189683 O0 000 O0 0 1 1 1 4 68 0000000000 TEND IES LB 189683 O0 000 O0 0 1 1 1 4 68 0000000000 ILD IES OH~ff4189683 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 12388.500 GR.IES -999.250 SN. IES TENS.IES 360.339 TEND.IES -17.406 ILD. IES 5.393 SP.IES -80.000 9.513 DEPT. 10312.000 GR.IES 318.980 SN. IES -999.250 SP. IES -999.250 TENS.IES -999.250 TEND.IES -999.250 ILD. IES -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT . 001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verific~=mon Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE START DEPTH IES 10312.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 10118.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH IES 88888.0 88906.5 12344.0 12362.5 12336.0 12350.0 12329.5 12343.5 12317.5 12332.5 12307.0 12321.5 12304.0 12317.5 12293.0 12307.0 12272.0 12283.5 12257.0 12269.5 12248.5 12259.5 12211.5 12223.0 12198.5 12213.5 12196.0 12208.5 12188.5 12199.5 12182.5 12194.0 12165.5 12174.5 12152.5 12161.5 12150.5 12158.5 12149.0 12156.5 12145.0 12154.5 12139.5 12148.0 12083.5 12092.5 12074.5 12079.5 12056.5 12057.0 LIS Tape Verific~_zon Listing Schlumberger Alaska Computing Center 12039 0 12025 0 11989 0 11983 0 11930 5 11923 5 11918 0 11912 0 11909 0 11902 5 11897 5 11892 0 11865 5 11858 0 11854 5 11824 0 11821.5 11810.0 11794.0 11738.5 11733.0 11729.5 11723.5 11716.5 11711.5 11699.5 11696.0 11686.5 11666.5 11660.0 11640.5 11636.5 11632.5 11626.0 11620.0 11614.0 11596.5 11592.5 11572.5 11568.0 11556.5 11549.0 11538.5 11536.5 11523.0 11516.0 11508.0 11500 5 11493 0 11487 5 11477 5 11474 5 11468 5 11454 0 11433 0 12043.5 12026.0 11987.5 11981.0 11926.5 11922.0 11912.0 11906.0 11904.5 11898.0 11894 0 11888 5 11864 5 11856 0 11851 5 11821 0 11820 0 11811 0 11798 5 11748.5 11744.5 11740.5 11733.5 11727.0 11723.5 11711.0 11705.0 11700.0 11681.0 11672.0 11660.5 11654.0 11647.5 11644.5 11637.0 11632.0 11613.5 11611.0 11591.5 11586.0 11572.0 11563.5 11554.0 11553.0 11541.0 11534.0 11524.0 11514.5 11507.0 11502.5 11494.0 11488.5 11483.5 11467.5 11446.5 13-MAY-1998 09:58 PAGE: 10 LIS Tape Verific~.=on Listing Schlumberger Alaska Computing Center 11427.0 11417.5 11411.0 11408.0 11406.0 11402.5 11386.0 11378.0 11376.5 11373.0 11369 0 11357 0 11347 5 11345 0 11339 5 11328 0 11318 0 11276.5 11273 0 11265 0 11255 5 11245 0 11243 5 11232 5 11230 0 11225 0 11218 5 11216.0 11212.5 11210.5 11205.5 11202.5 11195.5 11191.5 11189.0 11186.0 11180.5 11174.5 11167.5 11164.0 11161.5 11144.5 11139.0 11130.5 11111.0 11108.0 11101.0 11097.5 11074.5 11068.0 11064.0 11054.5 11051.0 11048.0 11046.0 11439.0 11432.0 11426.5 11423.5 11418.0 11413.0 11395.0 11387.0 11384.5 11381.5 11376.5 11366.0 11356.0 11353.5 11345.5 11335.0 11326.0 11286.5 11283.0 11273.0 11263.5 11254.0 11253.0 11240.5 1123 6.5 11234.0 11226.5 11223.5 11219.5 11218.5 11213.5 11210.5 11203.5 11198.5 11196.0 11193.5 11186.0 11181.0 11176.5 11173.0 11169.5 11153.5 11147.5 11138.0 11119.5 11115.5 11104.5 11099.5 11080.5 11073.5 11071.0 11061.0 11057.0 11055.0 11052.0 13-MAY-1998 09:58 PAGE: 11 LIS Tape Verific~_=on Listing Schlumberger Alaska Computing Center 11039.0 11043.5 11033.5 11041.5 11028.0 11034.0 11023.5 11028.0 11014.5 11018.5 11009.0 11012.5 11006.0 11010.5 10996.5 11002.0 10989.0 10995.0 10986.0 10993.5 10979.5 10986.5 10974.0 10980.5 10972.5 10978.5 10966.0 10971.5 10957.5 10963.5 10951.5 10959.0 10948.0 10953.0 10939.5 10946.0 10937.5 10942.5 10926.0 10929.0 10917.5 10922.0 10911.5 10917.0 10901.0 10905.0 10891.0 10892.5 10886.0 10888.5 10882.5 10886.0 10879.5 10880.5 10870.5 10872.5 10864.0 10865.5 10858.0 10861.0 10847.0 10851.0 10844.0 10848.0 10837.0 10841.0 10819.5 10824.5 10814.5 10818.5 10801.5 10804.5 10796.0 10799.0 10792.0 10794.0 10788.5 10790.5 10776.0 10779.0 10774.5 10776.5 10764.5 10769.0 10760.5 10765.0 10756.0 10759.5 10749.5 10753.0 10742.5 10745.0 10738.0 10742.0 10733.5 10736.5 10728.5 10731.0 10723.5 10726.5 10720.0 10722.0 10708.5 10709.5 10703.0 10704.5 10689.5 10691.5 10682.5 10682.0 13-MAY-1998 09:58 PAGE: 12 LIS Tape Verifi~a~l'on Listing Schlumberger Alaska Computing Center 10675.0 10665.5 10658.5 10656.5 10651 . 