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197-064
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 13, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-21B PRUDHOE BAY UNIT P-21B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2024 P-21B 50-029-22148-02-00 197-064-0 N SPT 9000 1970640 2500 438 2754 2703 2676 322 325 327 328 OTHER P Kam StJohn 10/15/2024 2 Year AOGCC CMIT-TxIA per CO 736/Sundry #320-183 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-21B Inspection Date: Tubing OA Packer Depth 591 2755 2691 2670IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241016124316 BBL Pumped:3 BBL Returned:2.8 Friday, December 13, 2024 Page 1 of 1 9 9 9 9 99 999 9 9 9 99 9 9 2LOSURGXFHU ,$UHPHGLDOFHPHQW CMIT-TxIA per CO 736/Sundry #320-183 James B. Regg Digitally signed by James B. Regg Date: 2024.12.13 16:09:46 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 13, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-21B PRUDHOE BAY UNIT P-21B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2024 P-21B 50-029-22148-02-00 197-064-0 N SPT 9000 1970640 2500 424 2743 2627 2592 319 321 321 322 OTHER P Kam StJohn 10/15/2024 2 Year AOGCC MIT-T per CP 769/ Sundry #320-183 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:PRUDHOE BAY UNIT P-21B Inspection Date: Tubing OA Packer Depth 587 666 672 668IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS241016124024 BBL Pumped:1.2 BBL Returned:1.2 Friday, December 13, 2024 Page 1 of 1 9 9 9 99 999 9 9 9 9 9 9 9 2LOSURGXFHU ,$UHPHGLDOFHPHQW MIT-T per CP 769/ Sundry #320-183 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-21B PRUDHOE BAY UNIT P-21B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 P-21B 50-029-22148-02-00 197-064-0 N SPT 9000 1970640 2500 507 2745 2652 2619 192 193 193 193 OTHER P Kam StJohn 10/10/2022 2 year MIT-T to 2500 psi 2750 psi Max as per Sundry 320-183 and CO 736. 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-21B Inspection Date: Tubing OA Packer Depth 395 513 518 510IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221010162101 BBL Pumped:3.1 BBL Returned:3.1 Tuesday, December 13, 2022 Page 1 of 1 1-Oil completion; IA remedial cement squeeze MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp North Slope, LLC P-21B PRUDHOE BAY UNIT P-21B Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/13/2022 P-21B 50-029-22148-02-00 197-064-0 N SPT 9000 1970640 2500 499 2735 2690 2668 192 203 204 204 OTHER P Kam StJohn 10/10/2022 2 year CMIT-TxIA to 2500 psi 2750 psi Max as per Sundry 320-183 and CO 736. 30 MinPretest Initial 15 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-21B Inspection Date: Tubing OA Packer Depth 452 2736 2690 2668IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS221010163258 BBL Pumped:1.6 BBL Returned:1.5 Tuesday, December 13, 2022 Page 1 of 1 2 year CMIT-TxIA to 2500 psi 2750 psi Max as per Sundry 320-183 and CO 736.2 year CMIT-TxIA to 2500 psi 2750 psi Max as per Sundry 320-183 and CO 736.2 year CMIT-TxIA to 2500 psi 2750 psi Max as per Sundry 320-183 and CO 736. Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU P-21B (PTD 197-064) Radial Bond Tool 10/20/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 1970640 E-Set: 34242 Abby Bell 11/13/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU P-21B (PTD 197-064) Radial Bond Tool 10/20/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 1970640 E-Set: 34242 Abby Bell 11/13/2020 MEMORANDUM TO: Jim Regg\ E° � I tI l e'l laz-0 P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P-21 B PRUDHOE BAY UNIT P -21B Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UNIT P -21B API Well Number 50-029-22148-02-00 Inspector Name: Guy Cook Permit Number: 197-064-0 Inspection Date: 10/21/2020 Insp Num: mitGDC201021134227 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well P -21B Type Inj N TVD 8676 - Tubing 406 2750 - 2628 - 2596 - PTD 1970640 Type Test SPT Test psi 2500 IA 620 708 _ 717 716 BBL Pumped: 1.3 BBL Returned: 12 OA 167 169 _ 170_ 170 Interval OTHER P/F P Notes: MIT -T per Sundry 320-183. Testing was completed with a Little Red Services pump truck and calibrated gauges. OOA - 0/0/0/0 Tuesday, November 3, 2020 Page I of 1 MEMORANDUM TO: Jim Regg a l P.I. Supervisor FROM: Guy Cook Petroleum Inspector I Well Name PRUDHOE BAY UNIT P-21 B Insp Num: mitGDC201021134558 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, November 3, 2020 SUBJECT: Mechanical Integrity Tests Hilcorp North Slope, LLC P-21 B PRUDHOE BAY UNIT P -21B Src: Inspector Reviewed By: P.I. Supry a�c— Comm API Well Number 50-029-22148-02-00 Inspector Name: Guy Cook Permit Number: 197-064-0 Inspection Date: 10/21/2020 Tuesday, November 3, 2020 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min J� - "TVD Tubing 2752 -- a- PTD 197060 -_IIYP YP Test SPT �Ietpsi'zsoo IA 9I-�� so 2751 26966�8 L � 'I BBL Pumped: z 9 BBL Returned: 2.9 OA J 167 z16 - 217. zt� Interval OTHER- IP/F l-- P --- - Notes: CMIT-TxIA per Sundry 320-183. Testing was completed with a Little Red Services pump truck and calibrated gauges. OOA - 0/0/0/0 a� Tuesday, November 3, 2020 Page 1 of 1 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:197-064 6.50-029-22148-02-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 13671 12378 9043 10952, 11088 13606 12378, 12432 8664, 8753 Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" 36 - 116 36 - 116 1490 470 Surface 2959 13-3/8" 35 - 2994 35 - 2667 4930 2270 Intermediate 3062 9-5/8" 34 - 3096 34 - 2730 6870 4760 Liner 8994 7" 1440 - 10434 1416 - 8272 8160 7020 Intermediate 11352 5-1/2" 33 - 11385 33 - 8890 7740 6820 Perforation Depth: Measured depth: 11620 - 13510 feet True vertical depth:8960 - 8974 feet Tubing (size, grade, measured and true vertical depth)3-1/2" 9.2# L-80 30 - 11176 30 - 8803 10952, 11088 8664, 8753Packers and SSSV (type, measured and true vertical depth) 3-1/2" Baker SABL-3 Packer Production Liner 2513 3-1/2" 11158 - 13671 8793 - 8953 10160 10530 12. Stimulation or cement squeeze summary: Intervals treated (measured): Pump 13bbls of cement with 11bls of 15.8ppg class 'G' cement behind pipe. Final treating pressure = 547 psi. Final wellhead pressures: Tbg = 250-psi, IA = 250-psi, OA = 175-psi Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 23518171873213 686159 1243 139 189 213 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Aras Worthington aras.worthington@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:(907)440-7692 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured8953 Sundry Number or N/A if C.O. Exempt: 320-183 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 IA Cement Squeeze Operations shutdown Change Approved Program 5 Pump 13bbls of cement with 11bls of 15.8ppg class 'G' cement behind pipe. Field estimated TOC in IA = 9946', estimated BOC = 10919'. Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028264 PBU P-21B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Cement Evaluation By Samantha Carlisle at 1:27 pm, Oct 29, 2020 Digitally signed by Stan Golis DN: cn=Stan Golis, ou=Users Date: 2020.10.29 13:00:55 - 08'00' Stan Golis DSR-11/2/2020 RBDMS HEW 10/29/2020 SFD 11/2/2020 MGR30OCT2020 SFD 11/2/2020 , ADL 028288 ACTIVITY DATE SUMMARY 9/28/2020 ***WELL S/I ON ARRIVAL*** (cement squeeze) PULL PX PLUG FROM X NIP @ 10,969' MD ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 9/29/2020 T/I/O/OO = 260/270/590/Vac. Temp = SI. TBG FL (Fullbore request). ALP = 1880 psi, SI @ CV. TBG FL @ near surface (~80', 0.7 bbls). SV, WV, SSV = C. MV = O. IA, OA, OOA = OTG. 01:30 9/30/2020 ...WELL SHUT IN ON ARRIVAL... (Set Plug and Punch Tubing) SET NORTHERN SOLUTIONS 3-1/2" MILL EZ CBP AT 10,923'. PASSED PT TO 1500PSI. PUNCH TUBING FROM 10,914' - 10,919' AND CONFIRM CIRCULATION ***JOB COMPLETE*** WELL SHUT IN ON DEPARTURE. READY FOR COIL 10/2/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP MIRU. ***Job Continued on 10/3/2020*** 10/3/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP Complete rig up. RIH with 2.800" drift BHA. Tagged CBP at 10909CTM and correct depth to CBP and flag pipe at 10850. Corrected EOP at flag = 10837.92'. Circ tubing over to safelube. POOH. MU & RIH w/cement retainer. Can't get past GLM #5 at 3600ft. POH. RIH & perform FCO from 10920ft using sweep. POH. MU & RIH w/cement retainer. ***Job in Progress*** 10/4/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP Continue RIH w/ cement retainer. Set cement retainer at 10893. Circ out IA with diesel. Pump 13bbls of cement with 11bls of 15.8ppg class 'G' cement behind pipe. TOC in IA is 9946ft, Bottom of cement 10919ft. Reverse out cement down to 10890ft. POH. FP to 1000ft. LD stinger BHA, 1/2" activation ball is missing. Pump 1" drift ball. Change pack offs, Check chains. Cut 100ft of pipe for chrome management. Wait on cement. Make up and RIH with 2.800" 5-blade junk mill. ***Job Continued on 10/5/2020*** 10/5/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP Continue RIH with 2.800" 5-blade junk mill. Begin milling cement & retainer at 10875CTM. Milled through cement and retainer and pushed down to CBP 10909' CTMD. Up wts are ~13k heavier with well clean. SKL-400 +safelube appears to not be working very well. Swap to regular slick 1%KCL/SL and circ well over with hopes of improving PU wts. Wts improved to ~31k, ordered fresh load of regular slick 1%KCL w/SL before resume milling of CBP. Mill CBP and push to SABL-3 Packer at 10936' CTMD. Continue to chase OOH for bit trip to downsize to 2.73" junk mill. RIH with 2.73" milled/pushed CBP to 12434CTM and stacked weight on WRP - not moving. POOH. for logging tools. ***Job Continued on 10/6/2020*** Daily Report of Well Operations PBU P-21B Daily Report of Well Operations PBU P-21B 10/6/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP Continue POOH for logging tools. 2.73" mill is a tight mill gaged at 2.725. Lay down milling BHA, trim pipe. and make up logging tools and venturi with 2.63" mule shoe. Log from PBTD 12427 CTMD, paint flag at 12300', log up to 10500'. POOH. Became detained in SSSV nipple at 2100' with venture for awhile. See log for details. Log shows a +22.5' correction, making corrected EOP at flag = 12311.48'. Decision to re-run a 2.65" DJN drift before setting CIBP. Chrome drag in well significant without safelube. RIH and dry drift to WRP. Pump gel and safelube, and chase to surface. ***Job Continued on 10/7/2020*** 10/7/2020 CTU 9 1.75" CT Job Objective: IA CMT and set CIBP Continue POOH with 2.65" nozzle and chase to surface. Make up and RIH with 3.5" Quadco CIBP BHA. Set CIBP ME at 12378'. PUH and attempt to pump gel sweep and chase OOH. Coil plugged up and pressured to 4300-4400psi. Unsuccessful regaining circulation down coil. POOH. MU nozzle and RIH to 2750' MD / 2500' TVD. Lay in 24 bbls of diesel Freeze Protect. Rig down CTU. ***Job Complete*** 10/11/2020 T/I/O/OOA=0/0/150/0 Freeze Protect Tbg (Post Coil Job) Pump 24 bbls crude down tbg FWHPs=1260/0/150/0 10/19/2020 ***WELL S/I ON ARRIVAL*** BRUSHED / GAUGED TBG 2.70" TO 2.75" X NIPPLE @ 10,969' MD. TIGHT THROUGH PACKER @ 10,952' MD, DID NOT CLEAR UP W/ BRUSHING ACTION. ATTEMPTED TO SET 2.75" XX PLUG @ 10,969' MD. HAD TO JAR THROUGH RESTRICTION @ 10,952' MD. UNABLE TO WORK THROUGH X NIPPLE @ 10,969' MD, AND PRE-SET LOCK. PULLED PRE-SET 2.75" XX PLUG FROM 10,969' MD. ***WSR CONTINUED ON 10-20-20*** 10/20/2020 ***WSR CONTINUED FROM 10-19-20*** DRIFTED W/ 20' x 2.0" TO 10,982' MD. RAN HES GAMMA RAY / CCL / RADIAL BOND TOOLS. MADE PASS FROM 10,952' TO 9862' MD. TOC @ 9860' MD. BRUSHED & FLUSHED RESTRICTION IN PACKER @ 10,952' MD, AND X NIPPLE @ 10,969' MD. (STILL TIGHT THROUGH RESTRICTION). SET 2.75" XX PLUG @ 10,969' MD. MITT 2500 PSI (PASSED). CMIT 2500 PSI (PASSED). ***WSR CONTINUED ON 10-21-20*** 10/20/2020 T/I/O/OO= 250/100/160/0. LRS unit 72 Assist Slickline. Pumped 23 bbls of 94* F crude while they brushed the profile. MIT-T to 2500 psi *PASSED* at 2335 psi. TBG lost 132 psi during the first 15 minutes and 35 psi during the second 15 minutes. Pumped 1.2 bbls of 80* F crude to achieve test pressure. Installed TxIA jumper to equilize pressure. CMIT-TxIA to 2500 psi *PASSED* at 2403 psi. T/IA lost 23/25 psi during the first 15 minutes. T/IA lost 15/16 psi during the second 15 minutes. Pumped 2 bbls of 80* F crude to achieve test pressure. Bled back 3 bbls to Final T/I/O/OO= 240/250/160/0. Daily Report of Well Operations PBU P-21B 10/21/2020 ***WSR CONTINUED FROM 10-20-20*** SET 2.70" WHIDDON CATCHER ON XX PLUG @ 10,969' MD. LRS PERFORMED STATE WITNESSED MITT 2500 PSI (PASSED). LRS PERFORMED STATE WITNESSED CMIT 2500 PSI (PASSED). PULLED DGLV's FROM STA's #3 (8022' MD), #4 (6457' MD), AND #5 (3600' MD). SET INT-LGLV's IN STA# 5 @ 8022' MD, AND STA # 4 @ 6457' MD. ***WSR CONTINUED ON 10-22-20*** 10/21/2020 T/I/O/OO= 400/580/160/0. LRS unit 72 Assist Slickline (CEMENT SQUEEZE). AOGCC (Guy Cook) MIT-T to 2500 psi *PASSED* at 2596 psi (2750 psi max applied pressure). TBG lost 122 psi during the 1st 15 minutes and 32 psi during the 2nd 15 minutes. TBG lost 154 psi during the 30 minute test. Pumped 1.3 bbls of 54* F crude to achieve test pressure. Bled back 1.2 bbls to T/I/O/OO= 414/636/169/0. CMIT-TxIA to 2500 psi *PASSED* at 2666 psi (2750 psi max applied pressure). T/IA lost 62/58 psi during the 1st 15 minutes. T/IA lost 24/25 psi during the 2nd 15 minutes. T/IA lost 86/83 psi during the 30 minute test. Pumped 2.9 bbls of 54* F crude to achieve test pressure. Bled back 2.9 bbls to Final T/I/O/OO= 470/475/170/0. 10/22/2020 ***WSR CONTINUED FROM 10-21-20*** SET 24/64" INT-OGLV IN STA# 3 @ 8022' MD. PULLED CATCHER FROM 10,969' MD. EQUALIZED & PULLED 2.75" XX PLUG FROM 10,969' MD. ***WELL TURNED OVER TO DSO*** Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:197-064 6.API Number:50-029-22148-02-00 PRUDHOE BAY, PRUDHOE OIL BP Exploration (Alaska), Inc 5. Field/Pools:9. Well Name and Number: ADL 028288 & 028264 Property Designation (Lease Number): 10. 8. PBU P-21B 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown IA Squeeze Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 13671 Effective Depth MD: 13Cr80 / L-80 11. May 10, 2020 Commission Representative: 15. Suspended Contact Name: Worthington, Aras J Contact Email:Aras.Worthington@bp.com Authorized Name: Worthington, Aras J Authorized Title:Interventions & Integrity Engineer Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required? Subsequent Form Required: Approved by: COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 3-1/2" Baker SABL-3 Packer Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 8953 Effective Depth TVD:Plugs (MD): Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 10962 / 8671 11088 / 8754 Date: Liner 2513 3-1/2" 11158 - 13671 8794 - 8954 10160 10530 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 36 - 116 34 - 3096 34 - 2730 14. Estimated Date for Commencing Operations: BOP Sketch 35 - 2994 Conductor 7740 Proposal Summary 13. Well Class after proposed work: 3-1/2" Baker SABL-3 Packer 11620 - 13510 8960 - 8974 3-1/2" 9.2#30 - 11176 Liner 12432 9051 12432 None 35 - 2667 2260 9-5/8" 5-1/2" Contact Phone:+1 907 564 4102 Date: 6280 2959 502013-3/8"Surface 4760 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 80 20"36 - 116 470 Intermediate 3062 6870 Intermediate 11352 33 - 11385 33 - 8890 8994 7" 1440 - 10434 1416 - 8272 7240 / 8160 5410 / 7020 Address:P.O. Box 196612 Anchorage, AK 99519-6612 3. No 5Yes Casing Length MD TVD Burst 1490 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. Aras Worthington Digitally signed by Aras Worthington Date: 2020.04.28 12:40:55 -08'00' 320-183 By Samantha Carlisle at 12:57 pm, Apr 28, 2020 10-404 DSR-4/28/2020 SCMT to AOGCC for review before POP. Biennial CMIT-T x IA. X DLB 4/28/2020 MGR30APR20 Yes on Required? Comm. 4/30/2020 dts 4/30/2020 JLC 4/30/2020 Well: P-21 P-21 IA Cement Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Laurie Derrick (907) 564-5952 Expected Start Date May 10, 2020 History P-21B is a 1997 rotary ST. P-21B is a gas lifted, waterflood producer. It has recently become Not Operable due to TxIA communication, confirmed by an Acoustic LDL to be from a production packer leak. On 02/20/2020 an MITT to 2500 psi passed, but the CMIT TxIA failed due to the packer leak. Current status The well is classified as Not Operable and is secured with a plug. Objective Well P-21 was found to have a packer leak at ~10,950’ MD. By repairing this well with an IA cement squeeze, it is estimated that an incremental 445 mbo can be produced over the next several years. Without an IA remedial squeeze, the well has no utility in the foreseeable future. The proposed TOC in the IA is ~9850’ MD which is ~5100’ TVD deeper than the surface casing shoe. BP does not currently have a top of UG4 pick for this well but given the depth of the TOC we are confident we are well below the UG4 top. Post-Job Evaluation x CMIT TxIA and MITT x SCMT to locate TOC Long-Term Integrity Monitoring x Record WHPs daily. x Biennial CMIT TxIA and MITT. 5 Slickline 1. Pull TTP E Line/Fullbore 1. Set CBP in tubing near packer. 