0 10643.0 10632.0 10630.0 10623.5 10620.5 10615.5 10609.0 10595.5 10594.5 10590.5 10586.0 10580.5 10578.0 10574.5 10571.0 10564.5 10561.0 10557.0 10550.0 10543.0 10535.5 10531.0 10528.5 10521.5 10506.0 10497.0 10494.5 10487.0 10479.0 10470.0 10466.0 10460.0 10452.5 10445.5 10435.5 10431 5 10423 5 10417 0 10411 5 10408 0 10404 0 10397 0 10394 0 10384 5 10380 0 10373 0 10363 5 10361 5 10358 0 10351 5 10676.5 10668 5 10660 0 10657 0 10652 5 10645 0 10633 0 10630 0 10624 0 10621.0 10616.0 10608.5 10596.5 10595.5 10589.5 10584.5 10580.0 10577.5 10574.0 10569.5 10562.5 10556.5 10554.5 10549.5 10544.5 10533.5 10531.0 10528.0 10522.5 10511.5 10502.5 10499.5 10493.0 10485.5 10475.0 10470.0 10465.0 10457.5 10453.0 10441.0 10435.0 10428.0 10420.0 10416.5 10411.5 10406.0 10400.5 10397.5 10387.5 10383.5 10375.5 10365.5 10364.0 10360.0 10353.5 13-MAY-1998 09:58 PAGE 13 LIS Tape Verific&~=on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 14 10343.5 10340.0 10337.5 10329.0 10325.5 10304 0 10299 5 10296 5 10291 0 10285 0 100 0 $ 10345.5 10342.5 10340.0 10330.5 10327.0 10305.5 10301.0 10296.5 10292.0 10286.0 101.0 REMARKS'. THIS FILE CONTAINS THE VALID DECIMATED AND DEPTH SHIFTED MAIN PASS IES DATA IN CASING. LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 2 3 4 5 66 6 73 7 65 8 68 9 65 11 66 12 68 13 66 14 65 15 66 16 66 0 66 66 0 66 0 73 16 66 1 0.5 FT 64 0 FT 68 1 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NU~3 SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH IES GAPI 189683 O0 000 O0 0 2 1 1 4 68 0000000000 TENS IES LB 189683 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN IES LB 189683 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verifica.==on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 15 ** DATA ** DEPT. 10312.000 GRCH. IES 318.980 TENS. IES -999.250 HTEN. IES DEPT. 10171.000 GRCH. IES 65.419 TENS. IES -999.250 HTEN. IES -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE19I]MBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SU~k4ARY VENDOR TOOL CODE START DEPTH IEL 12395.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 10312.0 02-JAN-98 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 16 SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : JO01 2000 O1-JAN-98 1411 02-JAN-98 12510.0 12397.0 10170.0 12390.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA1V~LA RAY IEL INDUCTION ELECTROLOG $ TOOL NUMBER ........... 1310 0811 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 3. 750 10299.0 10312.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.3 FLUID LOSS (C3): 5.6 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OP~4~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.078 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 126 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 078 MUD CAKE AT (BHT) : FLO PRO 8.80 60.0 60.0 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): RENJkRKS: TOOL STRING RUN WITHOUT CENTRALIZATION DUE TO HOLE SIZE LOG CORRELATED TO SONIC LOG 06-06-91 REPEAT PASS IS FROM DOWN LOG THIS FILE CONTAINS THE RAW MAIN PASS OPEN HOLE DATA CLIPPED AT CASING. $ LIS FORMAT DATA LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 17 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 3 1 1 4 68 COArD IEL M~IHO 189683 O0 000 O0 0 3 1 1 4 68 SN IEL 0~189683 O0 000 O0 0 3 1 1 4 68 SP IEL MV 189683 O0 000 O0 0 3 1 1 4 68 GR IEL GAPI 189683 O0 000 O0 0 3 1 1 4 68 TTEN IEL LB 189683 O0 000 O0 0 3 1 1 4 68 TEN IEL LB 189683 O0 000 O0 0 3 1 1 4 68 SPD IEL F/HR 189683 O0 000 O0 0 3 1 1 4 68 RT IEL OH~4 189683 O0 000 O0 0 3 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 12395.000 COND.IEL 0.000 SN. IEL 0.000 SP. IEL GR.IEL 0.000 TTEN. IEL 3000.000 TEN. IEL -500.000 SPD. IEL RT. IEL 0.000 DEPT. 10312.000 COND. IEL 282.528 SN. IEL 11.631 SP. IEL GR.IEL 445.735 TTEN. IEL 365.484 TEN. IEL -18.472 SPD. IEL RT. IEL 3.539 -80.000 0.000 -11.045 3083.712 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 18 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE · 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~fAugY VENDOR TOOL CODE START DEPTH IEL 12388.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 10312.0 02-JAN-98 JO01 2000 O1-JAN-98 1411 02-JAN-98 12510.0 12397.0 10170.0 12390.0 LIS Tape Verific~L.mon Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 19 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY IEL INDUCTION ELECTROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : TOOL NUMBER 1310 0811 3. 750 10299.0 10312.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: 9.3 FLUID LOSS (C3): 5.6 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.078 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 126 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 078 MUD CAKE AT (BHT) : FLO PRO 8.80 60.0 60.0 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: TOOL STRING RUN WITHOUT CENTRALIZATION DUE TO HOLE SIZE LOG CORRELATED TO SONIC LOG 06-06-91 REPEAT PASS IS FROM DOWN LOG THIS FILE CONTAINS THE RAW REPEAT DOWN PASS OPEN HOLE DATA CLIPPED AT CASING. $ LIS FORMAT DATA LIS Tape Verific~==~on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 20 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 36 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MODNUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 4 1 1 4 68 0000000000 COND IEL t4I~IO189683 O0 000 O0 0 4 1 1 4 68 0000000000 SN IEL 0H~I189683 O0 000 O0 0 4 1 1 4 68 0000000000 SP IEL MV 189683 O0 000 O0 0 4 1 1 4 68 0000000000 GR IEL GAPI 189683 O0 000 O0 0 4 1 1 4 68 0000000000 TTEN IEL LB 189683 O0 000 O0 0 4 1 1 4 68 0000000000 TEN IEL LB 189683 O0 000 O0 0 4 1 1 4 68 0000000000 SPD IEL F/HR 189683 O0 000 O0 0 4 1 1 4 68 0000000000 RT IEL OH~k4189683 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. GR.IEL RT. IEL 10132.500 COND. IEL 0.000 SN. IEL 0.000 SP. IEL 0.000 TTEN. IEL 3000.000 TEN. IEL -500.000 SPD.IEL 0.000 DEPT. GR.IEL RT. IEL 12388.000 COND.IEL 101.535 SN. IEL 6.382 SP. IEL 0.000 TTEN. IEL 3000.000 TEN. IEL -500.000 SPD. IEL 9.849 -80.000 0.000 -13.806 0.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION · O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE · 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER 5 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE StC4~N~RY VENDOR TOOL CODE START DEPTH IEL 10312.0 $ LOG HEADER DATA STOP DEPTH .......... 10164.0 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY IEL INDUCTION ELECTROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 02-JAN-98 JO01 2000 O1-JAN-98 1411 02-JAN-98 12510.0 12397.0 10170.0 12390.0 TOOL NUMBER 1310 0811 3. 750 LIS Tape Verifica~mon Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 22 DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10299.0 10312.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH : 9.3 FLUID LOSS (C3): 5.6 MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0.078 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.126 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 078 MUD CAKE AT (BHT): FLO PRO 8.80 60.0 60.0 60.