2. Punch tubing just above CBP and confirm circulation TxIA. Coil Tubing 1. Set cement retainer above tubing punch. 2. Pump cement down CT taking returns from the IA to bring TOC in IA up to ~9850’ MD. 3. MU Motor and 2.80” Mill. 4. Mill through Cement, Retainer, and CBP. Push remnants to bottom. Slick Line/Fullbore 1. Set TTP. 2. CMIT TxIA to 2500 psi. MITT to 2500 psi. 3. Run SCMT to locate TOC in IA. 4. Pull TTP. Integrity Engineer 1. Add Biennial CMIT TxIA and MITT to Anncomm. SCMT to AOGCC for review. Pump 15.8 ppg and ~14 bbls (we lay 1-2 bbls on top of the retainer and then circulate it out). 2 CurrentWellbore: Packer Leak 0.5 BPM @ 1100 psi 3 TOC in IA ~9850’MD P-21 Proposed 4 P-21 Proposed P&A Reservoir Cement Plug Surface Cement Plug AOGCC will require cement acrosss all annuli at surface casing shoe. �r 0 - • O 0) 4_, � � 0 � � < o ) r � _Y > U N U7 , . a_ V > Cr u 0J c0 X co. . . . . O rN a a O o r- v y IF O to 0 O o O. u n ° . Q C O 0 0 iZS El in N ro O Q 0 W .- .- ,- ' ate--, (i) YO ate-'2k • Cm Vi 0: Q Q Q E y C C as O J' 0) 0) 0) 0) E C7 cv to Q co N fn Q W W -O �- > .J CO Q� M N M W 1- (6 >, Q I-4) Y O• 'a O >. • L0 ! .c , O- G O ] 0 • N J J J J J J Cia 11J ill L11 LL1 LL1 lli 0.0 O o O >-*1 I- LL LL LL LL LL LL tz+ Cl.) E a N o Q J J J J J J Q O c OJ CO 1- 0 0 0 Q Q Q c Z0)0 Col < Z Z Z Z Z Z LL LL LL LL LL LL 0) C U `J 6 L O O CU• - v o 0 c_- ,-. U z C 0 _0 v o v O O a @ a v w U U Q N t > .0cc) �� . w i+ L. O w J I- J O J iCO cooo W -10Ce� m \ N ri F. U O S cc ,�4 4) m w a) .� > PQ U m w W o v 0 4) 0 � �a Z1 e � y:, W0 >- >-Wg >- - a O J J O O J 1 Zi M u.. N W W W w E 2 Q ' f IS y 00 W 10 ttoo tto ttoo toCO Cl) L00303 m m m Z co O O O O O j . C L .0 L L a a a a a a 0) r W 7 = 7 3 7 3 v LL a a a a LL a `o ra o ..) 0.0 O. ..tu a co v co 40 cc X `n °u y.,,, a ', -O O O 0 0 0 0 /�;vy 0 0 0 0 0 0co MOM 4� M M E NU C C 4 V U t..) U C.) l]1.0.1 > cere > xen v c in to ra 1,4I;$ O N (V O + 0 0 0 0 0 0 N N N N Co V 0) C or ... t[) tD N CObo E 0 CO Co in M n N0 N N- O 0 r4 N N N N N U QN m 0CNI 0 OCNI T O O o,_Q1 0 0 0 0 0 0 - OO O O O O in t() )n N )n rr) 3 OJ OD Q u c E QJ 5cu co .) L.) _ CD L`W 'e w °C L- G • 11��� Q t`Q.) co CO CO p co Y E VI H OD M Z N �' N Nas _j d Q N W O el) li E Z OJ co v L c v 443 `�' It. c a a 0 COD a to d �: I- STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 0 Change Approved Program ID • Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: $Cj kiR 1" 6E YT1 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 197-064 ' 3. Address: P.O.Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-22148-02-00+ 7. Property Designation(Lease Number): ADL 0028264 . 8. Well Name and Number: PBU P-21B a 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13671 feet Plugs measured 12432 feet RECEIVED true vertical 8953 ' feet Junkmeasured SEP feet 2 5 2 015 Effective Depth: measured 12432 feet Packer measured 11114.54 feet true vertical 9051 feet Packer true vertical 8768.87 feet A®3 C Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface 2959 13-3/8"68#NT-80 36-2995 36-2667 5020 2260 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11620-11640 feet 11660-11900 feet 11934-12241 feet 12260-12360 feet 13150-13200 feet 13220-13290 13310-13370 feet 13380-13510 feet True vertical depth: 8960-8964 feet 8967-9001 feet 9001-9022 feet 9025-9040 feet 9043-9034 feet 9030-9016 9012-8999 feet 8997-8974 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.2#L-80 30-11202 30-8816 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: ) t O 7 201 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 467 465 2109 1697 192 Subsequent to operation: Shut In 1240 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations WI Exploratory ❑ Development E Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q , Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,44,yder Garry R(Wipro) .yam Title PDC Principal Engineer Signature (43.(-47. ---- �L✓. Phone +1 907 564 4424 Date 9/25/15 Form 10-404 Revised 5/2015 112" �� � RBDMS EP 2 9 2015 Submit Original Only m .o 0 0 0 0 0 co co r,_ NN O N O V Cf) N- U 1) 0 0 0 0 0 0 0 L C) N N- V CO O 7 0 N- CO N ' O CO Cf7 N- CO N- 00 ("D I� N- O N- N CO CO O CO O N- `— CO O I� CO N 00 `— N 00 N I- 00 CO ▪ 1 1 1 1 1 1 1 H CO I- CO CO CO C[) — O O CO CO CO CO t CO CO N- ice+ ON CO CO 09 M M O O -t O N N ,= N CO 0 CVS V I I I i CO QN CO COC�) (0 N- 0 O /s CO CO CO CO CV CO Ca °' • CO O co 0 0co O CO = Z J J CO CO O pp CV E N N oM � Cn � � � N cj Cf) 6 Ch cr)t Cr) CCS O CO C7 Ln C) N ' CO N- W W W Et H a)0 - - CE— W00 U U W W coD < 22 U w a Z Z W W W W m ODF- HZZD UcnZZJJ � . 0 • Packers and SSV's Attachment PBU P-21B SW Name Type MD TVD Depscription P-21B PACKER 1447.62 1422.87 7" Baker ZXP Packer P-21B TBG PACKER 11114.54 8768.87 3-1/2" Baker SABL-3 Packer P-21B PACKER 11158.42 8793.48 3-1/2" BAKER CPH PACKER • 0 E U = C 2 °' Q a) j Q --% C u) as c y 10 uo) N u) c Q CS cOO .= OQU Q� N0 pDOOM LIN - d C )I C4- - u) 1' O 0) C -, r-- c X0 o cC OY CO as D E co O 0 c) io Q 6 Q ' _N V CO V) U C 7 `- N I O M N o_'O -O OLc) .fl_-co O C co 0_a C LC) c ' a3 U' O ca co o -c coZ -p co co O co o ,— X N O To O �— E = eL E co 73 0 `— _Q O Z o E E X o co. I-- 1 Q L O -O N • L .� O '' ,— (13 c a) C ~ O rn as C 1 O a. Q ao _Jrna U -6 mE a) oa) O O 0 °- a) 0 � OL o O as m E ao _o (a Q ci _ O o u> ~ N E co p O m OQ .OO - O73 — v-- 2 2 c 2 c -p O a) N a) a) c15 m 3 «s a) CO ~ a)Clim oo E �- .-1) ) u) N Q dco u) kE - Q p DO v * Q O O '-C D O CN O N k CO 0_ 0: 1._ ,6,-. a ow eW a � = a , 1� L OL co = Q T * • C CO K )aa)Q V ry 1 * a) # m k 03 'k O Q K\ 1_7 0 CD C) C) m Lo v,m I m Lo C6 (0 a`) _c -0 _c tri io N o Ce NO � � NUrn - O= coo 0 - NU � .fl Qc Q oc� co 0 O >` � p o °' � ptr � O E °' � LL � � � _� � rnH W I— v) o = cr) _ a > co4- aao U rn - > U (U U Md N .LOO > +�ON O n OLo C (13 O L • w CO ,.- O a) O Eo "C '. 0 VN d O lb C c , 0 — � va � 0 -0 cn L -0 0a � vN 0 � a _ •gUa) � _ m c a) c m a) c 3 a) c O c\1 (u ,� c a) __ I- ( a) co > c co > :c a) N , OO co > •O • ~ 4 -0 .., � > o 2 * o D o o O Q a) oC Q c o * aoo O 3 0o O 2 L O 4 ooi E , = o H — U H -0 U O C- co a) L *, H .0 U N m C (a *, H -0 N- ui O .V c) O0 O0 O 3 � ao : UOQ � � 5 -a o_: O0ci — d () Lo W I- 0 >- co CD CD co I— N N N N fl ti IC) 5 I-- aco O O m M � = O 0) O ai U Q lk TREE= ativ • S NOTES: WELL ANGLE>70°@ 11371' *" WEACTUATOR FMC 3-1/2CI-ROME TUBING'*` ' ACTUATOR= BAKER C NTWL KB.ELE 92.4' BF.ELEV= 3808' I L ) .. 51' H7"x 5-1/2"XO,ID=4.892" KOP= 900 1440' —9-5/8"X 7"BKR TACK SLV,10=7.50" Man Angle= 103`6-1i3-2-& _ Datum MD= 11116' 1447' H9-5/8"X 7"BKR ZXP PKR D=6.188" Datum TV O= 8800'SS 1453' H 9-5/8"X 7"BKR HMC HGR,D=6.188" Minimum ID =2.74" @ 11163' 3-1/2" MILLED XN NIPPLE I I 2100' —{3-1/2-HES XKW,0=2.813" 13-318"CSG,68#,NT-80,13=12.415" H 299T -A , 9-5/8"CSG,47#,L-80,D=8.681_—I —3146 — 9-5/8"MLLOUT WINDOW(P-21B) 3096'-3146' GAS LFT MANDRELS 3 - ST MD TVI) DEV TYPE VLV LATCH FORT DATE 5 3600 3088 40 KBG-2-9 COME NT 16 04/19/14 7"LNR 26#,L-80 BTC,.0383 bpf,ID=6.276" — 9279' ---->< ?C 4 6457 5241 41 KBG-2-9 DOME NT 16 04/19/14 3 8022 6442 39 KBG-2-9 SO Nf 24 04/19/14 2 9557 7606 40 KBG-2-9 DMY 141 0 04/06/08 7"LNR 29#,L-80 BTC,,0371 bpf,D=6.184" — 10434' —J h, 1 10745 8510 40 KBG2-9 DMY NT 0 04/06/08 I I 10929' —3-1/2"I IS X NP,ID=2.813" El Er 10952' H 5-1/T X3-1/2"BKRSABL-3 FKR,ID=2.78" 3-1/2"TBG,9.2#,13CR VAM TOP — 11022' .0087 bpf,113=2.992" \ , , -10969' —3-1/2"HES X NIP,D=2.75" 3-1/2-TBG STL6(04!052"08) H 11024 r 1 11031' —UNIQUE OVERSHOT FBFFORATION StMAARY REF LOG TCP PERF I r 1107T H 3-1/2"FES X MP,D=2.75" ANGLE AT TOPFIBRF:78°@ 11620' S t9 11088' H5-1/T X 3-1/2"BKRSABL-3,A<R,ID=2.78" Note:Refer to Production OB for historical pert data 11143' —13-1/2"HES X NP,D=2.75" SCE SPF NTERVAL Opn/Sgz SHOT SQZ 2-1/8" 4 11620-11640 0 06/03/97 2-1/8" 4 11660-11900 0 06/03/97 11158' —5-1/2"x 3-1/T BKR CFH PKR 2-1/8" 4 11934-12241 0 06/03/97 ' w/HMC LW?HGR D=2.943" 2-1/8" 4 12260-12360 0 06/03/97 11 2-118" 4 13150-13200 C 06/03/97 1 11163' H 3-1/T IES XN NCP MLLED TO 2.74"(09/10/15) 2-1/8" 4 13220-13290 C 06/03/97 1 T 2-1/8" 4 13310-13370 C 06/03/97 11176' --{3-1/2"WLEG,ID=2.992" 2-1/8" 4 13380-13510 C 06/03/97 k 12437 —13-1/2"WET WRP(09/10/15) 3-1/T TBG,9.3#,L-80, .0087 bpf,D=2.992" H 11176' i 104 5-1/2"CSG, 17#,L-80 STL/FL4S, —I 11385' .0232 bpf, ID=4.892" PBTD H 13606' 3-1/2"LN2,9.2#,L-80 NSCT,.0087 bpf,D=2.992" — 13671' ,^8�, 13671' --I FISH-FASDRLL MLLED&RUSH TO BTM(04/21/08) DATE REV BY COMMENTS DATE REV BY COMvENTS PRUGHOE BAY UNIT 04/15/91 ORIGINAL(SUSPI 1)EE)) 03/07/14 BSE/JMD GLV C/O(02124/14) WELL: P-21B 05/01/96 RIG SIDETRACK(P-21A) 04/28/14 WKFVJM0 GLV GO(04/19/14) PERMT No: 1970640 06/05/97 RIG SIDETRACK(P-21 B) 09/14/15 SRB/JMD MLL XN NP/SET WRP(09/10/15) AR No: 50-029-22148-02 04/09/08 N3S RWO Sec.31,711N,R13E,2260'FSL&2019'FWL 05/13/08 7/TLH PLUG MILLED&PUSH TO BIM 07/27/09 FR/JM? DRLG DRAFT CORRECTX)NS BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 22, 2011 RE,CENE Mr. Tom Maunder , U 3 01 Alaska Oil and Gas Conservation Commission Gov issiog 333 West 7 Avenue et & Gag Cam' �' Anchorage, Alaska 99501 Ab Anchstso Subject: Corrosion Inhibitor Treatments of GPB P -Pad q 7 Dear Mr. Maunder, �—` Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB P- I 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: 07121/11 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 -01 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 -21 B 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 OS/05/09 • ~~ ~l~e!l~~1~~~1-~~~ NO. 5329 P~laska Data & Consulting Services ~<, a;;4' ~ ~ ~ ' *•~n~' ~ ~~ ~ ~ ~~~~~, ,- ~ ~ ~; ?. ~.' ~ Ui:,.- Company: State of Alaska 2525 Gambell Sereet, Sui4e 400 Alaska Oil & Gas l'ons Comm ,~nchorage, A0~ 99503-283a Attn: Christine Mahnken ~'~~' Be~h 333 West 7th Ave, Suite 100 Anchorage, AK 99501 lMell Job # Log Description Date BL Color CD ~ P-21 B AWJ1~00039 MEM PROD PROFILE 07/14/09 1 1 P2-12 AXWS-00013 PRODUCTION PROFILE °r 07l12/09 1 1 C-36A AY1 M-00017 IBP SET RECORD W/CROSSFLOW ~ 07/OS/09 1 1 W-45 AXBD-00035 MEM TEMP & PRESS SURVEY ..- c 07/09/09 1 1 H-13A B2NJ-00009 MCNL _. L G( L 06/17/09 1 1 ~ F-081# AY1M-00028 RST - G 07/01/09 1 1 01-18 AY3J-00038 CH ED T P C TBG PUNCH/JEWELRY lOG 07/10/09 1 _.. '-~ ~ D G lI ~[A1 CANC 11l~Vw1A\IIII _ -- '__ "_""'_ _"e~s~.~ ..~~~.. . .... v.v~.....v ~~~v ~~a.~ v~~~~~~~v v1~L vvr ~ Lf1VIl i V. BP Exploration (Alaska) Inc. Petrotechnica~ Data Center LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Servic;es 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ~ • STATE OF ALASKA ~~s ~„,. C,> ~ ~ ~ ~ ~ ALA IL AND GAS CONSERVATION COMM N REPO OF SUNDRY WELL OPEONS MAY 1 6 ~u0is A ~....~,., na Q r_ac i^.nnS_ Commissipn 1. Operations Performed: At1ChOf8~2 ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory ~ 197-064 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22148-02-00 7. KB Elevation (ft): ~, 89 5T 9. Well Name and Numb P BU P-21 B 8. Property Designatio 10. Field /Pool(s): ADL 028264 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 13671' " feet true vertical 8953' ~ feet Plugs (measured) None Effective depth: measured 13606' feet Junk (measured) 13603' true vertical 8961' feet Casing Length Size MD ND Burst Collapse Structural Conductor 110' 20" 110' 110' 1490 470 Surface 2959' 13-3/8" 2997' 2669' 5020 2270 Intermediate 3059' 9-5/8" 3096' 2730' 6870 4760 Production Liner Liner 8994' 7" 1440' - 10434' 1416' - 8272' 7240 5410 Liner 11385' 5-1/2" 11385' 8890' 7740 6280 Liner 2513' 3-1/2" 11158' - 13671' 8793' - 8953' 10160 10530 Perforation Depth MD (ft): 11620' - 13510' Perforation Depth TVD (ft): 8960' - 8974' 3-1/2", 9.2# / 9.3# 1 3Cr80 ! L-80 11161' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 5-1/2" x 3-1/2" Baker'SABL-3 packer; 10952'; 5-1/2" x 3-1/2" Baker'SABL-3' perm. packer 11088' 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~(~,~ ~~+~ ~ ~ 2~0~ Treatment description including volumes used and final pressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 131 77 1,898 1,600 300 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Frank Roach, 564-4373 N/A Printed Name Terrie Hubble Title Drilling Technologist O Prepared By Name/Number: ~ Signature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 ~~IGINAL R~~~s ~<<~t ~ ~~ Submit Original Only '' 733 Digital Well File • Page 1 of 1 • Well: P-21 Well History Well Date Summary P-21 B 3/10/2008 ***WELL SHUT IN ON ARRIVAIL ****** (RWO PREP) PULL PXN PLUG FROM 11151' MD DRIFT W/ 2.60" BELL GUIDE/S.BAILER(em t ), SAT DOWN C~ 11,763 SLM. TARGET FOR QUIK- ***WELL TURNED OVER TO DSO*** P-21 B 3/12/2008 Assist E-Line (Pre-RWO). Rig up. P-21 B 3/12/2008 ***WELL SHUT IN ON ARRIVAL*** INITIAL T/I/O/00 = 200/200/120/0 PSI RIG UP E-LINE FOR 4 RUN JOB. RUN 1:SET 2.550" BAKER QUIK DRILL PLUG AT 11550' LRS BE IN I. ***JOB CONTINUED ON 13-MARCH-2008*** P-21 B 3/13/2008 T/I/O/00= 40/200/100NAC. Temp= SI. Assist E-Line CMIT-TxIA PASSED to 3500 osi.(Pre-RWO) Pumped 24 bbls of 50* crude into the IA to achieve test pressure. T/I lost 40/60 psi 1st 15 mins, T/I lost 20/0 psi 2nd 15 mins for a total of 60/60 psi in 30 mins.. Bled pressures WHP= 60/100/100/0. Annulus casing valves are open to gauges. P-21 B 3/13/2008 ********CONTINUED FROM PREVIOUS DAY********* 3.5" COMPOSITE PLUG SET AT 11550' AND PRESSURE TESTED BY LRS TO 3500 PSI. RIH WITH TUBING PUNCHER AND STRING SHOT FOR CHEM CUTTER PREP. . CUT 3.5" TUBING WITH 2-5/8" CHEMICAL CUTTER AT DEPTH = 11046' *****JOB COMPLETE LEAVE LOCATION WELL SHUT IN***** P-21 B 3/13/2008 ***CONTINUED FROM 12 MAR 08*** RIH WITH 2' TUBING PUNCH AND SHOOT AT FROM 11032'-11034'. 9 HOLES SHOT. POOH RIH WITH STRING SHOT FOR CHEM CUTTER PREP. SHOOT STRING SHOT FROM 11038' TO 11050'. POOH. RIH WITH 2-5/8" CHEMICAL CUTTER. CUT 3.5" TUBING AT DEPTH = 11046'. POOH. BOTTOM HALF OF CHEMICAL CUTTER HEAD (OD=2.62") AND COLLAPSABLE BOTTOM CENTRALIZER (L=20.38"') LEFT IN HOLE AFTER CUT. OVERALL LENGTH OF FISH = 26.63". 2.62" SEVERED CHEMICAL CUTTING HEAD IS LOOKING UP HOLE. PERFORMED MAN-DOWN &WELL CONTROL DRILL. FINAL T/I/O/00 = 60/160/240/0 ***JOB COMPLETE*** P-21 B 3/15/2008 *** WELL S/I ON ARRIVAL *** (fish) TOOK IMPRESSION OF LOWER SECTION OF CHEMICAL CUTTER W/ 2.50" LIB C~? 11133' SLM. RECOVERED CHEMICAL CUTTER FROM 11,130'SLM. *** TURN WELL OVER TO PAD OPERATOR -LEFT WELL SHUT IN *** P-21 B 3/15/2008 T/IA/OA=300/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RWO) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite caps. Cycle and torque LDS "Standard style" all functioned no problems PPPOT-IC RU 2 HP bleed tools onto IC test void 100 psi to 0 psi. Pressured to 3500 psi for 30 minute test, 3500/ 15 minutes, 3450/ 30 minutes. Bleed IC void to 0 psi, RD test equipment re installed Alemite cap. Cycle and torque LDS "ET style" all functioned no problems P-21 B 3/17/2008 T/I/O/00= 420/360/300/0 Temp= SI Circ-Out TxIA (Pre RWO) Pumped 5 bbls meth spear folowed by 170 bbls 1% KCL down Tbg thru jet cut C~ 11046' up IA thru hard line jumper to FL. *** Job continued on 3-18-08 WSR*** P-21 B 3/18/2008 *** Job continued from 3-17-08 WSR*** Circ-Out TxIA (Pre RWO) Pumped 151 bbls 1%KCL (336 total) down Tbg thru jet cut C~ 11046' up IA taking returns thru hard line jumper to flowline. Freeze protected TxIA w/ 50 bbls diesel, U-tubed for 1 hr. Freeze protected Flowline and jumper line w/ 10 bbls meth. MIT-OA FAILED to 2000 psi (3 attempts) Pressured up OA w/ 1.5 bbls diesel. OA lost 60 psi in 1st 15 min and 40 psi in 2nd 15 min for a total loss of 100 psi in 30 min test. Bleed pressures to 0 psi. Final WHPs 0/0/0 ( IA/OA/OOA casing valves open to gauges, IA/OA tagged, swab shut needle valve open at time of departure) P-21B 3/22/2008 T=O; Set 4-1/16" CIW "H" BPV thru tree; 1-2' ext. used, tagged ~ 102" ***Complete*** (Best/Wortham) P-21 B 3/22/2008 T/I/O/00 = 400/400/100/vac. Temp = SI. Bleed WHP's to 0 psi for BPV (pre RWO). TBG FL ~ surface. IA FL near surface. OA FL @ surface. Bled TBG & IA simultaneously to 0 psi in 5 min. SI, monitored for 30 min. TBG & IAP increased to 0+ psi. Bled OAP to 0 psi in 5 min. SI, monitored for 30 min. OAP increased to 10 psi. Final WHPs = 0+/0+/10/vac. Print Date: 5/14/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/Wllnfo/Reports/ReportViewer.aspx 5/14/2008 • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: P-21 Common Well Name: P-21 Spud Date: 3/20/1991 Event Name: WORKOVER Start: 3/24/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task I! Code NPT Phase Description of Operations 3/24/2008 18:00 - 20:00 2.00 MOB P PRE Rig down floor and derrick. Scope down and lower derrick. 