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: TOOL STRING RUN WITHOUT CENTRALIZATION DUE TO HOLE SIZE LOG CORRELATED TO SONIC LOG 06-06-91 REPEAT PASS IS FROM DOWN LOG THIS FILE CONTAINS THE RAW DATA IN CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 i, LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 23 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 5 1 1 4 68 0000000000 GR IES GAPI 189683 O0 000 O0 0 5 1 1 4 68 0000000000 TENS IES LB 189683 O0 000 O0 0 5 1 1 4 68 0000000000 HTEN IES LB 189683 O0 000 O0 0 5 1 1 4 68 0000000000 CVEL IES F/HR 189683 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10312.000 CVEL. IES 3083.712 DEPT. 10164.000 CVEL.IES 3073.842 GR.IES 445.735 TENS. IES 365.484 HTEN. IES GR.IES 62.229 TENS. IES 379.457 HTEN. IES -18. 472 -16. 801 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION . O01CO1 DATE · 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE . FLIC VERSION · O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verifica~on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 24 FILE HEADER FILE NUMBER 6 RAW CASED HOLE REPEAT PASSES Curves and log header data for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE StC4MARY VENDOR TOOL CODE START DEPTH IEL 10312.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : STOP DEPTH .......... 10132.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANk~ARAY IEL INDUCTION ELECTROLOG $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (OH~4M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHE~ OR THERMAL): MATRIX: MATRIX DENSITY: 02-JAN-98 JO01 2000 O1-JAN-98 1411 02-JAN-98 12510.0 12397.0 10170.0 12390.0 TOOL NOWiBER 1310 0811 3. 750 10299.0 10312.0 FLO PRO 8.80 9.3 5.6 0.078 60.0 O. 126 60.0 0.078 60.0 LIS Tape Verifica~on Listing Schlumberger Alaska Computing Center 13-MAY-1998 09:58 PAGE: 25 HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: TOOL STRING RUN WITHOUT CENTRALIZATION DUE TO HOLE SIZE LOG CORRELATED TO SONIC LOG 06-06-91 REPEAT PASS IS FROM DOWN LOG THIS FILE CONTAINS THE RAW REPEAT DATA IN CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 20 4 66 255 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 51 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 189683 O0 000 O0 0 6 1 1 4 68 0000000000 GR IES GAPI 189683 O0 000 O0 0 6 1 1 4 68 0000000000 TENS IES LB 189683 O0 000 O0 0 6 1 1 4 68 0000000000 HTEN IES LB 189683 O0 000 O0 0 6 1 1 4 68 0000000000 CVEL IES F/HR 189683 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center DEPT. 10132.500 CVEL. IES 0.000 DEPT. 10312.000 CVEL.IES 3593.088 GR.IES GR. IES 13-MAY-1998 09:58 0.000 TENS. IES 145.425 TENS. IES 3000.000 364.435 HTEN. IES HTEN. IES PAGE: 26 -500.000 -14.955 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION · O01CO1 DATE : 98/05/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC TAPE NAME : 98194 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : BP EXPLORATION, P-O3A PB1, PRUDHOE BAY, API# 50-029-22176-01 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/05/13 ORIGIN : FLIC REEL NAME : 98194 CONTINUATION # : PREVIOUS REEL : CO~k4ENT : BP EXPLORATION, P-O3A PB1, PRUDHOE BAY, API# 50-029-22176-01 Sperry-Sun Drilling Services LIS Scan Utility Tue Mar 10 10:20:30 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 80063 S. LAITILA PARKER/WHITL P-03A PB1 500292217670 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 10-MAR-98 MWD RUN 2 AK-MW- 80063 S. LAITILA PARKER/WHITL MWD RUN 3 AK-MW-80063 S. LAITILA PARKER/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 AK-MW-80063 S. LAITILA PARKER/WHITL MWD RUN 5 AK-MW- 80063 S. LAITILA PARKER/WHITL MWD RUN 6 AK-MW-80063 S. LAITILA PARKER/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: MWD RUN 7 AK-MW-80063 S. LAITILA PARKER/WHITL MWD RUN 8 AK-MW- 80063 S. LAITILA PARKER/WHITL 31 TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD liN 13E 2594 2020 91.50 .00 .00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 10252.0 4.500 9977.0 5.500 10674.0 12510.0 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 THROUGH 8 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. GAMMA RAY DATA (SGRD) FROM 12293'MD TO 12483'MD IS MEASURED AFTER DRILLING (MAD) DURING MAD RUN 8. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN DRILLING SERVICES AND BOB METZGER OF BP EXPLORATION (ALASKA), INC. ON 19 FEBRUARY 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12510'MD, 8941'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10280.5 12483.0 ROP 10308.5 12510.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 10309.0 10917.0 2 10917.0 11208.0 3 11208.0 11426.0 4 11426.0 11445.0 5 11445.0 11954.0 6 11954.0 12086.0 7 12086.0 12510.0 8 12320.0 12510.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 12510.5 11395.5 4461 10280.5 GR 19.22 596.28 57.358 4406 10280.5 ROP 11 2474.25 99.2311 4405 10308.5 Last Reading 12510.5 12483 12510.5 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 12510.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10280.5 ROP 10308.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10890.0 10916.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 27-DEC-97 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 10917.0 10309.0 10917.0 35.1 97.4 TOOL NUMBER NGP 53 3.750 3.8 FLO- PRO 8.60 51.0 9.0 27000 6.6 .000 .000 .000 63 .3 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 10916.5 10598.5 1273 10280.5 GR 19.91 596.28 54.9398 1220 10280.5 ROP 16.28 607.76 79.6761 1217 10308.5 Last Reading 10916.5 10890 10916.5 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 10916.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10890 . 0 11181.0 ROP 10917 . 0 11207 . 5 $ LOG HEADER DATA DATE LOGGED: 28-DEC-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.9 MAXIMUM ANGLE: 95.4 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 11208.0 10917.0 11208.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 77 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 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 8.80 109.0 9.0 30000 5.6 .000 .000 .000 .000 60.9 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10890 11207.5 11048.8 636 10890 GR 19.22 87.66 34.9882 583 10890 ROP 32.78 2474.25 128.35 582 10917 Last Reading 11207.5 11181 11207.5 First Reading For Entire File .......... 10890 Last Reading For Entire File ........... 11207.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11180.5 ROP 11208.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11397.0 11423.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet 28-DEC-97 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 11426.0 11208.0 11426.0 83.9 93.1 TOOL NUMBER NGP 77 3.750 3.8 FLO- PRO 8.80 109.0 9.0 30000 5.6 .000 .000 .000 .000 68.0 .3 Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11180.5 11423.5 11302 487 11180.5 GR 26.05 90.84 44.34 434 11180.5 ROP 32.41 883.5 102.482 431 11208.5 Last Reading 11423.5 11397 11423.5 First Reading For Entire File .......... 11180.5 Last Reading For Entire File ........... 11423.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11399 . 0 11417 . 5 ROP 11426 . 0 11443 . 0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP [NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 29-DEC-97 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 11445.0 11426.0 11445.0 .0 .0 TOOL NUMBER NGP 53 3.750 3.8 FLO- PRO 8.70 .0 8.6 31000 7.6 .000 .000 .000 .000 88.