20:00 - 22:30 2.50 MOB P PRE Rig down modules, blow down and unhook steam and water 22:30 - 00:00 I 1.50 I MOB I P 3/25/2008 100:00 - 01:00 I 1.00 I MOB I P 01:00 - 06:00 ~ 5.00 ~ MOB ~ N 06:00 - 08:00 2.00 MOB N 3/30/2008 00:00 - 02:30 2.50 MOB P 02:30 - 03:30 1.00 MOB P 03:30 - 07:00 3.50 MOB P 07:00 - 17:30 10.50 MOB P 17:30 - 00:00 6.50 RIGU P 3/31/2008 100:00 - 03:00 3.00 RIGU P 03:00 - 06:00 I 3.001 RIGU I P 06:00 - 07:00 I 1.001 WHSUR I P 07:00 - 11:00 I 4.001 WHSUR I P 11:00 - 13:00 I 2.001 WHSUR I P 13:00 - 15:30 I 2.501 WHSUR I P 15:30 - 00:00 ~ 8.50 ~ WHSUR P 4/1/2008 100:00 - 01:00 I 1.001 BOPSUR P 01:00 - 06:00 I 5.001 BOPSUR P 06:00 - 08:00 I 2.001 BOPSUFI P lines. Unhook electrical between modules. PRE Move pipeshed and pit modules to end of pad. Move carrier off of MPI-15. Pick up herculite and move BOP cradle. PRE Move off of MPI pad down track 14 road. Broke drive shaft on carrier between MPI and MPH pads. PRE Remove broken driveline from carrier. Hook truck onto carrier and tow it to MPH pad. Work on carrier drive line. PRE Drive line repaired. Decision made to move to MPF-Pad to do RWO there. PRE Blow down and rig down for move. PRE Scope down and lay over derrick. PRE Jack up carrier and pipe shed, move carrier off MPF-50 ~ 05:00, load and stage rig components for move to GPB P-pad. PRE PJSM w/ Truck crew, move Rig, Camp and all components to GPB P-pad, cross Kuparuk River C«~ 16:00 hrs, Rig on location C~? 17:30 hrs. PRE Spot Camp, lay mats and herculite for carrier, spot carrier over Well with WSL present X21:00 hrs, spot pits and pipe shed, install handi-berm. Called AOGCC for 24 hour notice of BOPE testing. Left message with no response. PRE Raise and scope up derrick ~ 01:00 hrs, RU lines, hand rails and landings, handi-berm. Spot Tiger tank in berm and RU. Rig t d ~ 03:00 hrs. PRE RU hardline to Tiger tank and test to 500 psi, test hardline to 1500 psi to closed choke. PUMU lubricator, test to 500 psi w/ diesel. DECOMP State waived right to witness BOPE test (John Crisp). Pull BPV. T / IA / OA / OOA pressures of 0 psi. BOLD lubricator. Rig up to tree with tree cap pump in sub. DECOMP Pressure test lines to Tiger Tank to 500 psi, test hardline to closed choke to 1500 psi, ok. Open well and circulate 1%KCL down tubing taking returns from the IA thru choke to tiger tank. Pump ~ 4 BPM, 670 psi and 400 Bbls total. 50 Bbls of diesel and 1 %KCL returns. DECOMP Flow check, well dead. Dry rod TWC. Test from above to 3500 psi, from below to 1000 psi and chart both tests. Blow down all lines. DECOMP ND Tree. Blew hydraulic hose on sweeney. KSAR and HACL and use hammer wrench to break out studs. Lay down tree. Check hanger threads w/ 4 1/2" TDS, 9 1/2 Turns. Threads are in good condition. DECOMP I~IU BOPE. Lou Grimaldi called C~ 16:30 hrs and requested 1 hrs notice to witness BOPE test. NU choke and kill lines, flow riser, hook up accumulator hoses, function test BOPE, replace API-ring in Kill line unibolt, service valves. DECOMP Service valves for BOPE test. John Crisp with AOGCC wavied witness of BOPE test ~ 00:50 hrs. DECOMP Testin BOPE er BP / AOGCC Regulations to 250 psi low and 3,500 psi high. Test the Annular to 3,500 psi. Test w/ 3 1/2" test joint. Accumulator draw down test complete. DECOMP Crew change. All test complete except 2 7/8" test joint and Printed: 4/21/2008 1:12:23 PM • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: P-21 Common Well Name: P-21 Spud Date: 3/20/1991 Event Name: WORKOVER Start: 3/24/2008 End: 4/9/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABORS 3S Rig Number: Date From - To .Hours Task Code II, NPT I' Phase Description of Operations 4/1/2008 06:00 - 08:00 2.00 BOPSU -- P DECOMP equipment. BOPE test 2 7/8" equipment to 250 / 3500 psi. 08:00 - 12:30 4.50 PULL P DECOMP PUMU new Kelly, swivel, upper and lower kelly cock, and kelly bushing. MU but not tighten or test. 12:00 Kelly in air and installing rollers in bushing. 12:30 - 14:30 2.00 WHSUR P DECOMP PUMU 7" shootin ni le & lubricator, test to 500 si, ull TWC, UD nipple & lubricator. 14:30 - 16:00 1.50 PULL P DECOMP PUMU landing joint, FMC teck BOLDS, IA=O psi, OA=O PSI, PU control line spooler rig floor, Pulled 135 K on 3-1/2" tbg strin unsuccessful, consult with Engineer in town, pulled 155 K with no success, call SWS a-line unit. LD landing joint. 16:00 - 21:00 5.00 PULL C DECOMP RD flow riser & Annular flanged air-boot, remove bottom section of rotary table pollution pan (cut bolt off with saw-all). 21:00 - 23:00 2.00 EVAL C DECOMP PU/NU 13 5/8" x 7" Otis shooting flange on annular BOP. 23:00 - 00:00 1.00 EVAL C DECOMP PJSM with a-line crew, RU SWS a-line equipment. 4/2/2008 00:00 - 04:30 4.50 EVAL C DECOMP RU SWS, lubricator ext and W/L BOP, test to 500 psi, OK. PJSM with a-line crew, MU jet cut tools. 04:30 - 06:30 2.00 EVAL C DECOMP RIH with 2.5" Jet cut tool on E-line. 06:30 - 07:00 0.50 EVAL C DECOMP Correlate the Jet cutter run to the existing jewelry in the well - the X Nipple, Packer and X Nipple below it. Tie-in the correlation pass to the log from the previous attempt at chemically cutting the Tubing. Observe the first cut attempt on the CCL at 11,047'. CCL to Jet Cut = 6.2' putting the stop depth at 11,042.8' to put the jet cut depth at 11,049' (2' below the revious attem t . Good surface indication of detonation with the current peaking and about 50K tension loss on the line. 07:00 - 09:00 2.00 EVAL C DECOMP POOH with the jet cutter assembly. 09:00 - 10:00 1.00 EVAL C DECOMP ND the 13-5/8" x 7" Otis Connection Shooting Flange. 10:00 - 11:00 1.00 PULL C DECOMP NU the Flow Riser and Air Boots with Drip Pan. 11:00 - 12:30 1.50 PULL P DECOMP PU the 3-1/2" Landing Joint and screw into the Hanger with 11 turns - OK. MU TIW Valve. Pull the Hanger to the Floor with a PUW = 105K. Finish RU Spooling Unit and unload remaining E-line tools from the Pipe Shed. 12:30 - 13:00 0.50 PULL P DECOMP Perform mini-safety stand down with Alaska Drilling and Wells HSE Adviser, RWO Superintendent, Wellsite Leader, Toolpusher and Rig Crew. Topics discussed included personal safety, increased incident rate across GPB and continuous improvement. 13:00 - 14:30 1.50 PULL P DECOMP Break out and lay down the Tubing Hanger. Break out the TIW Valve and lay down the Landing Joint. Change out elevators to 3-1/2" Tubing elevators. 14:30 - 00:00 9.50 PULL P DECOMP POOH with existing 3-1/2" NSCT and EUE 8rd Tubing Completion laying down in the Pipe Shed and spooling up the control line. Maintain continuous hole fill while POOH. Pre-tour checks at crew change. RD control line spooler at 19:30 hrs. Recovered 34 SS bands and all control line was recovered. 150 jts out ~ 00:00 hrs. Hole loss = 0 bbls. 4/3/2008 00:00 - 09:00 9.00 PULL P DECOMP Continue POH laying down 3-1/2" tubing completion, maintain k t of BSTXi" GLM 4130 Material ~ -7021'. The Joints after the 3rd GLM out of the hole (-8650') were coated with a thin layer of scale on the OD of the Pipe. The ID of the Pipe had evidence of scale as well but not as much as the OD. The Joints #'s are Printed: 4/21/2008 1:12:23 PM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: P-21 P-21 WORKOVER NABOBS ALASKA DRILLING I NABOBS 3S Hours Task ~I Code ' NPT Start: 3/24/2008 Rig Release: 4/9/2008 Rig Number: Page 3 of 6 Spud Date: 3/20/1991 End: 4/9/2008 Date I From - To 4/3/2008 00:00 - 09:00 9.00 PULL P 09:00 - 10:00 1.00 PULL P 10:00 - 11:30 1.50 CLEAN P 11:30 - 13:30 2.00 CLEAN P 13:30 - 18:00 4.50 CLEAN P 18:00 - 21:30 3.50 DHB P 21:30 - 00:00 2.50 BOPSU P 4/4/2008 00:00 - 02:00 02:00 - 04:30 04:30 - 09:00 09:00 - 10:00 10:00 - 11:00 11:00 - 11:30 11:30 - 12:00 12:00 - 13:00 13:00 - 22:30 22:30 - 00:00 2.00 BOPSU P 2.50 WHSUR P 4.50 BOPSU P 1.00 BOPSU P 1.00 WHSUR P 0.50 CLEAN P 0.50 CLEAN P 1.00 CLEAN P 9.50 CLEAN P 1.50 CLEAN P Phase ~ Description of Operations DECOMP 274 - 293 out of the hole. After Joint 293 the scale was no longer evident. DECOMP On surface with cut Joint of Tubing. The jet cut was clean and not flared out much. The cut Joint length = 12.61'. Recovered a total of 346 Joints and 5 GLM Assemblies. Clear and clean Rig Floor. DECOMP Bring all 2-7/8" PAC handling equipment to the Rig Floor. Bring all the BHA components to the Rig Floor. RU 2-7/8" Handling Equipment. Wrap the wellhead with Herculite and apply steam in preparation for packoff changeout. DECOMP PU and MU BHA #1 as follows: Dress Off Shoe, Washpipe Extension, Washpipe Extenstion, (3-3/4" x 2-7/8" Dress Off Mill inside), Triple Connection Top Sub, Double Pin Sub, XO, 5-1/2" Scraper, XO, Junk Basket, Junk Basket, Bit Sub, Pump Out Sub and (6) ea 3-1/8" Drill Collars. OAL = 207.44'. The total footage of wash over capability = 11.62'. DECOMP TIH with BHA #1 on 2-7/8" PAC DP picking up from the Pipe Shed 1 x 1. DECOMP PJSM, perform pre-tour checks at crew change, PUMU RTTS with Storm Valve, (top of tool) set C~ 121' Tested to 1,000 psi for 10 charted min. Good test. DECOMP PJSM with FMC rep. Drain BOP and blow down lines, ND riser, kill & choke lines, LOTO accumulator and disconnect hoses. Monitor OA continuously while ND/NU operations. The two tested barriers are the Baker Quik Drill in the 3-1/2" Liner at 11,550' and the RTTS with Storm Valve at 121'. DECOMP BOP set back, tubing spool removed. Recover one SS band from well head. Total recovered is 35. DECOMP PJSM with FMC rep, NU new, FMC New standard tubing spool with seconda ackoff. Packoff and spool tested to 4,300 psi for 30 min. DECOMP Remove lower 13 5/8" spacer spool from BOP, NU BOPE. NU Choke and Kill Lines and Accumulator Lines. NU Flow Riser. Function test BOPE. DECOMP Set Test Plug. PUMU 3-1/2" Test Joint. Fill the Stack with water and pressure test the body break to 250 / 3,500 psi against the Annular and Test Plug for 5 charted mins each. DECOMP LD Test Joint. Pull Test Plug and set 7" ID Wear Ring. DECOMP RIH with Halliburton BITS and Storm Valve pulling tool on 4 Joints of 2-7/8" PAC from the Derrick. Having trouble getting completely into the valve. DECOMP MU TIW and Headpin and come online with the mud pump at 2 bpm. Wash down and attempt to clean out any debris /junk that may be preventing us from getting into the valve. Attempt several times and finally got in. DECOMP Screw into the RTTS with 18 turns to the right. Open the TIW valve and check for pressure -well is dead. POH with RTTS and Storm Valve with a PUW = 35K. Break out and lay down the Packer. DECOMP TIH with BHA #1 on 2-7/8" HT PAC DP from the Pipe Shed 1 x 1. Crew change and perform pre-tour checks (160 joints ran) 18:00 hrs. Ran 270 joints @ 22:30 hrs. DECOMP Remove DP elevator and bails from blocks, put oil into swivel, Printed: 4/21/2008 1:12:23 PM ~ ~ BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: P-21 Common Well Name: P-21 Spud Date: 3/20/1991 Event Name: WORKOVER Start: 3/24/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task I Code ~ NPT Phase Description of Operations ~ _ __ 4/4/2008 22:30 - 00:00 - 1.50 CLEAN P DECOMP PU and tighten connections on kelly. 4/5/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Tighten XO's and lower kelly valve. 01:00 - 03:30 2.50 BOPSU P DECOMP Presure test 250 / 3,500 psi, upper and lower kelly valves for 5 charted min. Had to replace isolation valves on test pump. 03:30 - 04:00 0.50 CLEAN P DECOMP Blow down kelly and test lines, set back kelly, RU bails and elevators. 04:00 - 08:00 4.00 CLEAN P DECOMP Continue TIH with BHA #1 on 2-7/8" HT PAC DP from the Pipe Shed 1 x 1, from joint # 270 to joint # 303 ~ 05:30. Work the Scraper a couple of times on Jts #342 and 343 across the estimated packer setting area (10,917' - 10,980'1. 08:00 - 09:00 1.00 CLEAN P DECOMP a 23' in on Joint #344 = 11 024' 3SMD. Lay down Joint #344. PUMU 2-7/8" HT PAC pin x 3-1/2" IF box XO. PUMU 5' and 10' 3-1/2" IF Pup Joints. RD Elevators off of Bails. 09:00 - 10:00 1.00 CLEAN P DECOMP PU and MU Kelly to the 3-1/2" IF Pup Joints. PUW = 125K , SOW = 75K. Break circulation and notice a leak in the fitting from the standpipe hose to the swivel. Shut down pump and re-tighten the fitting. 10:00 - 13:00 3.00 CLEAN N DECOMP Attempt to break circulation again and the fitting is still leaking. Lay down the 3-1/2" IF Pup Joint and 3 singles of 2-7/8" HT PAC. Lower the Kelly to the Rig Floor and swap out the fitting with a new one. Pick up the 3 singles and Pup Joint and MU to the string. 13:00 - 14:00 1.00 CLEAN P DECOMP Break circulation at a rate of 2.25 bpm with 950 psi. Engage Rotary Table at 20 RPM with RW = 98K and 500 ft-Ibs of torque. RIH and tag the top of the Tubing Stump 7' in on the Kelly = 11,024'. Dress off the flare on the Stump and begin swallowin the Stump down to 18' in on the Kell 11' of Tag and stack weight and dress off 0.5' with Baker rep. POH off the Stump and shut down rotation. Re-tag the top of the Stump 8' in on the Kelly (1' deeper putting the top of the Stump at 11,025' 3SMD). Slide the shoe over the Stump twice without rotation - OK. Shut down the pump and slide the shoe over the Stump once with no problems. 14:00 - 16:00 2.00 CLEAN P DECOMP Break circulation at a rate of 2 bpm / 960 psi with a 26 bbl hi-vis sweep. Pump 50 bbls to get the sweep on the backside. Slowly pull out of the Stump and increase the rate to 4 bpm / 2,660 psi to chase the sweep out of the well. Pumped a total of 260 bbls until the sweep cleaned up. Very little shavings noticed on the magnets and in the sweep. 16:00 - 17:00 1.00 CLEAN P DECOMP Shut down the Pump. Slide over the Stump a couple more times without pumping or rotating - OK. Blow down and set back the Kelly in the Shuck. Break out and lay down the two 3-1/2" IF Pup Joints and XO. 17:00 - 00:00 7.00 CLEAN P DECOMP TOH with BHA #1 laying down the 2-7/8" HT PAC in the Pipe Shed. Filling the hole every 10 Joints out of the hole. Got word from Halliburton rep that there was another SS band on top of the RTTS when they broke it down at the shop which gives us a total of 36 recovered out of 37 bands originally run. 230 joints UD at 00:00 hrs. 4/6/2008 00:00 - 01:30 1.50 CLEAN P DECOMP Continue POH LD 2-7/8" PAC DP, from joint # 230 to joint # 260 01:30 - 02:30 1.00 CLEAN P DECOMP PU and make breaks on kelly. 02:30 - 07:00 4.50 CLEAN P DECOMP Continue UD 2-7/8" PAC DP from joint # 260 to joint # 315 at Printed: 4/21/2008 1:12:23 PM • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: P-21 Common Well Name: P-21 Spud Date: 3/20/1991 Event Name: WORKOVER Start: 3/24/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours Task ~~ Code NPT Phase Description of Operations 4/6/2008 02:30 - 07:00 4.50 CLEAN P DECOMP 05:30 hrs. 07:00 - 08:00 1.00 CLEAN P DECOMP On surface with BHA #1. Break down and lay down components with Baker rep. Recovered about 1 gallon of scale /cuttings in the Junk Baskets. The lip on the shoe and the polish mill on the inside of the washpipe both had good indications of dressing off on the Tubing. 08:00 - 08:30 0.50 WHSUR P DECOMP BOLDS and pull Wear Ring. 08:30 - 10:30 2.00 CLEAN P DECOMP Break out XO's and lay down the Kelly and XOs. Lay down the Kelly Shuck. 10:30 - 13:30 3.00 BUNCO RUNCMP PU and load the Stabbing Board in the Pipe Shed. PJSM. PU and RU the Stabbing Board in the Derrick. Load the Pipe Shed with the new 3-1/2" Vam Top Tubing to strap and tally. 