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAPI 4 1 68 ROP MWD 4 FT/H 4 1 68 4 2 8 3 Name Min Max Mean Nsam DEPT 11399 11443 11421 89 GR 30.8 38.84 34.4316 38 ROP 11 43.2 25.6994 35 First Last Reading Reading 11399 11443 11399 11417.5 11426 11443 First Reading For Entire File .......... 11399 Last Reading For Entire File ........... 11443 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11417 . 5 11927 . 5 ROP 11444 . 5 11954 . 0 $ LOG HEADER DATA DATE LOGGED: 30-DEC- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 11954.0 11445.0 11954.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OH/~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 87.0 92.7 TOOL NUMBER NGP 77 3.750 3.8 FLO- PRO 8.80 .0 9.0 5.6 .000 .000 .000 .000 98.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 AAPI 4 1 68 4 2 ROP MWD 5 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11417.5 11954 11685.8 1074 11417.5 GR 22.87 359.56 78.385 1021 11417.5 Last Reading 11954 11927.5 ROP 27.03 297.41 87.1202 1020 11444.5 11954 First Reading For Entire File .......... 11417.5 Last Reading For Entire File ........... 11954 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NLrMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11927 . 5 12059 . 0 ROP 11954 . 5 12083 . 5 $ LOG HEADER DATA DATE LOGGED: 30-DEC- 97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.7 MAXIMUM ANGLE: 91.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 12086.0 11954.0 12086.0 TOOL NUMBER NGP 223 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 3.750 3.8 FLO-PRO 8.80 .0 9.0 5.6 .000 .000 .000 .000 3.1 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 75.0 First Name Min Max Mean Nsam Reading DEPT 11927.5 12083.5 12005.5 313 11927.5 GR 25.28 139.7 47.3518 264 11927.5 ROP 27.54 1404 106.08 259 11954.5 Last Reading 12083.5 12059 12083.5 First Reading For Entire File .......... 11927.5 Last Reading For Entire File ........... 12083.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12067 . 5 12292 . 5 ROP 12095 . 5 12510 . 5 $ LOG HEADER DATA DATE LOGGED: 31-DEC-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 92.2 MAXIMUM ANGLE: 98.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 12510.0 12086.0 12510.0 TOOL NUMBER NGP 77 3.750 3.8 FLO- PRO 8.90 .0 MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (0HMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8.5 5.6 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 7 AAPI 4 1 68 4 2 ROP MWD 7 FT/H 4 1 68 8 3 93.0 First Name Min Max Mean Nsam Reading DEPT 12067.5 12510.5 12289 887 12067.5 GR 24.24 263.06 74.9072 451 12067.5 ROP 16.31 1509.2 115.428 831 12095.5 Last Reading 12510.5 12292.5 12510.5 First Reading For Entire File .......... 12067.5 Last Reading For Entire File ........... 12510.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SLrMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12293.0 12483.0 $ LOG HEADER DATA DATE LOGGED: 01-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 94.3 MAXIMUM ANGLE: 99.3 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 12510.0 12320.0 12510.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 223 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 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 8.90 .0 8.5 5.6 .000 .000 .000 .000 93 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 8 AAPI 4 1 Rep Code Offset Channel 68 0 1 68 4 2 Name Min Max DEPT 12293 12483 GR 26.1 143.56 First Mean Nsam Reading 12388 381 12293 47.1633 381 12293 Last Reading 12483 12483 First Reading For Entire File .......... 12293 Last Reading For Entire File ........... 12483 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Reel Trailer Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Mar 10 16:20:29 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 80063 S. LAITILA PARKER/WHITL P-03A 500292217601 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 10-MAR-98 MWD RUN 14 AK-MW-80063 K. ALLEN WHITLOW/MCCU MWD RUN 15 AK-MW-80063 K. ALLEN WHITLOW~MCCU JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 16 AK-MW-80063 S. LATZ PARKER/HILDR 31 liN 13E 2594 2020 ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 91.50 .00 .00 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.625 10252.0 4.500 9977.0 5.500 10674.0 12904.0 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1,14,15 AND 16 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP) . 4. MWD RUNS 2 THROUGH 13 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN DRILLING SERVICES AND BOB METZGER OF BP EXPLORATION (ALASKA), INC. ON 19 FEBRUARY, 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12904'MD, 8959'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10280.5 12877.0 ROP 10308.5 12904.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ EQUIVALENT UNSHIFTED DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 10308.0 10403.0 14 10403.0 11285.0 15 11285.0 12030.0 16 12030.0 12904.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 12904 11592.2 5248 10280.5 GR 20.37 596.28 46.5012 5194 10280.5 ROP 16.28 1913.58 104.199 5192 10308.5 Last Reading 12904 12877 12904 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 12904 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10280 . 5 10403 . 0 ROP 10308 . 5 10403 . 0 $ LOG HEADER DATA DATE LOGGED: 27-DEC-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 35.1 MAXIMUM ANGLE: 97.4 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 10403.0 10308.0 10403.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP 53 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 3.8 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 51.0 9.0 27000 6.6 .000 .000 .000 .000 63.3 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .3 REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 · Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 1 FT/H 4 1 68 4 2 GR MWD 1 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 10403 10341.8 246 10280.5 ROP 16.28 57.88 32.5766 190 10308.5 GR 21.76 596.28 131.883 246 10280.5 Last Reading 10403 10403 10403 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 10403 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10403.5 ROP 10403.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11258.5 11284.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN 12-JAN-98 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 11285.0 10403.0 11285.0 35.1 101.0 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO- PRO 8.90 65.0 8.9 5.8 .000 .000 .000 .000 68.0 .3 Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 First Name Min Max . Mean Nsam Reading DEPT 10403.5 11284.5 10844 1763 10403.5 GR 20.37 288.36 43.6587 1711 10403.5 ROP 25.48 1913.58 109.044 1763 10403.5 Last Reading 11284.5 11258.5 11284.5 First Reading For Entire File .......... 10403.5 Last Reading For Entire File ........... 11284.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA DATE LOGGED: START DEPTH STOP DEPTH 11255.0 12003.0 11284.0 12029.5 13 -JAN- 98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 12030.0 11285.0 12030.0 85.6 93.7 TOOL NUMBER NGP SPC 223 3.750 3.8 FLO- PRO 8.80 65.0 10.0 5.8 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 AAPI 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 Name Min Max Mean Nsam DEPT 11255 12029.5 11642.2 1550 GR 21.43 236.04 42.4724 1497 ROP 42.87 812.53 100.925 1492 First Last Reading Reading 11255 12029.5 11255 12003 11284 12029.5 First Reading For Entire File .......... 11255 Last Reading For Entire File ........... 12029.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12007 . 