13:30 - 17:30 4.00 BUNCO RUNCMP Load the Pipe Shed with the remaining Joints of 3-1/2" Vam Top Tubing. Remove thread protectors and strap and tally the Joints. 17:30 - 21:00 3.50 BUNCO RUNCMP RU the Nabors Casing Tools and Equipment. Continue loading and strapping the new Joints of 3-1/2" Vam Top. Baker rep on location and check all jewelry prior to picking up. Overshot swallow = 9.2' and bottom of overshot to shear pins = 5'. 21:00 - 21:30 0.50 BUNCO RUNCMP PJSM held with Baker rep and Nabors Casing crew. 21:30 - 00:00 2.50 BUNCO RUNCMP PU / RIH 3-1/2", 9.2 #, 13Cr, Vam Top completion. (Unique overshot, 1 Jt of Tubing, X nipple, Baker SABL-3 packer, X nipple, 1- GLM). Bakerlok all connections below the packer. Used Nabors Casing service and torque turn all connections to Optimum torque of 2,900 ft/Ib, Max torque = 3,190 ft/Ib, Min = 2,610 ft/Ib. Used Jet Lube Seal Guard thread compound on all connections above packer. 10 joints ran at 00:00 hrs. 4/7/2008 00:00 - 18:00 18.00 BUNCO RUNCMP Continue to run 3-1/2", 9.2#, 13Cr, Vam Top Completion from joint # 10 to joint # 80 at 05:30 hrs. Utilizing Jet Lube Seal Guard on all connections. Using stabbing guide and compensator and starting all connections by hand. Torque Turning the connections to an optimum make up torque of 2,900 ft-Ibs. 180 Joints in at 11:30 hrs. 260 Joints in at 16:30 hrs. 286 joints in at 18:00 hrs. 18:00 - 18:30 0.50 BUNCO RUNCMP Rig service and perform pre-tour checks. 18:30 - 21:30 3.00 BUNCO RUNCMP Continue to run 3-1/2" Cr completion from joint #286 to joint # 344. Saw the top of the Tubing Stump 7' in on Joint #344 = 11,025' 3SMD, then saw the shear pins 12' in on Joint #344. It took about 10K to shear the pins. Continue sliding over Stump and stacked out on no-go with 10K 16' in on Joint #344. 21:30 - 22:30 1.00 BUNCO RUNCMP Space out with Baker Production rep. POH and LD joint # 344-#343-#342, MU two pup joints, 9.87' and 9.82' and ran joint #342 on top (of pups). 22:30 - 00:00 1.50 BUNCO RUNCMP PU tubing hanger to rig floor and MU to landing joint and circulating assembly. 4/8/2008 00:00 - 01:00 1.00 BUNCO RUNCMP RD Nabors casing tools. 01:00 - 06:00 5.00 BUNCO RUNCMP Take on seawater in pits. Reverse circulate 165 bbls down the IA at 2 bpm 330 psi with 140 deg F seawater. 2 bpm maximum rate through the Packer per Baker Production rep. Reverse circulate 125 bbls of 140 deg. F inhibited seawater down the IA at 2 bpm 330 psi. 06:00 - 06:30 0.50 BUNCO RUNCMP Pre-tour checks and service the Rig. Drain the BOP Stack. 06:30 - 07:30 1.00 BUNCO RUNCMP PUW = 105K ,SOW = 68K. Land Tubing Hanger and RILDS Printed: 4/21/2008 1:12:23 PM • • BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: P-21 Common Well Name: P-21 Spud Date: 3/20/1991 Event Name: WORKOVER Start: 3/24/2008 End: 4/9/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/9/2008 Rig Name: NABOBS 3S Rig Number: Date I~~, From - To '', Hours ~I, Task Code NPT Phase Description of Operations 4/8/2008 06:30 - 07:30 1.00 BUNCO RUNCMP with FMC rep. Drop the ball and rod with Baker Production re . 07:30 - 09:30 2.00 BUNCO RUNCMP Found some drips on the downstream line of the mud pump where the Micro Motion is plumbed in. Blow down and work on the connections. 09:30 - 13:30 4.00 BUNCO RUNCMP Close the Blind Rams and line up down the Kill Line to pump down the Tubing. Pressure up to 4,500 psi to set the Packer and maintain for 30 mins. Extend the time on the test 15 mins to show stabilization er Anchora a En ineerin - ood test. Bleed the Tubing to 1,600 psi. Pressure up on the IA to 3,500 psi for 30 mins. Marginal test, consult with Anchora e Engineering, decision made to bleed to 0 psi and re-pressure up and start the test again. Pressure up to 3,500 psi and test for 30 charted mins - OK. Bleed the IA to 0 psi and the Tubing to 0 psi. Pressure up on the IA and shear the DCK-3 Valve with 2,200 psi. Circulate in both directions with 0.5 bpm to confirm the valve sheared. 13:30 - 14:00 0.50 WHSUR P RUNCMP PU T-bar and set 4" Type "H" TWC with FMC rep. 14:00 - 16:00 2.00 WHSUR N RUNCMP Attempt to test the TWC. Found leaking valves on the mud/circulation manifold on the Rig Floor. Break out the valves and test with the test hose and test pump to 3,500 psi. Replace bad valves with new ones and grease. 16:00 - 17:00 1.00 WHSUR P RUNCMP Pressure test TWC to 3,500 psi from above and 1,000 psi from below Hold each test for 10 minutes on the chart Good lest`., 17:00 - 20:30 3.50 BOPSU P RUNCMP Remove riser, turnbuckles, choke line, kill line and koomey hoses. Nipple down BOP stack and N/U spool on bottom of stack. Lay BOP stack over into cradle. 20:30 - 00:00 3.50 WHSUR P RUNCMP N/U adaptor flange and tree. Test hanger void to 5,000 psi for 30 minutes. Good test. Fill tree with diesel and test to 5,000 psi. Good test. 4/9/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP R/U DSM lubricator, test to 500 psi. Pull TWC and R/D lubricator. 01:30 - 03:30 2.00 WHSUR P RUNCMP R/U Little Red and test lines to 3,500 psi. Pump 50 bbls of 80 degree diesel freeze protect down IA taking returns out the tubing. Had to pressure up to 2,200 psi to reshear DCK-3 valve. Pump 1.25 bpm at 500 psi. 03:30 - 04:30 1.00 WHSUR P RUNCMP Line up and U-tube diesel freeze protect from IA to tubing. 04:30 - 05:30 1.00 WHSUR P RUNCMP P/U T-bar and set 4" type H BPV with FMC wellhead tech and test from below to 1,000 psi for 10 minutes. Good test. 05:30 - 06:00 0.50 WHSUR P RUNCMP Secure cellar and tree, remove secondary annulus valve. "" Rig Released at 06:00 hours "' Printed: 4/21/2008 1:12:23 PM TREE= 4-1/16" CNV WEL4HG4D = FMC ACTUATOR = AXELSON KB. ELEV = 65.95' BF. ELEV = 38.08' KOP = 900' Max Angle = 103 @ 13324' Datum MD = 11116' Datum TV D = 8800' SS DRLG i. ~ T 7" x 5-1/2" XO SAFETY NOTES: WELL ANGLE> 70 DEG @ 11371' 8<> 90 P -Z ~ B o~'~HROM E T BG*** 143 -tTOP OF BKR TIEBACK SLV, ID = 7.50" 1447' 9-5/8" X 7" BKR ZXP PKR, ID = 6.188" 1453' 9-5/8" X 7" BKR HMC HGR, ID = 6.188" 2100' 3-1/2" HES X NIP, ID = 2.813" 13-3/8" CSG, 68#, NT-80, ID = 12.415" ~~ 2997' Minimum ID = 2.635" @ 11151' 3-1 /2" HES XN NIPPLE PERFORATION SUMMARY REF LOG: TCP PERF ANGLE AT TOP PERF: 78 @ 11620' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 4 11620 - 11640 O 06/03/97 2-1/8" 4 11660 - 11900 O 06/03/97 2-1/8" 4 11934 - 12241 O 06/03/97 2-1/8" 4 12260 - 12360 O 06/03/97 2-1/8" 4 13150 - 13200 O 06/03/97 2-1/8" 4 13220 - 13290 O 06/03/97 2-1/8" 4 13310 - 13370 O 06/03/97 2-1/8" 4 13380 - 13510 O 06/03/97 3-1/2" TBG, 9.2#, 13Cr-80, .0087 bpf, ID = 2.992" ~-~ 11031' I TOP OF P & A CMT PLUG GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3600 3088 40 KBG-2-9 DOME INT 16 04/11/08 4 6457 5241 41 KBG-2-9 SO INT 20 04/11/08 3 8022 6442 39 KBG-2-9 DMY INT 0 04/06/08 2 9557 7606 40 KBG-2-9 DMY INT 0 04/06/08 1 10745 8510 40 KBG-2-9 DMY INT 0 04/06/08 9-5/8" CSG MILLOUT WINDOW 3096' - 3146' (OFF CMT PLUG) 10929' 3-1/2" HES X NIP, ID = 2.813" 10951' 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.78" 10969' 3-1/2" HES X NIP, ID = 2.75" 10434' 7" LNR, 26/29#, L-80 SHOE 11022' UNIQUE MACHINE OVERSHOT 1 11065' 3-1/2" HES X NIP, ID = 2.75" 11081' 5-1/2" X 3-1/2" BKR SABL-3 PKR, ID = 2.78" 11130' 3-1/2" HES X NIP, ID = 2.75" 11151' 3-1/2" HES XN NIP, ID = 2.635" 9-518" CSG, 47#, L-80, ID = 8.681" ~-~ 12402' ~ ~~~a 5-12" X 3-1/2" BKR CPH PKR/HMC HGR W! TIEBACK SLV, ID = 2.943" 11158' 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 11162' 5-1/2" CSG, 17#, L-80, ID = 4.892" 11: I DEBRIS: FASDRILL MILLED & PUSH TO BTM (04/21/081 PBTD 3-1/2" LNR 9.2#, L-80, .0087 bpf, ID = 2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS 04/15/91 ORIGINAL (SUSPENDED) 04/11/08 /TLH TTP PLUG PULLED/FASDRIL SET 05/01/96 RIG SIDETRACK (P-21A) 04/18/08 KJB/TLH GLV GO (04/11/08) 06/05/97 RIG SIDETRACK (P-216) 05/13/08 ???/TLH PLUG MILLED & PUSH TO BTM 01/27/02 CHIKAK CORRECTIONS 04/09/08 N3S RWO 04/09/08 /TLH CORRECTIONS 3-1/2" WLEG, ID = 2.992" ~ 13603' 13606' PRUDHOE BAY UNIT WELL: 8216 PERMfT No: 1970640 API No: 50-029-22148-02 3019' SNL & 2987' WEL, Sec. 31, T11 N, R13E BP Exploration (Alaska) STATE OF ALASKA 11/14!07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig Rep.: G.Sweatt/R.Bjorhus Operator. Bp Rep.: J.Menke/D.Rhodes Field/Unit & Well No.: GPB P-21 B Operation: Drlg: Test: Initial: x Test Pressure: Rams: 250/3500 Rig No.: 3S DATE: 4/1/2008 Rig Phone: 659-4487 Rig Fax: 659-4486 Op. Phone: 659-4485 Op. Fax: 659-4658 PTD # 1970640 Workover: x Explor.: Weekly: Bi-Weekly Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 1 NA Housekeeping: P Dri. Rig P Lower Kelly 1 NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 2 P BOP STACK: Quantity Size Test Result CHOKE MANIFO LD: Annular Preventer 1 i 3 518 5000 P Quantity Test Result Pipe Rams 1 2 7/8 X 5 P No. Vabes 13 P Lower Pipe Rams 0 NA Manual Chokes 1 P Blind Rams 1 Bfind F Hydraulic Chokes 1 P Choke Ln. Valves 1 3 118" 5000 F HCR Valves 2 3 1/8" 5000 P ACCUMULATOR SYSTEM: Kill Line Valves 1 2 1/16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3000 P Pressure After Closure 1600 P MUD SYSTEM: Usual Test Alarm Test 200 psi Attained 28sec P Trip Tank P P Futl Pressure Attained 150sec P Pit Level Indicators P P Bfind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 2000 Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 6 Hours Comaonents tested Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superv~er at: Remarks: Tested with 3 1/2" and 2 7/8" test ioints. Tested 31/2" and 2 7/8" !BOP and BaA safety valves. 24 HOUR NOTICE GIVEN YES x NO Date 03/30/08 Time 18:OOHrs Test start 01:OOHrs Finish BOP Test (for rigs) ~` ~ ~~~~ BFL 11/14/07 ~~~~ ~~'Y ~" By Jon Witness Rick Nabors 3s BOP Test GPB P-21 B.xls oN OR BEFORE C..LOi~_lg~ILM.D OC P E RM I T DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 97-064 DGR/NGP-MD 97-064 DGR/NGP-TVD 97-064 MWD SRVY 97-064 8097 97-064 BHC/SL 97-064 PIL 97-064 SSTVD 97-064 CN/LDT 97-064 CN 97-064 7823 10-407 j10804-13671 ~'/8555- 8954 j~SPERRY 3100-13671 ~3',6-13 SPERRY MPT/GR ~ 11100-13090 1100-13090 11100-13090 11100-13-62 .~11100-13036 ~CHLUM DTE/BCS/SDN/CNTG FINAL 09/03/97 FINAL 09/03/97 08~28/97 09/10/97 FINAL 09/29/97 FINAL 09/29/97 FINAL 09/29/97 FINAL 09/29/97 FINAL 09/29/97 1 09/29/97 ops T0 Are dry ditch samples required? yes ~>3%nd received? Was the well cored? yes ~'~}>J~alysis & description received? Are well tests required? .yes (h~ Received? Well is in compliance Initial COMMENTS T D BOX 9/24/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11375 Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) LIS Well Job # Log Description Date BL RF Sepia Tape H-37 PB1 ~ "~'~.'~ 97413 PEX-AIT, BHC 970717 1 H-37 PB1 9741 3 PEX-AIT 970717 I 1 H-37 PB1 9741 3 PEX-MCFL/MICROLOG 970717 I 1 H-37 PB1 97413 PEX-CNL/GR 970717 1 1 H-37 PB1 97413 PEX-LDT/CNL 970717 1 1 H-37 PB1 9741 3 PEX-BHC SONIC 970717 1 1 H-37 PB1 97413 PEX-BOREHOLE PROFILE/CALIPER 970717 1 1 H-37 Pa1 97413 SSTVD 970717 1 1 H-37 PB1 97413 CBT 970719 1 1 'P-21B ~ '"] ~ ~)~ 97320 DTE/BCS/SDN/CNTG 970522 1 P-21B 97320 PHASOR INDUCTION 970522 1 1 P-21B 97320 CNL 970522 I 1 P-21B 97320 CNL/LDT 970522 I 1 P-21B 97320 BCS 970522 I 1 P-21B 97320 SSTVD 970522 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 R CE V .D Received by: SEP 2 9 997 AJask~ Oil & Gas Cons. OF:IICI_lNG ~ E R V' I l'" E ~; WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - September 10, 1997 P-21B, AK-MM-70116 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. AP1//: 50-029-22148-02. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska September 3, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs P-2 lB, AK-MW-70153 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this of this transmittal letter to the attention of~ Yma Galvin, Sperry-Sun Drilling Services, 5631' Silverado Way, #G, Anchorage, AK 99518 P-21B: 2"x 5"MD Gamma Ray Logs: 50-029-22148-02 2" x 5" TVD Gamma Ray Logs: 50-029-22148-02 1 Blueline 1 Rev Folded Sepia 1 Blueline 1 Rev Folded Sepia RECEIVED S£P 0 ~ 199"/' ~jaska C41 & Gas Cons, Commissi~¢ /~chorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ORIGINAL ALASKA OIL AND GA8 CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned I~ Service 12. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-64 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22148-02 i4. Location of well at surface F' ....... C0&SPLFT!C;,'...?]- ...... ] ' _il~l~.~ i~-~ 9. Unit or Lease Name 2260' NSL, 2019' EWL, SEC. 31, T11N, R13E ;.,.--, .ii ~ m~mm~l~.~ Prudhoe Bay Unit At top of productive interval i ~ ~!'~¢ i 10. Well Number 916' NSL, 3878' WEL, SEC. 36, T11N, R12E j ~,/-,.~'~,,z¢_,~_ ~ J P-21B At total depth ! ~ I I 11. Field and Pool 2843' NSL, 4442' WEL, SEC. 36, T11 N, R12E [._=%. ---- Prudhoe Bay Field / Prudhoe Bay i5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 89.57'I ADL 028264 12. Date Spudded4/27/97 113' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °ffsh°re 16' N°' °f C°mpleti°ns5/26/97 6/5/97 N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13671 8954 ETI 13606 8962 ET1 ~]Yes E~No (Nipple) 2005' MD 1900' (Approx.) 22. Type Electric or Other Logs Run MWD/LWD, GR, RES, Phaser, LDT, CNL, Sonic, LDL 23. CASING~ LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.65# H-40 Surface 110' 30" 280 cu ft Arctic Set (Approx.) 13-3/8" 68# NT-80 38' 2997' 17-1/2" 4217 cuft Permafrost 9-5/8" 47# NSCC 37' 3096' 12-1/4" 3025 cuft Class 'G' 7" 26# / 29# L-80 1440' 10434' 8-1/2" 213 cu ft Class 'G' 5-1/2" 17# L-80 52' 11385' 6" 314 cuft Class 'G' 3-1/2" 9.2# L-80 11158' 13671' 6" 230 cuft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-1/8" Gun Diameter, 4 spf 3-1/2", 9.3#, L-80 11161' 11088' MD TVD MD TVD 11620' - 11640' 8961' - 8965' 11660' - 11900' 8968' - 9002' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11934' - 12241' 9002' - 9023' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12260' - 12360' 9026' - 9041' Freeze Protect with 42 Bbls of Diesel 13150' - 13200' 9044' - 9035' 13220' - 13290' 9031' - 9017' 13310' - 13370' 9013' - 9000' 13380' - 13510' 8998' - 8975' 127. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 17, 1997I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAs-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED !OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. EC VED AUG 28 ~997 ~.OJi ,& Gas Cons. C;0mmiss~or- ........ , ~chorage ., . Form 10-407 Rev. 07-01-80 Submit In Duplicate '29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Shublik 11318' 8867' Shublik 'B' 11410' 8899' Shublik 'C' 11462' 8916' Top of Sadlerochit 11615' 8960' HOT 12436' 9052' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that,t~e~,~r~nd correct to the best of my knowledge Signed Pan Stoltz ~,,~,,¢'//f_,¢~,~7~'/~--'-'~ ' Title Senior Drilling Engineer Date ~/Z ~) ,J P-21~'~ 97-64 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GEU':RA'-' 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. ITED 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 2?: 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 Facility Date/Time 23 Apr 97 24 Apr 97 25 Apr 97 26 Apr 97 27 Apr 97 PB P Pad Progress Report Well P-21B Page 1 Rig Doyon # 9 Date 22 July 97 02:00-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-15:00 15:00-18:00 18:00-21:00 21:00-21:30 21:30-00:00 00:00-00:30 00:30-01:30 01:30-03:30 03:30-06:00 06:00-08:30 08:30-09:00 09:00-13:00 13:00-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-16:30 16:30-18:00 18:00-20:00 20:00-20:30 20:30-21:00 21:00-21:30 21:30-23:30 23:30-01:00 01:00-01:30 01:30-03:00 03:00-06:00 06:00-12:00 12:00-12:30 12:30-22:00 22:00-00:00 00:00-00:30 00:30-01:00 01:00-02:30 02:30-04:00 04:00-05:30 05:30-06:00 06:00-07:30 07:30-08:30 08:30-09:00 09:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-22:00 22:00-00:30 00:30-01:00 01:00-01:30 01:30-03:30 Duration 4hr 3hr 3hr 1/2 hr 2-1/2 hr 3hr 3hr 1/2 hr 2-1/2 hr 1/2 hr lhr 2hr 2-1/2 hr 2-1/2 hr 1/2 hr 4hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 1-1/2 hr 2hr 1/2 hr 1/2 hr 1/2 hr 2hr 1-1/2 hr 1/2 hr 1-1/2 hr 3hr 6hr 1/2 hr 9-1/2 hr 2hr 1/2hr 1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr 1/2hr 2hr lhr 1/2 hr lhr 1-1/2 hr 7hr 2-1/2 hr 1/2 hr 1/2 hr 2hr Activity Rig moved 50.00 % Rig moved 100.00 % Installed BOP stack Held safety meeting Rigged up All functions Tested All functions Rigged up Flowline Rigged up Kelly Set Bridge plug at 1500.00 ft with 0.0 psi Held safety meeting Set Bridge plug at 2000.00 ft with 0.0 psi Worked stuck pipe at 2000.00 ft Worked toolstring at 1500.00 ft Pulled Dfillpipe in stands to 0.00 ft Removed Drillstring handling equipment Ran Drillpipe to 3350.00 ft (5in OD) Held safety meeting Circulated at 3350.00 ft Pulled Drillpipe in stands to 0.00 ft ~Ran Drillpipe in stands to 3350.00 ft Circulated at 3350.00 ft Pulled Drillpipe in stands to 0.00 ft Installed Bridge plug Circulated at 3300.00 ft Tested Casing - Via string Circulated at 3300.00 ft Pulled Drillpipe in stands to 0.00 ft Installed Casing cutter Held safety meeting Ran Drillpipe in stands to 3086.00 ft Functioned Casing cutter Functioned Casing cutter Held safety meeting Functioned Other sub-surface equipment Circulated at 3146.00 ft Held safety meeting Cleared Flowline Pulled Drillpipe in stands to 1000.00 ft Laid down 200.00 ft of Drill collar Ran Drillpipe to 3096.00 ft (5in OD) Circulated at 3100.00 ft Washed to 3246.00 ft Mixed and pumped slurry - 54.000 bbl Pulled Drillpipe in stands to 2150.00 ft Held 2000.0 psi pressure on 20.000 bbl squeezed cement Pulled Drillpipe in stands to 750.00 ft Held safety meeting Pulled Drillpipe in stands to 0.00 ft Circulated at 0.00 ft Removed BOP stack Tested All functions Held safety meeting Laid down 540.00 ft of 5in OD drill pipe Made up BHA no. 1 Facility Date/Time 28 Apr 97 29 Apr 97 30 Apr 97 01 May 97 02 May 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 03:30-05:30 05:30-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-00:00 00:00-00:30 00:30-01:30 O1:30-02:00 02:00-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-22:00 22:00-22:30 22:30-00:30 00:30-01:00 01:00-01:30 O1:30-02:30 02:30-05:00 05:00-06:00 06:00-09:00 09:00-12:00 12:00-12:30 12:30-21:30 21:30-22:00 22:00-22:30 22:30-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-13:30 13:30-14:00 14:00-14:30 14:30-15:00 15:00-15:30 15:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-18:00 18:00-19:00 19:00-19:30 19:30-20:00 20:00-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 2hr 1/2 hr 3hr 3hr 1/2 hr 1/2 hr 1/2 hr 10-1/2 hr 1/2 hr lhr 1/2hr 4hr 6hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 8hr 1/2 hr 2hr 1/2 hr 1/2 hr lhr 2-1/2 hr lhr 3hr 3hr 1/2 hr 9hr 1/2 hr 1/2 hr 1/2 hr lhr 1/2 hr 5-1/2 hr 7-1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 8-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 5-1/2 hr lhr 1/2 hr 1/2 hr 4hr 1/2 hr 5-1/2 hr 6hr 1/2 hr R.I.H. to 2822.00 ft Laid down 450.00 ft of 5in OD drill pipe i Drilled cement to 3096.00 ft Drilled to 3119.00 ft Held safety meeting Drilled to 3182.00 ft Tested Other sub-surface equipment - Via string Drilled to 4034.00 ft Held safety meeting Pulled out of hole to 3096.00 ft R.I.H. to 4034.00 ft Drilled to 4450.00 ft Drilled to 4980.00 ft Held safety meeting Drilled to 5075.00 ft Pulled out of hole to 4000.00 ft R.I.H. to 5075.00 ft Drilled to 5963.00 fl Circulated at 5963.00 ft Pulled out of hole to 3096.00 ft Held safety meeting Pulled out of hole to 1050.00 ft Pulled BHA Made up BHA no. 2 R.I.H. to 3096.00 ft R.I.H. to 5940.00 ft Drilled to 6069.00 ft Held safety meeting Drilled to 6954.00 ft Circulated at 6954.00 ft Pulled out of hole to 5960.00 ft R.I.H. to 6954.00 ft Drilled to 7018.00 ft Held safety meeting Drilled to 7515.00 ft Drilled to 7994.00 ft Held safety meeting Circulated at 7994.00 ft Pulled out of hole to 6943.00 ft R.I.H. to 7994.00 ft Drilled to 8563.00 ft Held safety meeting Drilled to 8880.00 ft Drilled to 9069.00 ft (cont...) Held safety meeting Drilled to 9511.00 fl Circulated at 9511.00 ft Pulled out of hole to 7982.00 ft R.I.H. to 9511.00 ft Drilled to 9637.00 ft Held safety meeting Drilled to 9872.00 ft Drilled to 10174.00 ft Held safety meeting 2 22 July 97 Facility Date/rime 03 May 97 04 May 97 05 May 97 06 May 97 07 May 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 12:30-00:00 00:00-00:30 00:30-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-12:00 12:00-12:30 12:30-13:00 13:00-15:30 15:30-16:00 16:00-17:30 17:30-19:00 19:00-20:00 20:00-00:00 00:00-00:30 00:30-01:00 O1:00-04:30 04:30-05:00 05:00-06:00 06:00-07:30 07:30-09:30 09:30-10:00 10:00-12:00 12:00-12:30 12:30-00:30 00:30-02:00 02:00-02:30 02:30-03:30 03:30-04:30 04:30-05:00 05:00-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-12:30 12:30-15:00 15:00-15:30 15:30-16:30 16:30-17:00 17:00-18:00 18:00-00:00 00:00-00:30 00:30-06:00 06:00-11:00 11:00-12:00 12:00-12:30 12:30-13:30 13:30-00:00 00:00-00:30 00:30-01:00 O1:00-02:00 02:00-06:00 06:00-12:00 11-1/2 hr 1/2hr 4-1/2 hr lhr 1/2hr 4hr 1-1/2 hr 1/2hr 1/2hr 2-1/2 hr 1/2hr 1-1/2 hr 1-1/2 hr lhr 4hr 1/2hr 1/2hr 3-1/2 hr 1/2 hr lhr 1-1/2 hr 2hr 1/2 hr 2hr 1/2 hr 12hr 1-1/2 hr 1/2 hr lhr lhr 1/2 hr lhr 1/2 hr 4-1/2 hr lhr 1/2 hr 2-1/2 hr 1/2 hr lhr 1/2hr lhr 6hr 1/2 hr 5-1/2 hr 5hr lhr 1/2hr lhr 10-1/2 hr 1/2hr 1/2hr lhr 4hr 6hr Drilled to 10582.00 ft Held safety meeting Drilled to 10803.00 ft Circulated at 10803.00 ft Circulated at 10803.00 ft Pulled out of hole to 200.00 ft Pulled BHA Held safety meeting Installed BOP test plug assembly Tested Well control Installed Bore protector Made up BHA no. 3 R.I.H. to 3096.00 ft Serviced Block line R.I.H. to 10730.00 ft Held safety meeting Washed to 10803.00 ft Drilled to 10916.00 ft Investigated pressure change Pulled out of hole to 9900.00 ft Pulled out of hole to 7183.00 ft R.I.H. to 10872.00 ft Washed to 10916.00 ft Drilled to 10980.00 ft Held safety meeting Drilled to 11370.00 ft Circulated at 11370.00 ft Drilled to 11391.00 ft Circulated at 11391.00 ft Pulled out of hole to 10433.00 ft R.I.H. to 11391.00 ft Circulated at 11391.00 ft Circulated at 11391.00 ft Pulled out of hole to 1050.00 fl Laid down 900.00 ft of 5in OD drill pipe Held safety meeting Pulled BHA Installed BOP test plug assembly Serviced Top ram Installed Bore protector Rigged up Casing handling equipment Ran Liner to 4000.00 ft (7in OD) Held safety meeting Ran Liner to 9000.00 ft (7in OD) Ran Liner to 8975.00 ft (7in OD) Installed Setting tools Held safety meeting Ran Drillpipe in stands to 10434.00 ft Circulated at 10434.00 ft Held safety meeting Worked stuck pipe at 10434.00 ft Displace treatment Worked stuck pipe at 10434.00 ft Worked stuck pipe at 10434.00 ft 3 22 July 97 Facility PB P Pad Progress Report Well P-21B Page 4 Rig Doyon # 9 Date 22 July 97 Date/Time 08 May 97 09 May 97 10 May 97 11 May 97 12:00-12:30 12:30-16:00 16:00-16:30 16:30-00:00 00:00-00:30 00:30-06:00 06:00-10:00 10:00-12:00 12:00-12:30 12:30-13:00 13:00-18:30 18:30-19:30 19:30-20:00 20:00-21:00 21:00-23:00 23:00-00:00 00:00-00:30 00:30-03:30 03:30-05:00 05:00-06:00 06:00-08:30 08:30-10:00 10:00-10:30 10:30-12:00 12:00-12:30 12:30-17:00 17:00-21:00 21:00-21:30 21:30-23:00 23:00-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-09:00 09:00-10:00 10:00-14:30 14:30-16:00 16:00-17:30 17:30-18:00 18:00-19:30 19:30-20:30 20:30-21:30 21:30-22:30 22:30-23:30 23:30-00:00 00:00-00:30 00:30-01:00 01:00-01:30 01:30-02:00 02:00-02:30 02:30-06:00 06:00-12:00 12:00-12:30 12:30-15:30 Duration 1/2 hr 3-1/2 hr 1/2 hr 7-1/2 hr 1/2 hr 5-1/2 hr 4hr 2hr 1/2 hr 1/2 hr 5-1/2 hr lhr 1/2 hr lhr 2hr lhr 1/2 hr 3hr 1-1/2 hr lhr 2-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 4hr 1/2hr 1-1/2 hr lhr 1/2 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr lhr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr lhr lhr lhr lhr 1/2hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 6hr 1/2 hr 3hr Activity Held safety meeting Worked stuck pipe at 10434.00 ft Circulated at 10434.00 ft Worked stuck pipe at 10434.00 ft Held safety meeting Worked stuck pipe at 10434.00 ft Circulated at 10434.00 ft Displaced slurry - 359.000 bbl Held safety meeting Displaced slurry - 364.000 bbl Wait on cement Functioned Permanent packer Reverse circulated at 1439.00 ft Rigged up Drillstring handling equipment Laid down 1500.00 ft of 5in OD drill pipe Rigged up Drillstring handling equipment Held safety meeting Laid down 5000.00 ft of 5in OD drill pipe Serviced Dual bore rams Laid down 3000.00 ft of 5in OD drill pipe Laid down 10000.00 ft of 5in OD drill pipe Rigged up Kelly Retrieved Bore protector Tested Well control Held safety meeting Tested Well control Made up BI-LA no. 4 Functioned downhole tools at 2100.00 ft Serviced Block line Singled in drill pipe to 2500.00 ft Held safety meeting Singled in drill pipe to 10200.00 ft Singled in drill pipe to 10318.00 ft Tested Casing Circulated at 10318.00 ft Pulled out of hole to 200.00 ft Pulled BHA Rigged up Packer assembly Ran Drillpipe in stands to 1430.00 ft Tested Casing Pulled Drillpipe in stands to 360.00 ft Pulled Drill collar in stands to 0.00 ft Ran Drillpipe in stands to 1480.00 ft Tested Liner - Via annulus and string Circulated at 1480.00 ft Held safety meeting Pulled Drillpipe in stands to 0.00 ft Rigged down sub-surface equipment - Downhole equipment Laid down 360.00 ft of Drill collar Made up BHA no. 5 R.I.H. to 10318.00 ft Drilled installed equipment - Landing collar Held safety meeting Drilled cement to 10433.00 ft Facility Date/Time 12 May 97 13 May 97 14 May 97 15 May 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 15:30-16:00 16:00-16:30 16:30-19:00 19:00-19:30 19:30-21:30 21:30-23:30 23:30-00:00 00:00-00:30 00:30-06:00 06:00-08:00 08:00-08:30 08:30-09:30 09:30-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-16:00 16:00-22:00 22:00-00:00 00:00-00:30 00:30-01:30 01:30-02:30 02:30-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-17:30 17:30-18:30 18:30-21:00 21:00-21:30 21:30-22:00 22:00-00:00 00:00-00:30 00:30-01:30 01:30-04:00 04:00-05:30 05:30-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-16:00 16:00-17:30 17:30-21:00 21:00-00:00 00:00-00:30 00:30-01:30 01:30-06:00 06:00-11:30 11:30-12:00 12:00-12:30 12:30-14:30 14:30-15:00 15:00-16:00 16:00-18:00 1/2 hr 1/2 hr 2-1/2 hr 1/2 hr 2hr 2hr 1/2 hr 1/2 hr 5-1/2 hr 2hr 1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 6hr 2hr 1/2 hr lhr lhr 3-1/2 hr 6hr 1/2hr 4-1/2 hr 1/2 hr lhr 2-1/2 hr 1/2 hr 1/2 hr 2hr 1/2 hr lhr 2-1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 3-1/2 hr 3hr 1/2 hr lhr 4-1/2 hr 5-1/2 hr 1/2hr 1/2 hr 2hr 1/2 hr lhr 2hr Tested Casing - Via annulus and string Held drill (Kick (well kill)) Washed to 10515.00 ft Circulated at 10515.00 ft Installed Kelly Reamed to 10654.00 ft Circulated at 10654.00 ft Held safety meeting Reamed to 11322.00 ft Circulated at 11391.00 ft Pulled out of hole to 10400.00 ft R.I.H. to 11391.00 ft Circulated at 11391.00 ft Held safety meeting Pulled out of hole to 10400.00 ft R.I.H. to 11391.00 ft Circulated at 11391.00 ft Laid down 5000.00 ft of 3-1/2in OD drill pipe Pulled BHA Held safety meeting Pulled BHA Removed Bore protector Ran Casing to 500.00 ft (5-1/2in OD) Ran Casing to 6000.00 ft (5-1/2in OD) Held safety meeting Ran Casing to 10434.00 ft (5-1/2in OD) Circulated at 10434.00 ft Ran Casing to 11385.00 ft (5-1/2in OD) Circulated at 11385.00 ft Laid down 40.00 ft of Casing Circulated at 11385.00 ft Displaced slurry - 263.000 bbl Held safety meeting Rigged down Cement head Installed Emergency hang off assembly Installed Slip & seal assembly Installed Casing spool Rigged up All functions Tested All functions Held safety meeting Tested All functions Installed Wear bushing Laid down 2800.00 ft of 3-1/2in OD drill pipe Made up BHA no. 6 Held safety meeting Made up BHA no. 6 Singled in drill pipe to 5000.00 ft Singled in drill pipe to 6000.00 ft Serviced Iron roughneck Held safety meeting Singled in drill pipe to 11073.00 ft Circulated at 11073.00 ft Tested Casing - Via string Circulated at 11073.00 ft 5 22 July 97 Facility Date/Time 16 May 97 17 May 97 18 May 97 19 May 97 20 May 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 18:00-20:30 20:30-21:00 21:00-00:00 00:00-00:30 00:30-03:00 03:00-03:30 03:30-04:00 04:00-06:00 06:00-12:00 12:00-12:30 12:30-13:00 13:00-14:30 14:30-22:00 22:00-23:00 23:00-00:00 00:00-00:30 00:30-01:00 01:00-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-12:00 12:00-12:30 12:30-00:00 00:00-00:30 00:30-03:00 03:00-04:00 04:00-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-14:00 14:00-16:30 16:30-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-04:00 04:00-05:30 06:00-10:30 10:30-12:00 12:00-12:30 12:30-20:00 20:00-21:30 21:30-00:00 00:00-00:30 00:30-03:30 03:30-05:00 05:00-06:00 06:00-10:30 10:30-11:30 11:30-12:00 2-1/2 hr 1/2 hr 3hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 2hr 6hr 1/2 hr 1/2 hr 1-1/2 hr 7-1/2 hr lhr lhr 1/2 hr 1/2 hr 3hr lhr lhr 1-1/2 hr 4-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 2-1/2 hr lhr 2hr 4-1/2 hr 1-1/2 hr 1/2 hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr lhr 2hr 1/2 hr 3-1/2 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 7-1/2 hr 1-1/2 hr 2-1/2 hr 1/2hr 3hr 1-1/2 hr lhr 4-1/2 hr lhr 1/2 hr Drilled cement to 11305.00 ft Tested Casing - Via string Drilled installed equipment - Float collar Held safety meeting Drilled cement to 11405.00 ft Circulated at 11405.00 ft Tested Other sub-surface equipment - Via string Drilled to 11451.00 ft Drilled to 11564.00 ft Held safety meeting Drilled to 11577.00 ft Circulated at 11577.00 ft Pulled out of hole to 200.00 ft Pulled BHA Made up BHA no. 7 Held safety meeting Made up BHA no. 7 R.I.H. to 7000.00 ft Serviced Block line R.I.H. to 8500.00 ft R.I.H. to 11563.00 ft Drilled to 11685.00 ft Held safety meeting Drilled to 12032.00 ft Held safety meeting Drilled to 12129.00 ft Circulated at 12129.00 ft Pulled out of hole to 9500.00 ft Pulled out of hole to 200.00 ft Pulled BHA Held safety meeting Made up BHA no. 8 R.I.H. to 4500.00 ft R.I.H. to 12114.00 ft Functioned downhole tools at 12129.00 ft Drilled to 12158.00 ft Circulated at 12158.00 ft Pulled out of hole to 8500.00 ft Held safety meeting Pulled out of hole to 200.00 ft Pulled BHA R.I.H. to 12114.00 ft Circulated at 12150.00 ft Held safety meeting Drilled to 12414.00 ft Circulated at 12414.00 ft Pulled out of hole to 9000.00 ft Held safety meeting Pulled out of hole to 200.00 ft Made up BHA no. 9 Made up BHA no. 10 R.I.H. to 9000.00 ft Installed Block line R.I.H. to 1100.00 ft 6 22 July 97 Facility Date/Time 21 May 97 22 May 97 23 May 97 24 May 97 25 May 97 PB P Pad Progress Report Well P-21B Page 7 Rig Doyon # 9 Date 22 July 97 12:00-12:30 12:30-13:30 13:30-00:00 00:00-00:30 00:30-01:30 01:30-02:30 02:30-06:00 06:00-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-17:00 17:00-19:00 19:00-00:00 00:00-00:30 00:30-02:00 02:00-04:00 04:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-12:00 12:00-12:30 12:30-13:00 13:00-15:30 15:30-21:00 21:00-22:30 22:30-00:00 00:00-00:30 00:30-06:00 06:00-07:30 07:30-09:30 09:30-12:00 12:00-12:30 12:30-13:30 13:30-15:00 15:00-17:30 17:30-00:00 00:00-00:30 00:30-02:00 02:00-06:00 06:00-12:00 12:00-12:30 12:30-17:00 17:00-19:30 19:30-00:00 00:00-00:30 00:30-02:00 02:00-03:00 03:00-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:30 Duration 1/2 hr lhr 10-1/2 hr 1/2 hr lhr lhr 3-1/2 hr 6hr 1/2 hr lhr 1-1/2 hr 2hr 2hr 5hr 1/2 hr 1-1/2 hr 2hr lhr lhr 2hr lhr 3hr 1/2 hr 1/2 hr 2-1/2 hr 5-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 5-1/2 hr 1-1/2 hr 2hr 2-1/2 hr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 6-1/2 hr 1/2 hr 1-1/2 hr 4hr 6hr 1/2 hr 4-1/2 hr 2-1/2 hr 4-1/2 hr 1/2 hr 1-1/2 hr lhr 2hr lhr 2hr lhr 1-1/2 hr Activity Held safety meeting R.I.H. to 12414.00 ft Drilled to 12680.00 ft Held safety meeting Drilled to 12758.00 ft Circulated at 12758.00 ft Drilled to 12870.00 ft Drilled to 13042.00 ft Held safety meeting Drilled to 13106.00 ft Circulated at 13106.00 ft Pulled out of hole to 12870.00 ft Circulated at 13106.00 ft Pulled out of hole to 4500.00 ft Held safety meeting Pulled out of hole to 200.00 ft Pulled BHA Conducted electric cable operations R.I.H. to 6000.00 ft Conducted electric cable operations Rigged up All functions Tested All functions Held safety meeting Tested All functions Rigged up Logging/braided cable equipment R.I.H. to 11074.00 ft Rigged up Winch Conducted electric cable operations Held safety meeting Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Pulled out of hole to 2000.00 ft Held safety meeting Pulled out of hole to 0.00 ft Rigged down Logging/braided cable equipment Made up BI-LA no. 11 R.I.H. to 12900.00 ft Held safety meeting Logged hole with LWD: Directional (DIR) from 12900.00 ft to 13106.0( Drilled to 13230.00 ft Drilled to 13293.00 ft Held safety meeting Drilled to 13451.00 ft Circulated at 13439.00 ft Pulled out of hole to 4500.00 ft Held safety meeting Pulled out of hole to 200.00 ft Pulled BHA Made up BI-IA no. 12 R.I.H. to 1000.00 ft Serviced M.W.D. tool Serviced Block line Made up BI-IA no. 12 Facility- Date/Time 26 May 97 27 May 97 28 May 97 29 May 97 30 May 97 PB P Pad Progress Report Well P-21B Rig Doyon 4/9 Page Date Duration Activity 10:30-11:00 11:00-11:30 11:30-12:00 12:00-12:30 12:30-13:00 13:00-13:30 13:30-14:00 14:00-16:30 16:30-22:30 22:30-00:00 00:00-00:30 00:30-06:00 06:00-12:00 12:00-12:30 12:30-14:00 14:00-15:30 15:30-16:30 16:30-18:30 18:30-00:00 00:00-00:30 00:30-01:30 01:30-04:30 04:30-06:00 06:00-07:30 07:30-08:30 08:30-12:00 12:00-12:30 12:30-13:00 13:00-18:00 18:00-18:30 18:30-00:00 00:00-00:30 00:30-01:00 01:00-02:00 02:00-03:30 03:30-06:00 06:00-06:30 06:30-08:30 08:30-12:00 12:00-12:30 12:30-20:00 20:00-00:30 00:30-05:00 05:00-06:00 06:00-12:00 12:00-12:30 12:30-19:00 19:00-21:00 21:00-01:00 01:00-02:30 02:30-03:30 03:30-06:00 06:00-10:30 10:30-13:30 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 6hr 1-1/2 hr 1/2 hr 5-1/2 hr 6hr 1/2 hr 1-1/2 hr 1-1/2 hr lhr 2hr 5-1/2 hr 1/2 hr lhr 3hr 1-1/2 hr 1-1/2 hr lhr 3-1/2 hr 1/2 hr 1/2hr 5hr 1/2 hr 5-1/2 hr 1/2 hr 1/2 hr lhr 1-1/2 hr 2-1/2 hr 1/2 hr 2hr 3-1/2 hr 1/2 hr 7-1/2 hr 4-1/2 hr 4-1/2 hr lhr 6hr 1/2 hr 6-1/2 hr 2hr 4hr 1-1/2 hr lhr 2-1/2 hr 4-1/2 hr 3hr R.I.H. to 100.00 ft Functioned downhole tools at 100.00 ft R.I.H. to 500.00 ft Held safety meeting R.I.H. to 800.00 ft Functioned downhole tools at 800.00 ft Pulled out of hole to 0.00 ft Made up BHA no. 12 R.I.H. to 12342.00 ft Drilled to 13459.00 ft Held safety meeting Drilled to 13555.00 ft Drilled to 13671.00 ft Held safety meeting Circulated at 13671.00 ft Pulled out of hole to 11385.00 ft R.I.H. to 13671.00 ft Circulated at 13671.00 ft Pulled out of hole to 4000.00 ft Held safety meeting Pulled out of hole to 2897.00 ft Laid down 2697.00 ft of 2-3/8in OD drill pipe Pulled BHA Pulled BHA Rigged up Casing handling equipment Ran Liner to 2000.00 ft (3-1/2in OD) Held safety meeting Ran Liner to 2492.00 ft (3-1/2in OD) Ran Tubing to 2416.00 ft (2-1/16in OD) Circulated at 3000.00 ft Ran Drillpipe in stands to 10500.00 ft Held safety meeting Ran Drillpipe in stands to 11385.00 ft Circulated at 11385.00 ft Ran Drillpipe in stands to 13671.00 ft Circulated at 13671.00 ft Circulated at 13671.00 ft Displaced slurry - 41.000 bbl Circulated at 10072.00 ft Held safety meeting Pulled Drillpipe in stands to 0.00 ft Tested BOP stack Made up BHA no. 13 R.I.H. to 500.00 ft R.I.H. to 10109.00 ft Held safety meeting Drilled cement to 11157.00 ft Circulated at 11157.00 ft Pulled out of hole to 522.00 ft Pulled BHA Made up BHA no. 14 R.I.H. to 320.00 ft Pulled out of hole to 0.00 ft Fished at 11157.00 ft 8 22 July 97 Facility Date/Time 31 May 97 O1 Jun 97 02 Jun 97 03 Jun 97 04 Jun 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 13:30-16:30 16:30-17:30 17:30-22:00 22:00-22:30 22:30-00:00 00:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-05:30 05:30-06:00 06:00-13:30 13:30-15:30 15:30-21:30 21:30-00:00 00:00-01:00 01:00-06:00 06:00-12:00 12:00-12:30 12:30-15:00 15:00-15:30 15:30-16:30 16:30-17:00 17:00-17:30 17:30-18:00 18:00-19:00 19:00-20:00 20:00-20:30 20:30-00:00 00:00-00:30 00:30-01:30 01:30-02:00 02:00-06:00 06:00-08:00 08:00-08:30 08:30-12:00 12:00-12:30 12:30-22:00 22:00-22:30 22:30-22:45 22:45-23:00 23:00-23:30 23:30-00:00 00:00-00:30 00:30-00:45 00:45-01:00 01:00-01:15 01:15-06:00 06:00-12:00 12:00-12:30 12:30-14:00 14:00-15:00 15:00-17:30 17:30-19:30 3hr lhr 4-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr lhr lhr 23-1/2 hr 1/2 hr 7-1/2 hr 2hr 6hr 2-1/2 hr lhr 5hr 6hr 1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 1/2 hr 1/2 hr lhr lhr 1/2 hr 3-1/2 hr 1/2 hr lhr 1/2 hr 4hr 2hr 1/2hr 3-1/2 hr 1/2 hr 9-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/2 hr 1/2 hr 1/2 hr 1/4 hr 1/4 hr 1/4 hr 4-3/4 hr 6hr 1/2 hr 1-1/2 hr lhr 2-1/2 hr 2hr Fished at 11157.00 ft Made up BHA no. 14 R.I.H. to 2600.00 ft Circulated at 2600.00 ft R.I.H. to 3100.00 ft Held safety meeting R.I.H. to 11136.00 ft Serviced Block line Washed to 11157.00 ft Drilled cement to 13606.00 ft Circulated at 13606.00 ft Circulated at 13606.00 ft Tested Casing - Via annulus and string Pulled out of hole to 2500.00 ft Pulled BHA Held safety meeting Rigged up sub-surface equipment - TCP Ran Drillpipe in stands to 10000.00 ft Held safety meeting Ran Drillpipe in stands to 13000.00 ft Rigged up Manifolds Ran Drillpipe in stands to 13606.00 ft Space out tubulars Set packer at 10936.00 ft with 0.0 psi Held safety meeting Perforated Reverse circulated at 11505.00 ft Flow check Pulled Drillpipe in stands to 3000.00 ft Held safety meeting Pulled Drillpipe in stands to 2500.00 ft Retrieved Retrievable packer Retrieved TCP Retrieved TCP Removed Drillstring handling equipment Laid down 2930.00 ft of 2-3/8in OD drill pipe Held safety meeting Laid down 10852.00 ft of 2-7/8in OD drill pipe Removed Drillstring handling equipment Removed Bore protector Installed BOP test plug assembly Rigged down Top ram Rigged up Variable ram Held safety meeting Tested Variable ram Removed BOP test plug assembly Held safety meeting Ran Tubing to 2222.00 ft (3-1/2in OD) Ran Tubing to 7034.00 ft (3-1/2in OD) Held safety meeting Ran Tubing to 9171.00 ft (3-1/2in OD) Installed SCSSSV nipple assembly Ran Tubing to 11160.00 ft (3-1/2in OD) Installed Tubing hanger 9 22 July 97 Facility Date/Time 05 Jun 97 PB P Pad Progress Report Well P-21B Rig Doyon # 9 Page Date Duration Activity 19:30-20:00 20:00-23:50 23:50-00:00 00:00-00:30 00:30-01:30 O1:30-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-07:00 07:00-07:30 07:30-08:00 08:00-08:30 08:30-10:30 10:30-11:30 11:30-12:00 12:00-12:30 12:30-13:00 1/2hr 3-3/4 hr Ohr 1/2 hr lhr lhr 2hr lhr 1/2hr 1/2hr 1/2hr 1/2hr 1/2 hr 1/2 hr 2hr lhr 1/2 hr 1/2 hr 1/2 hr Installed Hanger plug Rigged down Kelly Rigged down Bottom ram Held safety meeting Installed Bottom ram Removed BOP stack Installed Xmas tree Retrieved Hanger plug Circulated at 11175.00 ft Circulated at 11175.00 ft Functioned Permanent packer Tested Permanent packer Tested Tubing Tested Tubing - Via annulus and string Freeze protect well - 42.000 bbl of Diesel Freeze protect well - 42.000 bbl of Diesel Installed Hanger plug Held safety meeting Installed Hanger plug 10 22 July 97 ]VNIglU0 LI'L£LI IT'SL9I 08'619I TL'I9SI LI'£0SI MTT'S0~E S99'9£TI I8' MSI'ETIE SOS'8EgI 6L' MT0'6L0~ SIg'0ETI M£S'9IOE SSS'EITI M98'£S6I S£8'SOTI M LI'£8 S L£ I9 M L~'S8 S £9 09 96'££~9 £~'£999 9I'689S 8T'£8£I 66'6E£I £I'£LEI I9'TI~I MIS'I68I S8£'009I 6I'E ME6'0£8I S8L'S6£I 09' M9I'0LLI SS6'I6£I 80'I M£I'0ILI S9E'88£I M~E'899I S££'98£I 89'I M TL'98 S 0 IT M E9'98 S 6I 6£ M LI'98 S 9£ 6£ M 8L'98 $ 0£ 09 M 96'S8 S 0E 09 06'ABE9 Lg'LLET 09'60£S SC'ETI9 E6'TCE9 0£'0ETS E8'960I 99'8L6 T0'616 M8S'985I SE0'I8£I 98' MSI'gESI S£0'8L£I 9I' MT0'E99I SIS'gL£I IL' MET'66£I SI£'0LEI £9' MI5'9££I S99'995I 65' M A8'£8 S 6S 09 99'£66£ £E'£809 68'6E6T M 99'98 M 98'98 M £E'98 M ~0'98 S£'66t 98'6££ 69'089 ML6'E£EI S88'I9£I M£8'60EI S90'£S£I M£I'9TII S08'IS£I M96'ESOI S~9'S~£I 0I' M8I'0EOI $6£'8££I M 89'S8 S SI ET M 9S'£8 S 0S I~ M I9'£8 S 9S I9 0£'0£S£ £E'099£ 0I'I0~£ A9'06S£ 9E'I£9£ IS'0ES£ E0'I£I9 E8'09££ 6£'0ST£ £9' SC'SOS SI ' T6 £ MLS'£S6 S9L'I££I 99'I M80'S68 S99'9E£I I£'I M09'T£8 S66'SI£I EE'I M9L'TLL S0£'L0£I ST'9 M LE'98 $ SS IT M S£'E8 S ET 0T M S6'08 S ~£ 6£ M IS'E8 S 6 09 M E6'SL S 9S 65 £L'O6E£ 0£'08£C OE'E86£ 6I'6I'E£ 9L'80££ C6'988£ T£'9~I£ TE'9CE£ SI'~6A£ CE'gLOC 06'£9I£ I8'L69£ 8E'I00£ S8'060C OI'SO£ 06'£6I M9T'SL9 S98'ESEI E£'8 M SE'L9 S £I 6£ M85'099 S£S'S9EI 6£'L M I£'09 S LE I9 M99'909 SIL'EgEI E0'L M £6'9S S 6I TT ML8'69~ S6L'SIEI £0'S M E£'69 S 0 99 ME8'9£S S60'SSII 68'II M £6'9~ S 9I 99 I£'TS6E 88'090£ S9'££S£ ST'S0gE ~£'966E 6E'6S8E 98'8~6~ 99'SI8~ £E'S06E 89'ES££ £E'E££E 98'I98~ 80'06E£ 85'6LI S£'99I 98'tgi £t't~I MLS'LOS SI£'0~II 8L'9 M ~9'T£ S SE 99 MII'EST SSI'0III 9£'8 M TL'SE S 0E LT MS~'ELT S8I'680I 68'II M S0'9~ S 9 6T MES'~9T $9I'890I 86'T M I9'£~ S S ES MIE'E9T SEg'L90I 00' M E9'EE S S ~S E6'8~LE 69'818E LC'LEEC 69'~89E 9E'gLLE 69'E9I£ 8S'£99E SI'£SLE I0'IEI£ ES'~99E 60'T££~ 00'IOI£ I6'£T9E 8T'EELE 00'00I£ 'LDZS '£EZA £SZM/LSVZ HLnOS/HLHOM OOI/D~ SZZHOZG SZ£~IG~OOD ~Nfq~©NlfLDZH ~OILDZHIG q~LOL SqC ZS~OD q~DILHZA ~OILHZA ~ZS-~qS NOIi~r~OqdXZ d~ 'i~ LS'68 = 'AZqZ ©NIHS~ XZA~S L69ES0 :AZA~S ~0 k~S~q~ ZD~OHDN~ SZDIAHZS ©MIq~I~ NZ1S-A~, 3 IRRY-SUN DRILLING SERVICES ANCHOP~AGE ALASKA PAGE SHARED SERVICES DRILLING DBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 MWD SURVEY JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5945.77 4854.76 4765.19 5976.18 4877.53 4787.96 6038.66 4924.37 4834.80 6133.93 4996.46 4906.89 6229.07 5069.21 4979.64 41 29 41 34 41 17 40 20 39 53 S 81.65 W 1.55 1442.42S 2248.72W S 80.92 W 1.61 1445.48S 2268.65W S 82.77 W 2.01 1451.34S 2309.57W S 84.12 W 1.36 1458.46S 2371.44W S 83.63 W .59 1465.00S 2432.39W 1777.29 1795.66 1833.49 1891.16 1948.10 6324.22 5141.75 5052.18 6417.71 5212.58 5123.01 6511.23 5283.70 5194.13 6606.63 5356.62 5267.05 6701.74 5429.46 5339.89 40 45 40 45 40 14 40 2 39 59 S 84.43 W 1.05 1471.40S 2493.62W S 84.86 W .30 1477.09S 2554.38W S 83.65 W 1.00 1483.17S 2614.81W S 83.41 W .26 1490.10S 2675.92W S 83.61 W .15 1497.01S 2736.69W 2005.35 2062.33 2118.89 2175.88 2232.54 6795.93 5501.78 5412.21 6891.85 5575.66 5486.09 6987.27 5649.43 5559.86 7079.43 5720.89 5631.32 7175.04 5794.87 5705.30 39 41 39 34 39 9 39 9 39 27 S 83.75 W .33 1503.66S 2796.66W S 83.02 W .50 1510.70S 2857.44W S 81.91 W .85 1518.64S 2917.43W S 83.04 W .77 1526.26S 2975.13W S 84.49 W 1.01 1532.83S 3035.33W 2288.51 2345.14 2400.79 2454.30 2510.50 7270.65 5868.35 5778.78 7365.79 5941.46 5851.89 7460.26 6014.23 5924.66 7554.69 6086.95 5997.38 7649.81 6159.94 6070.37 40 5 39 27 39 47 39 28 40 17 S 84.76 W .70 1538.56S 3096.23W S 84.28 W .75 1544.37S 3156.82W S 85.10 W .65 1549.95S 3216.81W S 84.66 W .44 1555.32S 3276.80W S 86.09 W 1.29 1560.23S 3337.60W 2567.61 2624.40 2680.68 2737.01 2794.23 7745.26 6232.48 6142.91 7839.39 6303.43 6213.86 7933.02 6374.38 6284.81 8029.28 6448.57 6359.00 8123.03 6520.63 6431.06 40 46 41 24 40 2 39 7 40 24 S 85.92 W .52 1564.56S 3399.47W S 86.99 W 1.00 1568.38S 3461.21W S 86.62 W 1.46 1571.78S 3522.20W S 85.93 W 1.07 1575.76S 3583.40W S 85.28 W 1.44 1580.36S 3643.18W 2852.66 2911.09 2968.91 3026.78 3083.12 8216.17 6591.29 6501.72 8311.11 6662.81 6573.24 8406.86 6734.31 6644.74 8502.02 6805.82 6716.25 8597.61 6878.60 6789.03 40 54 41 19 42 2 40 30 40 19 S 84.13 W .97 1585.96S 3703.60W S 83.64 W .56 1592.61S 3765.68W S 84.52 W .97 1599.18S 3829.02W S 84.37 W 1.62 1605.25S 3891.50W S 8A.66 W .28 1611.18S 3953.19W 3139.79 3197.79 3257.02 3315.56 3373.38 8693.08 6951.43 6861.86 8787.01 7022.90 6933.33 8882.05 7095.31 7005.74 8976.05 7167.46 7077.89 9070.21 7240.02 7150.45 40 14 40 4O 4O 3 39 40 39 30 S 84.08 W .40 1617.23S 4014.62W S 83.06 W .85 1624.06S 4075.18W S 83.36 W .68 1631.34S 4136.31W S 80.68 W 1.87 1639.70S 4195.96W S 83.99 W 2.25 1647.70S 4255.41W 3430.90 3487.39 3544.30 3599.50 3654.60 £-~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 MWD SURVEY JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9164.56 7312.15 7222.58 9259.90 7383.49 7293.92 9354.51 7453.75 7364.18 9450.14 7525.58 7436.01 9543.38 7596.30 7506.73 40 45 42 20 41 43 40 53 40 27 S 85.93 W 1.87 1653.03S 4315.98W S 86.65 W 1.74 1657.11S 4379.08W S 87.56 W .92 1660.32S 4442.35W S 88.24 W 1.00 1662.63S 4505.44W S 84.72 W 2.50 1666.35S 4566.06W 3711.50 3771.17 3831.24 3891.37 3948.75 9638.32 7668.70 7579.13 40 9733.67 7741.26 7651.69 40 9828.65 7813.09 7723.52 41 9921.79 7884.29 7794.72 39 10017.26 7957.68 7868.11 40 10 42 1 15 15 S 85.24 W .46 1671.73S 4627.24W S 82.66 W 1.84 1678.25S 4688.73W S 82.96 W .39 1686.03S 4750.38W S 82.86 W 1.89 1693.44S 4809.96W S 83.96 W 1.28 1700.44S 4870.61W 4006.23 4063.69 4120.97 4176.35 4232.88 10109.43 8027.62 7938.05 41 0 10205.61 8099.75 8010.18 41 49 10300.18 8170.44 8080.87 41 25 10394.00 8241.67 81.52.10 39 46 10489.53 8315.34 8225.77 39 18 S 83.89 W .80 1706.79S 4930.29W S 84.18 W .89 1713.40S 4993.57W S 84.15 W .43 1719.79S 5056.06W S 83.31 W 1.84 1726.45S 5116.75W S 83.90 W .63 1733.23S 5177.19W 4288.65 4347.81 4406.27 4462.92 4519.31 10583.77 8387.94 8298.37 39 54 10678.67 8460.37 8370.80 40 35 10751.18 8515.79 8426.22 39 42 10771.06 8531.14 8441.57 39 15 10801.94 8555.07 8465.50 39 9 S 83.88 W .63 1739.62S 5236.92W S 84.89 W 1.01 1745.61S 5297.94W S 85.32 W 1.30 1749.61S 5344.52W S 84.83 W 2.75 1750.69S 5357.12W S 85.45 W 1.31 1752.34S 5376.56W 4575.11 4632.27 4676.05 4687.89 4706.17 10832.68' 8578.69 8489.12 40 27 10863.16 8601.50 8511.93 42 40 10894.83 8624.55 8534.98 43 57 10926.61 8647.20 8557.63 45 9 10958.47 8669.52 8579.95 45 56 N 89.14 W 12.04 1752.96S 5396.22W 4724.93 N 83.85 W 13.62 1751.71S 5416.39W 4744.69 N 78.08 W 13.13 1748.29S 5437.82W 4766.26 N 73.47 W 10.85 1742.80S 5459.42W 4788.54 N 68.40 W 11.62 1735.37S 5480.90W 4811.23 10990.26 8691.40 8601.83 47 11022.15 8712.68 8623.11 49 11054.02 8733.08 8643.51 51 11085.88 8752.74 8663.17 52 11117.78 8771.69 8682.12 54 4 12 10 39 30 N 65.02 W 8.51 1726.25S 5502.08W N 62.01 W 9.70 1715.65S 5523.33W N 59.12 W 9.29 1703.61S 5544.64W N 55.60 W 9.86 1690.09S 5565.74W N 52.60 W 9.53 1675.03S 5586.53W 4834.08 4857.40 4881.16 4905.13 4929.20 11149.41 8789.52 8699.95 56 53 11181.25 8806.51 8716.94 58 35 11213.02 8822.51 8732.94 60 57 11243.79 8836.96 8747.39 63 1 11275.62 8850.78 8761.21 65 31 N 48.31 W 13.51 1658.39S 5606.66W 4953.06 N 45.21 W 9.83 1639.95S 5626.26W 4976.91 N 41.17 W 13.26 1619.93S 5645.04W 5000.38 N 38.16 W 10.93 1599.02S 5662.37W 5022.70 N 35.23 W 11.44 1576.03S 5679.49W 5045.39 PAGE 4 ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 MWD SURVEY JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATE DEGREES DG/100 NORTH/SOUTH EAST/WEST S VERT. SECT. 11307.29 8863.35 8773.78 67 40 11339.44 8875.05 8785.48 69 37 11370,61 8885.76 8796.19 70 10 11402.37 8896.43 8806.86 70 33 11434,60 8906,89 8817.32 71 34 N 34.17 W 7.45 1552.14S 5696.03W N 33.59 W 6.26 1527.28S 5712.72W N 35.69 W 6.58 1503.20S 5729.36W N 37.81 W 6.40 1479.24S 5747.25W N 39.94 W 6.99 1455.51S 5766.39W 5067.75 5090.52 5113.02 5136.71 5161.52 11465.91 8916.93 8827.36 11497.45 8927.13 8837.56 11527.53 8936.79 8847.22 11554.79 8945.01 8855.44 11585.97 8953.25 8863.68 71 4 71 11 71 22 73 30 75 52 N 45.41 W 16.63 1433.71S 5786.48W N 49.77 W 13.09 1413.59S 5808.51W N 54.40 W 14.59 1396.09S 5830.98W N 53.51 W 8.41 1380.80S 5851.99W N 50.32 W 12.45 1362.25S 5875.65W 5186.74 5213.38 5239.73 5264.08 5291.86 11617,64 8960.39 8870.82 11649.21 8966.39 8876.82 11680.95 8971,73 8882.16 11710.54 8977.06 88.87.49 11743.99 8983.74 8894.17 78 3 8O 1 80 36 78 38 78 19 N 48.24 W 9.42 1342.12S 5899.03W N 45,38 W 10.86 1320.91S 5921.62W N 41.52 W 12.13 1298.20S 5943.13W N 38.26 W 12.72 1275.87S 5961.80W N 37.41 W 2.67 1249.99S 5981.90W 5319.80 5347.27 5374.10 5398.09 5424.42 11775.34 8990.11 8900.54 11806.83 8995.82 8906.25 11838.02 8999,71 8910.13 11870.06 9001.53 8911.96 11901.19 9001.95 8912.38 78 14 80 50 84 50 88 37 89 49 N 35.16 W 7.03 1225.25S 6000.07W N 34.54 W 8.51 1199.84S 6017.76W N 33.36 W 13.36 1174.17S 6035.04W N 33.10 W 11.79 1147.42S 6052.56W N 29.53 W 12.10 1120.83S 6068.74W 5448.57 5472.45 5496.00 5520.09 5542.82 11932.45 9001.73 8912.16 11965.15 9000.91 8911.34 11996.48 9000.09 8910.52 12028.05 9000.36 8910.79 12060.09 9002.65 8913.08 90 59 91 52 91 8 87 52 83 55 N 25.44 W 13.61 1093.11S 6083.16W N 20.56 W 15.16 1063.02S 6095.93W N 17.98 W 8.56 1033.46S 6106.27W N 17.02 W 10.80 1003.36S 6115.76W N 16.97 W 12.33 972.80S 6125.10W 5564.18 5584.57 5602.49 5619.73 5636.96 12090.63 9005.90 8916.33 12121.94 9009.13 8919.56 12152.22 9012.09 8922.52 12184.16 9015.53 8925.96 12215.45 9019.53 8929.96 83 84 84 83 82 51 19 26 11 7 N 17.65 W 