0 12877 . 0 ROP 12031.0 12904 . 0 $ LOG HEADER DATA DATE LOGGED: 15-JAN-98 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MSC 1.32 NGP 5.74, DEP 2.17 MEMORY 12904.0 12030.0 12904.0 MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 73.5 92.1 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 8.80 65.0 9.5 5.2 .000 .000 .000 .000 77.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 AAPI 4 1 68 4 2 ROP MWD 16 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12007 12904 12455.5 1795 12007 GR 23.7 253.36 40.8641 1741 12007 ROP 29.76 1674 109.016 1747 12031 Last Reading 12904 12877 12904 First Reading For Entire File .......... 12007 Last Reading For Entire File ........... 12904 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility Tue Mar 10 12:46:00 1998 Reel Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/03/10 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MW- 80063 S. LAITILA PARKER/WHITL M C OF LMEg P-03A PB2 500292217671 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 10-MAR-98 MWD RUN 13 AK-MW-80063 B. JAHN SEVCIK/WHITL 31 liN 13E 2594 2020 91.50 .00 .00 OPEN HOLE CASING DRILLERS BIT SiZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 10.755 2703.0 3RD STRING 7.625 10252.0 PRODUCTION STRING 3.750 10604.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL GAMMA RAY DATA (SGRD) IS DOWNHOLE RECORDED. 3. MWD RUNS 1 AND 13 ARE DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP). 4. MWD RUNS 2 THROUGH 12 CONTAIN NO VALID DATA AND ARE NOT PRESENTED. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ROB KALISH OF SPERRY-SUN DRILLING SERVICES AND BOB METZGER OF BP EXPLORATION (ALASKA), INC. ON 19 FEBRUARY, 1998. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10604'MD, 8972'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUM~J~RY PBU TOOL CODE START DEPTH STOP DEPTH GR 10280.5 10576.5 ROP 10308.5 10603.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH MERGED MAIN PASS. BIT RUN NO MERGE TOP MERGE BASE 1 10308.0 10417.0 13 10417.0 10604.0 $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 10603.5 10442 647 10280.5 GR 21.76 596.28 79.5088 593 10280.5 ROP 16.28 1091.8 132.319 591 10308.5 Last Reading 10603.5 10576.5 10603.5 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 10603.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10280.5 ROP 10308.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMIA~ ANGLE: MAXIMUM ANGLE: STOP DEPTH 10417.0 10417.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined 27-DEC-97 MSC 1.32 NGP 5.74, DEP 2.17, DEP MEMORY 10417.0 10308.0 10417.0 35.1 97.4 TOOL NUMBER NGP 53 3.750 3.8 FLO- PRO 8.60 65.0 9.0 27000 6.6 .000 .000 .000 .000 63 .3 .3 Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 AAPI 4 1 68 4 2 ROP MWD 1 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10280.5 10417 10348.8 274 10280.5 GR 21.76 596.28 121.287 274 10280.5 ROP 16.28 67.7 35.8 218 10308.5 Last Reading 10417 10417 10417 First Reading For Entire File .......... 10280.5 Last Reading For Entire File ........... 10417 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/03/10 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SLrMMARY VENDOR TOOL CODE GR ROP $ LOG HEADER DATA START DEPTH STOP DEPTH 10417.5 10576.5 10417.5 10603.5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 09-JAN-98 MSC 1.32 NGP 5.74, DEP 2.17, DEP MEMORY 10604.0 10417.0 10604.0 78.9 108.4 TOOL NUMBER NGP SPC 302 3.750 3.8 FLO-PRO 8.90 65,0 8.9 5,8 .000 .000 .000 .000 65.6 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 SlT~ SIq ~O pu~ ~0~ T~STsZqd SAS ................. squeu~uoo NMONMNfl ........... ~e~ I~H I0 ...... ~equmN uoTqenuTquoo N. 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