2.22 943.81S 6134.13W N 18.15 W 2.16 914.18S 6143.70W N 18.55 W 1.37 885.57S 6153.19W N 15.39 W 10.57 855.21S 6162.46W N 12.84 W 8.79 825.11S 6170.03W 5653.46 5670.66 5687.50 5704.60 5719.99 12248.38 9024.24 8934.67 12279.93 9028.91 8939,34 12311.97 9033.65 8944.08 12337.15 9037.37 8947,80 12370.27 9042.46 8952.89 81 25 81 33 81 25 81 34 80 45 N 9.91 W 9.05 793.17S 6176.45W N 9.72 W .73 762.42S 6181.77W N 9.56 W .66 731.18S 6187.08W N 8.67 W 3.55 706.59S 6191.02W N 9.22 W 2.97 674.27S 6196.11W 5734.79 5748.19 5761.71 5772.13 5785.73 RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 MWD SURVEY JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECT I ON RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12401.70 9047.54 8957.97 12433.58 9051.89 8962.32 12465.05 9054.30 8964.73 12496.25 9055.29 8965.72 12528.10 9055.75 8966.18 80 38 83 41 87 30 88 51 89 28 N 8.04 W 3.72 643.60S 6200.77W N 8.75 W 9.85 612.36S 6205.38W N 8.14 W 12.26 581.33S 6209.98W N 8.93 W 5.01 550.49S 6214.61W N 9.11 W 2.03 519.04S 6219.60W 5798.47 5811.32 5824.12 5836.88 5850.15 12560.00 9056.08 8966.51 89 19 12591.41 9057.08 8967.51 87 1 12622.73 9058.59 8969.02 87 26 12646.95 9060.11 8970.54 85 22 12684.86 9063.40 8973.83 84 40 N 7.95 W 3.67 487.50S 6224.34W N 7.43 W 7.54 456.39S 6228.54W N 7.66 W 1.56 425.38S 6232.64W N 8.99 W 10.19 401.47S 6236.14W N 9.27 W 1.99 364.18S 6242.14W 5863.20 5875.62 5887.93 5897.74 5913.55 12717.07 9066.65 8977.08 83 45 12748.19 9069.88 8980.31 84 19 12779.53 9072.79 8983.21 85 1 12812.14 9075.44 89'85.87 85 39 12842.39 9077.27 8987.70 87 25 N 10.38 W 4.46 332.61S 6247.60W N 10.13 W 2.03 302.15S 6253.11W N 11.09 W 3.76 271.48S 6258.86W N 9.50 W 5.23 239.51S 6264.67W N 11.00 W 7.66 209.80S 6270.04W 5927.31 5940.82 5954.61 5968.82 5981.99 12874.34 9077.91 8988.34 12906.62 9077.00 8987.43 12937.93 9074.70 8985.13 12968.34 9071.57 8982.00 13002.34 9067.52 8977.95 90 16 92 56 95 '28 96 20 97 19 N 10.06 W 9.42 178.40S 6275.88W N 10.93 W 8.67 146.67S 6281.75W N 10.99 W 8.11 116.02S 6287.69W N 9.58 W 5.43 86.27S 6293.09W N 8.40 W 4.47 52.93S 6298.36W 5996.06 6010.27 6024.23 6037.45 6051.51 13033.42 9063.32 8973.75 98 13 13070.94 9057.47 8967.90 99 42 13102.45 9051.96 8962.39 ** 26 13134.35 9046.42 8956.85 99 33 13165.80 9040.99 8951.42 ** 18 N 7.86 W 3.37 22.44S 6302.72W N 7.96 W 3.98 14.27N 6307.82W N 7.93 W 2.35 44.99N 6312.11W N 8.94 W 4.18 76.06N 6316.71W N 9.15 W 2.47 106.65N 6321.58W 6063.91 6078.70 6091.11 6103.91 6116.84 13198.34 9035.08 8945.51 ** 37 13229.72 9029.28 8939.71 ** 40 13260.29 9023.43 8933.86 ** 24 13294.29 9016.35 8926.78 ** 39 13324.98 9009.62 8920.04 ** 41 N 10.39 W 3.87 138.19N 6327.01W N 10.47 W .30 168.52N 6332.60W N 12.07 W 5.66 197.94N 6338.46W N 13.42 W 5.35 230.37N 6345.79W N 15.06 W 5.22 259.39N 6353.16W 6130.56 6144.10 6157.67 6173.46 6188.37 13357.17 9002.69 8913.12 13385.28 8997.01 8907.44 13414.54 8991.57 8902.00 13448.70 8985.59 8896.02 13480.06 8980.15 8890.58 '** 9 ** 9 ** 16 99 54 ** 4 N 15.91 W 3.08 289.68N 6361.55W N 16.20 W 3.73 316.14N 6369.17W N 15.96 W 3.11 343.76N 6377.13W N 16.74 W 2.50 376.04N 6386.60W N 17.43 W 2.24 405.56N 6395.67W 6204.61 6219.07 6234.17 6251.98 6268.67 ]RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 MWD SURVEY JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 13511.73 8974.87 8885.30 99 5 N 19.39 W 6.84 435.18N 6405.53W 13543.14 8970.04 8880.47 98 34 N 20.45 W 3.72 464.36N 6416.10W 13574.54 8965.88 8876.31 96 40 N 21.04 W 6.33 493.46N 6427.13W 13604.86 8962.24 8872.67 97 4 N 20.63 W 1.88 521.59N 6437.83W 13671.00 8954.09 8864.52 97 4 N 20.63 W .00 583.02N 6460.96W 6286.14 6304.18 6322.63 6340.52 6379.33 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6487.21 FEET AT NORTH 84 DEG. 50 MIN. WEST AT MD = 13671 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 285.62 DEG. TIE-IN SURVEY AT 3,100.00' MD WINDOW POINT AT 3,101.00' MD PROJECTED SURVEY AT 13,671.00' MD iRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P- 21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 3100.00 2733.48 2643.91 1067.42 S 462.21 W 366.52 4100.00 3467.93 3378.36 1340.14 S 1035.84 W 632.07 5100.00 4216.49 4126.92 1387.52 S 1696.96 W 883.51 6100.00 4970.60 4881.03 1456.21 S 2349.58 W 1129.40 7100.00 5736.84 5647.27 1527.83 S 2988.02 W 1363.16 265.55 251.44 245.89 233.76 8100.00 6503.09 6413.52 1579.13 S 3628.31 W 1596.91 9100.00 7263.00 7173.43 1649.68 S 4274.26 W 1837.00 10100.00 8020.51 7930.94 1706.13 S 4924.14 W 2079.49 11100.00 8761.23 8671.66 1683.60 S 5574.98 W 2338.77 12100.00 9006.91 8917.33 934.93 S 6136.96 W 3093.09 233.74 240.09 242.49 259.28 754.33 13100.00 9052.40 8962.83 42.60 N 6311.77 W 4047.60 13671.00 8954.09 8864.52 583.02 N 6460.96 W 4716.91 954.50 669.31 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. AUG 1~8 199'/' Qjt ,& Gas Coils, Uuri~DIF~'. 'RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3100.00 2733.48 2643.91 3185.19 2789.57 2700.00 3330.12 2889.57 2800.00 3470.19 2989.57 2900.00 1067.42 S 462.21 W 1124.45 S 491.33 W 1205.00 S 557.74 W 1263.17 S 636.39 W 366.52 395.62 29.10 440.55 44.93 480.62 40.07 3600.76 3089.57 3000.00 3731.40 3189.57 3100.00 3861.62 3289.57 3200.00 3994.66 3389.57 3300.00 4129.08 3489.57 3400.00 1295.57 S 713.51 W 1310.12 S 796.23 W 1322.56 S 878.70 W 1332.57 S 965.85 W 1342.31 S 1055.15 W 511.19 30.57 541.83 30.63 572.05 30.22 605.09 33.04 639.51 34.42 4263.95 3589.57 3500.00 4399.58 3689.57 3600.00 4534.54 3789.57 3700.00 4668.33 3889.57 3800.00 4800.63 3989.57 3900.00 1351.71 S 1145.16 W 1359.11 S 1236.47 W 1365.80 S 1326.86 W 1371.78 S 1415.54 W 1376.74 S 1502.01 W 674.38 34.88 710.01 35.63 744.97 34.96 778.76 33.79 811.06 32.30 4932.99 4089.57 4000.00 5064.62 4189.57 4100.00 5195.73 4289.57 4200.00 5325.24 4389.57 4300.00 5456.93 4489.57 4400.00 1381.09 S 1588.61 W 1386.14 S 1674.04 W 1391.18 S 1758.68 W 1396.37 S 1840.82 W 1403.53 S 1926.18 W 843.42 32.36 875.05 31.63 906.16 31.11 935.67 29.52 967.36 31.69 5589.68 4589.57 4500.00 5724.21 4689.57 4600.00 5858.62 4789.57 4700.00 5992.28 4889.57 4800.00 6124.89 4989.57 4900.00 1412.12 S 2013.03 W 1423.17 S 2102.34 W 1434.97 S 2191.37 W 1447.16 S 2279.19 W 1457.86 S 2365.62 W 1000.11 32.74 1034.64 34.53 1069.05 34.41 1102.71 33.65 1135.32 32.62 6255.60 5089.57 5000.00 6387.34 5189.57 5100.00 6518.92 5289.57 5200.00 6649.67 5389.57 5300.00 6780.06 5489.57 5400.00 1466.89 S 2449.31 W 1475.32 S 2534.64 W 1483.72 S 2619.75 W 1493.27 S 2703.43 W 1502.55 S 2786.59 W 1166.04 30.71 1197.77 31.73 1229.35 31.59 1260.10 30.75 1290.49 30.39 6909.90 5589.57 5500.00 7039.04 5689.57 5600.00 7168.18 5789.57 5700.00 7298.39 5889.57 5800.00 7428.17 5989.57 5900.00 1512.10 S 2868.85 W 1523.16 S 2949.81 W 1532.41 S 3030.99 W 1540.19 S 3114.02 W 1548.19 S 3196.35 W 1320.33 29.84 1349.47 29.14 1378.61 29.14 1408.82 30.21 1438.60 29.78 7558.08 6089.57 6000.00 1555.52 S 3278.95 W 1468.52 29.91 PAGE 9 RRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA SHARED SERVICES DRILLING PBU / P-21B 500292214802 NORTH SLOPE BOROUGH COMPUTATION DATE: 6/11/97 DATE OF SURVEY: 052697 JOB NUMBER: AK-MM-70116 KELLY BUSHING ELEV. = 89.57 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7688.67 6189.57 6100.00 1561.95 S 3362.67 W 1499.10 7820.91 6289.57 6200.00 1567.73 S 3449.01 W 1531.34 7952.86 6389.57 6300.00 1572.53 S 3534.94 W 1563.29 8082.24 6489.57 6400.00 1578.18 S 3616.84 W 1592.67 8213.89 6589.57 6500.00 1585.81 S 3702.12 W 1624.32 30.58 32.24 31.95 29.38 31 65 8346.75 6689.57 6600.00 1595.22 S 3789.07 W 1657.18 8480.65 6789.57 6700.00 1603.89 S 3877.69 W 1691.08 8612.00 6889.57 6800.00 1612.04 S 3962.46 W 1722.43 8743.06 6989.57 6900.00 1620.60 S 4046.74 W 1753.49 8874.55 7089.57 7000.00 1630.78 S 4131.52 W 1784.98 32 85 33.90 31 35 31.06 31 49 9004.78 7189.57 7100.00 1642.67 S 4214.06 W 1815.21 9134.75 7289.57 7200.00 1651.65 S 4296.56 W 1845.18 9268.13 7389.57 7300.00 1657.44 S 4384.62 W 1878.56 9402.48 7489.57 7400.00 1661.66 S 4474.23 W 1912.91 9534.54 7589.57 7500.00 1665.83 S 4560.34 W 1944.97 30 22 29.97 33 38 34.35 32.06 9665.64 7689.57 7600.00 1673.19 S 4644.80 W 1976.07 9797.47 7789.57 7700.00 1683.52 S 4730.07 W 2007.90 9928.61 7889.57 7800.00 1693.98 S 4814.24 W 2039.04 10059.05 7989.57 7900.00 1703.28 S 4897.47 W 2069.48 10191.95 8089.57 8000.00 1712.48 S 4984.50 W 2102.38 31.10 31.83 31.14 30.44 32.89 10325.69 8189.57 8100.00 1721.51 S 5072.85 W 2136.12 10456.23 8289.57 8200.00 1730.98 S 5156.21 W 2166.66 10585.89 8389.57 8300.00 1739.76 S 5238.28 W 2196.32 10717.07 8489.57 8400.00 1747.82 S 5322.78 W 2227.50 10847.14 8589.57 8500.00 1752.51 S 5405.73 W 2257.57 33.74 30.54 29.66 31.18 30.07 10987.62 8689.57 8600.00 1726.99 S 5500.32 W 2298.05 11149.59 8789.57 8700.00 1658.21 S 5606.74 W 2360.02 11381.86 8889.57 8800.00 1494.63 S 5735.57 W 2492.29 11772.74 8989.57 8900.00 1227.32 S 5998.60 W 2783.17 11800.00 8994.70 8905.13 1205.38 S 6013.93 W 2805.30 40.48 61.97 132.26 290.89 22.12 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS MEMORANDUM TO: David Johnsto~ Chairman THRU: Blair Wondzell, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: May 22, 1997 FILE NO: aiflevef, doc FROM: John Spaulding,~ SUBJECT: Petroleum Insp. BOPE Test Doyon 9 BPX / PBU well P-21B Prudhoe Oil Pool PTD 97-64 Thursday May 22, 1997' I traveled to BPX's Prudhoe Bay Unit to witness the BOPE Test on Doyon Rig 9. The AOGCC BOPE Test Report is attached for reference. The rig is using 2 3/8" drill pipe, and the test required more time as there were 4 floor valves that all had there own separate crossover fittings. All portions of the BOPE tested well with no failures observed. The rig was in very good condition and quite clean, and readily accessable from all areas. Summary: I witnessed the successful BOPE Test on Doyon 9, 5122197, test time 4 hours, no failures Attachments: aiflevef, xls X Unclassified Confidential (Unclassified if document removed) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 7 5/8" Test: Initial Workover: Doyon Rig No. ( 9 ) PTD# BPX Rep.: P-21B Rig Rep.: Set @ 10,404' Location: Sec. Weekly X Other DATE: 5/22/97 97-64 Rig Ph.# 659-4831 Doug Stoltz Ron Matteson 31 T. 11N R 13E Meridian Umiat TEST DATA MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location ok Standing Order Posted ok BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign ok Drl. Rig ok Hazard Sec. ok Quan. 1 Test Press. P/F 300/3,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P N/A P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan Pressure P/F 1 500/5,000 P 1 500/5,000 P 2 500/5, 000 P 2 500/5,000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes 15 Test Pressure P/F 500/5,000 P 38 500/5,000 P 2 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 5 @ 2250 avg. 3,100 P 1,800 P minutes 24 sec. minutes 0 sec. Yes Remote: Yes Psig. TEST RESULTS Number of Failures: 0 ,Test Time: ~4.0~) Hours. Number of valves tested 29 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: / Excellent test; Rig was in very good shape!!!!! Distribution: orig-Well File c- Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev.12/94) AIFLEVEF.XLS MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission David Joh~ DATE: April 23, 1997 Chairman ~ THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor ~ aifkdwee.doc FROM' Chuck Scheve, 4...,/q SUBJECT: Petroleum Inspector BOPE Test Doyon 9 PBU P-21B PTD # 97--64 Wednesday April 23 ~1997: I traveled to BPXs P Pad and witnessed the initial BOPE test on P-21B being drilled by Doyon Rig 9. As the attached AOGCC BOPE Test Report shows there was 1 failure. The casing pressure gauge on the choke panel would not work on the initial test. The diaphragm type sending unit was changed out and the gauge worked properly throughout the remaining tests. The rig was clean and all equipment seemed to be in good working order. Excellent test procedures were employed by Doyon personnel allowing the test to be completed in a minimum number of steps. The location was well organized and ali excess equipment was properly stored. Summary: I witnessed the BOPE test on Doyon Rig 9 drilling BPXs P-21B. Doyon 9, 4123197, Test Time 2.5 hours, 1 failure Attachment: aifkdweeXLS X Unclassified STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Doyon Rig No. Operator: BPX Well Name: P-21B Casing Size: Set @ Test: Initial X Weekly Other g PTD # Rep.: Rig Rep.: Location: Sec. DATE: 4/23/97 g7-64 Rig Ph.# 659-4631 Doug Stoltz Ron Mattesen 31 T. l l N R. 13E Meridian Umiat ~ ~ i TEST:DATA MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign Yes Drl. Rig OK Hazard Sec. OK BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 1 250/5,000 P 1 250/5,000 P I 250/5,000 P 1 250/5,000 ~ P Quan. Test Press. P/F Test 1 250/'3500 P Pressure P/F 250/5,000 P I 250/5,000 P f 250/5,000 P 1 250/5,000 P I 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A N/A N/A CHOKE MANIFOLD: No. Valves 15 No. Flanges Manual Chokes. 1 Hydraulic Chokes I 38 250/5,000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure MUD SYSTEM: Visual Alarm 200 psi Attained After Closure minutes 45 sec. Trip Tank OK OK System Pressure Attained 2 minutes 35 sec. Pit Level Indicators OK OK Blind Switch Covers: Master: Yes Remote: Yes Flow Indicator OK OK Nitgn. Btl's: 5 bottels at Meth Gas Detector OK OK 2300 Psig. H2S Gas Detector OK OK 3000 1300 Number of Failures: 1 ,Test Time: 2.5 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: The casing pressure gauge on the choke pannel not working sensor changed out and tested. Distribution: odg-Well File c - Oper.lRig c - Database c - Tdp Rpt File c -Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: VV'rtnessed By: Chuck Scheve F1-021L (Rev.12/94) AIFKDWEE.XLS TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 14. 1997 Dan Stoltz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 ac: Prudhoe By Unit P-21B BP Exploration (Alaska) Inc. Permit No 97-64 Sur. Loc.: 2260'NSL. 2019'EWL, Sec. 31, T1 IN. RI3E, UM Btmholc Loc: 2882'NSL. 4497'WEL, Sec. 36, TI 1N, RI2E. UM Dear Mr. Stoltz: Encloscd is thc approved application for permit to rcdrill thc above rcfcrcnccd well. The pcmfit to rcdrill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from other governmental agcncics, and does not authorize conducting drilling operations until all other required permitting dctcrnm]ations are made. Blowout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE tcst pcrformcd bcforc drilling bclow thc surface casing shoe must be given so that a representative of the Commission ma), witness the test. Notice may be givcn by contacting thc Commission pctrolcum ficld inspcctor on the North Slope Dav~-?N~''?' . BY ORDER OF T MISSION dllTench)sures cci Department of Fish & Game. I Iabitat Section w/o cncl. Deparhncnt ot'I';nvinomment Conservation w;o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 [] Drill [] Redrill Ilb' Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen~ [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE = 91.95' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028264 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2260' NSL, 2019' EWL, SEC. 31, T11N, R13E Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 904' NSL, 4000' WEL, SEC. 36, T11N, R12E P-21B Attotal depth 9. Approximate spud date Amount $200,000.00 2882' NSL, 4497' WEL, SEC. 36, T11N, R12E 04/21/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028265, 2882'I No Close Approach 2560 13913' MD 8975' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 3000' Maximum Hole Angle 108°i Maximum surface 3300 psig, At total depth (TVD) 8800' / 4390 psig 18. Casing Program Specifications Setting Depth Size 'Top Bottom Quantity of Cement ......... HoleCasing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 8-1/2" 7" i26# / 29# L-80 BTC-Mod 8601' 2850' 2576' 11451' 8877' 154 sx Class 'G' ,,, 6" 4-1/2" 12.6# L-80 IBT-Mod 2612' 11301' 8816' 13913' 8975' 212 sx Class 'G' .... 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 15460 feet Plugs (measured) true vertical 9131 feet Effective depth: measured 12226 feet Junk (measured) true vertical 7705 feet Casing Length Size Cemented M D TVD Structural Conductor 110' 20" 280 cu ft Arctic Set (Approx.) 110' 110' Surface 2959' 13-3/8" 4217 cu ft Permafrost 2997' 2670' Intermediate 12365' 9-5/8" 3025 cu ft Class 'G' 12402' 7790' Production Liner .RECEIVED Perforation depth: measured None true vertical ~.OJJ & Gas Cons. Commission · Anchorage....,., 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling ProgCam [] Ddlling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Repod [] 20 AAC 25.050 Requirements Contact Engineer Nam~N~,ber: Mark~Johnson, 564-5480 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that tye foregoing is ~t~¢and correct to the best of my knowledge Signed /' / // ~ DanStoltz ,~L //"~~~/. Title Senior Drilling Engineer Date ~' ..... ¢~--~¢,-' -~.2 Commission Use Only Permit Number J AP, Number J Approval Date J See cover,otter /~',/~_ ~' ¢ 50- dl .~ ?-- ~ 2_ / ¢-7/~' -' 4:%-~---. ,,4/' ~-/,/./~,.~ '~ for other requirements Conditions of Approval: Samples Required [] Yes ,~ No Mud Log Required [] Yes ~No Hydrogen Sulfide Measures '-~LY~s [] No Directional Survey Required '~ Yes [] No Required Working Pressure for DOPE [] 2M; []3M; D;~L 5M; [] 1OM; [] 15M Other: by order of Approved By (h-lqina. I Signed By Commissioner the commission Datec//J/ Form 10-401 Rev. 12-01-85 :: t)~vid W. Johnston Submit In Triplicate Well Name: I PBU P-21B Redrill Plan Summary I Type of Redrill (producer or injector): [ Producer Surface Location: 2260' NSL 2019' EWL S31 T11N R13E UM Target Location: 904' NSL 4000' WEL S36 T11N R12E UM Bottom Hole Location: 2882' NSL 4497' WEL S36 T11N R12E UM I AFE Number: 14P0897 I Estimated Start Date: 1 4/21/97 I I Rig: I Doyon 9 / I Operating days to complete: IMD: I13913 I ITVD: 18975 I Well Design (conventional, slimhole, etc.): I KBE: 191.95' Horizontal Sidetrack I Objective: I Target Zone 4 oil reserves with a horizontal wellbore. Mud Program: Sidetrack Mud Properties: LSND I 8 1/2" hole section Density (ppg)I Funnel Vis Yield Point [ 10 sec gel I 10 min gelI 9.4-10.4 40-55 3-10 4-10 15-25 pH Fluid Loss 8.5-9.5 6-10cc Production Mud Properties: B aradril-n Density (ppg) I Funnel visI LSRV 8.6-9.0 50-65 >45,000 cP I 6" hole section LSR YP I 10-20 pH 8.5-9.0 Directional: I I coy: 13000' MD Maximum Hole Angle: 108° Close Approach Well: NONE Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 8.5" 7" 26/29# L-80 BTC-M 8601' 2850/2576 11451/8877 6" 4 1/2" 12.6# L-80 mT-M 2612' 11301/8816 13913/8975 Tubing 4 1/2" 12.6# L-80 mx-~ 11301' 0/0 11301/8816 .RECEIVED Cement Calculations: I Liner Size: ]7" Basis:] CalCulate cement ¢olume to bring top of cement to 1000' MD above the Sag l~iver using 1 30% open hole excess, 80' shoe joint. Total Cement Volume: 33 B 154 sxs of Class G Blend @ 1.20 ft3/sx Liner Size 1 4 1/2" Basis:] CalCulate cement ¢olume to bring top of cement to 200' above 4 1/2" liner top'hanger using 30% open hole excess, 80' shoe joint. Total Cement Volume: 59 B 212 sxs of Class G Blend @ 1.56 ft3/sx Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Drilling Hazards/Contingencies · Pore pressure may be as high as 9.2 ppg EMW in the Ugnu (-4545' TVDSS) due to water disposal. Will ensure appropriate mud weight for overbalance. · Gas cut mud has been observed at 7365' TVD SS (Miluveach) and will be controlled with appropriate mud weights. In addition, tight hole conditions have been encountered in the Kingak shales at -7500 TVDSS. Mud weights as high as 10.4 ppg and the addition of shales stabilizers may be required. · P Pad is not an H2S pad. The highest H2S level on the pad is from P-4 at 69 ppm in 12/95. · Losses have been encountered drilling the Sag River, Shublik and Sadlerochit formations on other P-Pad wells. Pump LCM as necessary to control losses. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC- 2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC-2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. RECEIVED AlaS~ 0ii 8, Gas Cons. oommiSs'~on Anchorage SUMMARY REDRILL PROCEDURE: Note: This well was originally drilled in 4/91 and then sidetracked in 4/96. Both bottomhole locations had insufficient oil to complete and were suspended. TOC inside the 9 5/8" casing was last tagged at 12226' MD (7705' TVD). The casing also passed a pressure test to 3500 psi for 30 minutes. 1. Move in drilling rig. Test 9 5/8" casing to 3500 psi for 30 minutes. 2. Pull and lay down the tubing hanger and the one joint of 3-1/2" tubing in the well. 3. Set cast iron bridge plug at --3300'. Set down 15,000 lbs to test. 4. Mill 50' window in 9 5/8" from 3000-3050' MD. Spot cement kickoff plug. 5. Kickoff with 8 1/2" bit/MWD/GR and drill/build to 11451' MD (5' below TSAG) 6. Run and cement 7" liner. 7. Drill out with 6" bit/MWD/GR and TD Zone 4 horizontal section at ~13913' MD. 8. Run, cement, and perforate 4 1/2" liner. 9. Complete well with 4 1/2" L-80 IBT-mod tubing & 6 GLMs. Test. RDMO. lzZZ~, ! V4S., i(~ I1~ 'I'P N TRUE NORTH hared Service Drillin I Field: Prudhoe Bay Location :Alaska WELL PROFILE DATA .... Point .... MD Inc Dir WD North East DLS (deg/tOOft) l'ie on 3000 51.29 20,3.46 2671 -997 -432 0.00 End of Drop .3703 40.00 262.00 3183 -1294 -781 6.00 KOP 10513 40.00 262.00 8400 -1903 -5116 0.00 End of Build 10777 61.25 282.53 8567 - 1890 -5316 I 0.00 End of Hold 111,3761.25 282.55 8740 -1821 -5624 0.00 forget 11831 85.20 351.70 8965 -1354 -6021 10.00 forget 13082 85.17 351.74 9070 -121 -6200 0.00 forget 13913 107.75 521.49 8975 625 -6517 4.51 Scale 1 ' 800,00 East -> -8000 -7200 -6400 -5600 -4800 -4000 -5200 -2400 -1600 -800 0 800 1600 2400 -- 1600 - -- A 800 - II - 0 - _C - 1 k._ -800 - 0 - Z -1600- -- § -2400- ,, g - -- ~ -3200 F~ P-21 ESL P-21 Mid point NNP-21 BSL1 2400 - 1600 - 8oo A - II - 0 - Z - -800 0 - ..--4- -- 1600 --2400 ~ ., o o -3200 g -8000 -7200 -6400 -5600 -4800 -4000 -5200 -2400 -1600 -800 0 800 1600 Scale 1 ' 800.00 East -> Shared Services Drilling[ Structure: PB P Pad Well: P-21B Field · Prudhoe Bay Location :Alaska WELL PRO DATA 0 0 0 0 cO · o -800 0 ' 8OO 1600 2400 3200 4O0O 4800 5600 6400 7200 8000 8800 96OO 10400 -1600 I I I I -800 0 FILE .... Point .... MD Inc Dir '[VD North Eost BLS (deg/lOOft) Tie on 3000 51.29 203.462671 -997 -432 0.00 End of Drop 3703 40.00 262.003183 - 1294 -781 6.00 KOP 10513 40.00 262.008400 -1903 -5116 0,00 End of Build 10777 61,25 282.538567 - 1890 -5316 I 0.00 End of Hold 11137 61,25 282.538740 -1821 -5624 0.00 rarget 11831 85.20 351.708965 -1354 -6021 10.00 rorget 13082 85.17 351.749070 -121 -6200 0,00 forget 13913 107.75 321.49B975 625 -6517 4.51 Tie on I I I I I I I 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 $cc]le 1 ' 800.00 Verfical Secfion on 284.93 azimufh wifh reference 997.37 S, 431.68 W from 21B P-21 Wp12 Vertical Section RKB 284.93 89.65' MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Northing 3000.00 51.29 203.46 2580.88 2670.53 997.37s 3100.00 48.01 210.06 2645.66 2735.31 1065.39s 3200.00 45.14 217.32 2714.45 2804.10 1125.79s 3300.00 42.78 225.27 2786.48 2876.13 1177.92s 3400.00 41.01 233.86 2860.98 2950.63 1221.21s 3500.00 39.92 242.96 2937.13 3026.78 1255.18s 3600.00 39.57 252.33 3014.09 3103.74 1279.45s 3700.00 39.97 261.70 3091.02 3180.67 1293.77s 3703.27 40.00 262.00 3093.53 3183.18 1294.07s 3800.00 40.00 262.00 3167.63 3257.28 1302.72s 3900.00 40.00 262.00 3244.23 3333.88 1311.67s 4000.00 40.00 262.00 3320.83 3410.48 1320.61s 4100.00 40.00 262.00 3397.44 3487.09 1329.56s 4200.00 40.00 262.00 3474.04 3563.69 1338.50s 4300.00 40.00 262.00 3550.65 3640.30 1347.45s 4400.00 40.00 262.00 3627.25 3716.90 1356.40s 4500.00 40.00 262.00 3703.86 3793.51 1365.34s 4600.00 40.00 262.00 3780.46 3870.11 1374.29s 4700.00 40.00 262.00 3857.07 3946.72 1383.23s 4800.00 40.00 262.00 3933.67 4023.32 1392.18s 4900.00 40.00 262.00 4010.27 4099.92 1401.13s 5000.00 40.00 262.00 4086.88 4176.53 1410.07s 5100.00 40.00 262.00 4163.48 4253.13 1419.02s 5200.00 40.00 262.00 4240.09 4329.74 1427.96s 5300.00 40.00 262.00 4316.69 4406.34 1436.91s 5400.00 40.00 262.00 4393.30 4482.95 1445.86s 5500.00 40.00 262.00 4469.90 4559.55 1454.80s 5600.00 40.00 262.00 4546.51 4636.16 1463.75s 5700.00 40.00 262.00 4623.11 4712.76 1472.69s 5800.00 40.00 262.00 4699.71 4789.36 1481.64s 5900.00 40.00 262.00 4776.32 4865.97 1490.58s 6000.00 40.00 262.00 4852.92 4942.57 1499.53s 6100.00 40.00 262.00 4929.53 5019.18 1508.48s 6200.00 40.00 262.00 5006.13 5095.78 1517.42s 6300.00 40.00 262.00 5082.74 5172.39 1526.37s 6400.00 40.00 262.00 5159.34 5248.99 1535.31s 6500.00 40.00 262.00 5235.95 5325.60 1544.26s 6600.00 40.00 262.00 5312.55 5402.20 1553.21s 6700.00 40.00 262.00 5389.15 5478.80 1562.15s 12/11/96 3:06 PM Easting 431.68w 465.86w 505.99w 551.64w 602.30w 657.43w 716.41w 778.60w 780.68w 842.25w 905.90w 969.56w 1033.21 w 1096.86w 1160.52w 1224.17w 1287.82w 1351.48w 1415.13w 1478.78w 1542.44w 1606.09w 1669.74w 1733.40w 1797.05w 1860.70w 1924.36w 1988.01w 2051.66w 2115.31w 2178.97w 2242.62w 2306.27w 2369.93w 2433.58w 2497.23w 2560.89w 2624.54w 2688.19w Grid Coordinates Easting 630892.60 630859.61 630820.54 630775.81 630725.92 630671.40 630612.85 630550.93 63O548.85 630487.45 630423.97 630360.48 630297.00 630233.52 630170.04 630106.55 630043.07 629979.59 629916.11 629852.63 629789.14 629725.66 629662.18 629598.70 629535.22 629471.73 629408.25 629344.77 629281.29 629217.80 629154.32 629090.84 629027.36 628963.88 628900.39 628836.91 628773.43 628709.95 628646.46 Northing 5945984.2O 5945915.61 5945854.51 59458O1.6O 5945757.44 5945722.52 5945697.22 5945681.82 5945681.48 5945671.76 5945661.70 5945651.65 5945641.59 5945631.54 5945621.49 5945611.43 5945601.38 5945591.32 5945581.27 5945571.21 5945561.16 5945551.10 5945541.05 5945531.00 5945520.94 594551O.89 5945500.83 5945490.78 5945480.72 5945470.67 5945460.61 5945450.56 5945440.50 5945430.45 5945420.40 5945410.34 5945400.29 5945390.23 5945380.18 DLS deg/100ft 0.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 6.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0,00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 160.14 175.64 198.86 229.54 267.34 311.85 362.59 418.99 420.92 478.19 537.39 596.58 655.78 714.98 774.18 833.38 892.58 951.78 1010.98 1070.18 1129.38 1188.58 1247.78 1306.98 1366.18 1425.38 1484.58 1543.78 1602.98 1662.18 1721.38 1780.58 1839.78 1898.97 1958.17 2017.37 2076.57 2135.77 2194.97 Comment Page I of 4 P-21 Wp12 Vertical Section RKB 284.93 89.65' MD Inc. Azi. 6800.00 6900.00 7000.00 7100.00 7200.00 7300.00 7400.00 7500.00 7600.00 7700.00 7800.00 7900.00 8000.00 8100.00 8200.00 8300.00 8400.00 8500.00 8600.0O 87OO.OO 8800.00 8900.0O 9000.00 9100.00 9200.OO 9207.49 9300.00 9400.00 9500.00 9600.00 9700.00 980O.OO 9900.00 10000.00 1O10O.OO 10200.00 10300.00 10400.00 10500.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40,00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 40.00 TVDss TVDrkb Rect. Coordinates Grid Coordinates Northing Easting Easting Northing 262.00 5465.76 5555.41 1571.10S 2751.85W 628582.98 5945370.12 262.00 5542.36 5632.01 1580.04S 2815.50W 628519.50 5945360.07 262.00 5618.97 5708.62 1588.99S 2879.15W 628456.02 5945350.01 262.00 5695.57 5785.22 1597.94S 2942.81W 628392.54 5945339.96 262.00 5772.18 5861.83 1606.88S 3006.46W 628329.05 5945329.91 262.00 5848.78 5938.43 1615.83S 3070.11W 628265.57 5945319.85 262.00 5925.39 6015.04 1624.77S 3133.77W 628202.09 5945309.80 262.00 6001.99 6091.64 1633.72S 3197.42W 628138.61 5945299.74 262.00 6078.59 6168.24 1642.66S 3261.07W 628075.13 5945289.69 262.00 6155.20 6244.85 1651.61S 3324.73W 628011.64 5945279.63 262.00 6231.80 6321.45 1660.56S 3388.38W 627948.16 5945269.58 262.00 6308.41 6398.06 1669.50S 3452.03W 627884.68 5945259.52 262.00 6385.01 6474.66 1678.45S 3515.69W 627821.20 5945249.47 262.00 6461.62 6551.27 1687.39S 3579.34W 627757.71 5945239.42 262.00 6538.22 6627.87 1696.34S 3642.99W 627694.23 5945229.36 262.00 6614.83 6704.48 1705.29S 3706.65W 627630.75 5945219.31 262.00 6691.43 6781.08 1714.23S 3770.30W 627567.27 5945209.25 262.00 6768.03 6857.68 1723.18S 3833.95W 627503.79 5945199.20 262.00 6844.64 6934.29 1732.12S 3897.60W 627440.30 5945189.14 262.00 6921.24 7010.89 1741.07S 3961.26W 627376.82 5945179.09 262.00 6997.85 7087.50 1750.01S 4024.91W 627313.34 5945169.03 262.00 7074.45 7164.10 1758.96S 4088.56W 627249.86 5945158.98 262.00 7151.06 7240.71 1767.91S 4152.22W 627186.37 5945148.92 262.00 7227.66 7317.31 1776.85S 4215.87W 627122.89 5945138.87 262.00 7304.27 7393.92 1785.80S 4279.52W 627059.41 5945128.82 262.00 7310.00 7399.65 1786.47S 4284.29W 627054.66 5945128.06 262.00 7380.87 7470.52 1794.74S 4343.18W 626995.93 5945118.76 262.00 7457.47 7547.12 1803.69S 4406.83W 626932.45 5945108.71 262.00 7534.08 7623.73 1812.64S 4470.48W 626868.96 5945098.65 262.00 7610.68 7700.33 1821.58S 4534.14W 626805.48 5945088.60 262.00 7687.29 7776.94 1830.53S 4597.79W 626742.00 5945078.54 262.00 7763.89 7853.54 1839.47S 4661.44W 626678.52 5945068.49 262.00 7840.50 7930.15 1848.42S 4725.10W 626615.03 5945058.43 262.00 7917.10 8006.75 1857.37S 4788.75W 626551.55 5945048.38 262.00 7993.71 8083.36 1866.31S 4852.40W 626488.07 5945038.33 262.00 8070.31 8159.96 1875.26S 4916.06W 626424.59 5945028.27 262.00 8146.91 8236.56 1884.20S 4979.71W 626361.11 5945018.22 262.00 8223.52 8313.17 1893.15S 5043.36W 626297.62 5945008.16 262.00 8300.12 8389.77 1902.09S 5107.02W 626234.14 5944998.11 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Vertical Section 2254.17 2313.37 2372.57 2431.77 2490.97 2550.17 2609.37 2668.57 2727.77 2786.97 2846.17 2905.37 2964.57 3023.77 3082.97 3142.17 3201.36 3260.56 3319.76 3378.96 3438.16 3497.36 3556.56 3615.76 3674.96 3679.39 3734.16 3793.36 3852.56 3911.76 3970.96 4030.16 4089.36 4148.56 4207.76 4266.96 4326.16 4385.36 4444.56 Comment LCU ' 9207.49 MD 12/11/96 3:06 PM Page 2 of 4 P-21 Wp12 Vertical Section RKB 284.93 89.65' MD Inc. Azi. TVDss TVDrkb 10513.35 40.00 262.00 8310.35 8400.00 10600.00 46.57 270.27 8373.44 8463.09 10700.00 54.73 277.77 8436.85 8526.50 10776.69 61.25 282.53 8477.50 8567.15 10800.00 61.25 282.53 8488.71 8578.36 10900.00 61.25 282.53 8536.81 8626.46 11000.00 61.25 282.53 8584.91 8674.56 11100.00 61.25 282.53 8633.01 8722.66 11136.85 61.25 282.53 8650.74 8740.39 11200.00 62.09 289.64 8680.74 8770.39 11300.00 64.14 300.62 8726.06 8815.71 11400.00 66.99 311.15 8767.51 8857.16 11446.19 68.54 315.85 8785.00 8874,65 11500.00 70.50 321.20 8803.84 8893.49 11503.50 70.64 321.55 8805.00 8894.65 11600.00 74.54 330.80 8833.92 8923.57 11700.00 78.98 340.01 8856.86 8946.51 11800.00 83.69 348.93 8871.96 , 8961.61 11831.41 85.20 351.70 8875.00v/ 8964.65 11900.00 85.20 351.70 8880.74 8970.39 12000.00 85.20 351.71 8889.11 8978.76 12100.00 85.19 351.71 8897.49 8987.14 12200.00 85.19 351.71 8905.87 8995.52 12300.00 85.19 351.71 8914.26 9003.91 12400.00 85.19 351.72 8922.65 9012.30 12500.00 85.18 351.72 8931.04 9020.69 12600.00 85.18 351,72 8939.44 9029.09 12700.00 85.18 351.73 8947.84 9037.49 12800.00 85.18 351.73 8956.25 9045.90 12900.00 85.17 351.73 8964.66 9054.31 13000.00 85.17 351.74 8973.08 9062.73 13082.24 85.17 351.74 8980.00 v/ 9069.65 13100.00 85.66 351.10 8981.42 9071.07 13200.00 88.44 347.55 8986.57 9076.22 13300.00 91.22 344.01 8986.87 9076.52 13400.00 93.99 340.45 8982.33 9071.98 13500.00 96.76 336.88 8972.96 9062.61 13600.00 99.49 333.26 8958.82 9048.47 13700.00 102.10 329.58 8940.02 9029.67 12/1 Rect. Coordinates Northing Easting 1903.29s 5115.51w 1907.03s 5174.67w 1901.33s 5251.62w 1889.78s 5315.55w 1885.35s 5335.50w 1866.33s 5421.08w 1847.31s 5506.66w 1828.29s 5592.25w 1821.29s 5623.78w 1805.88s 5677.14w 1768.02s 5757.68w 1714.68s 5831.24w 1685.25s 5862.24w 1647.49s 5895.59w 1644.91 s 5897.65w 1568.49s 5948.77w 1480.08s 5989.17w 1384.94s 6015.55w 1354.13s 6020.81w 1286.50s 6030.68w 1187.89s 6045.05w 1089.28s 6059.43w 990.68s 6073.80w 892.07s 6088.16w 793.46s 6102.52w 694.85s 6116.87w 596.25s 6131.22w 497.64s 6145.56w 399.03s 6159.89w 300.42s 6174.23w 201.81s 6188.55w 120.71s 6200.33w 103.21s 6202.97w 5.09s 6221.46w 91.82n 6246.03w 186.92n 6276.51w 279,64n 6312.71w 369.39n 6354.42w 455.62n 6401.38w Grid Coordinates DLS Easting Northing de~100ff 626225.67 5944996.77 0.00 626166.59 5944992.00 10.00 626089.56 5944996.35 10.00 626025.44 5945006.78 10.00 626005.42 5945010.86 0.00 625919.53 5945028.38 0.00 625833.63 5945045.90 0.00 625747.74 5945063.42 0.00 625716.09 5945069.88 0.00 625662.47 5945084.35 10.00 625581.29 5945120.80 10.00 625506.82 5945172.84 10.00 625475.31 5945201.72 10.00 625441.31 5945238.89 10.00 625439.20 5945241.44 10.00 625386.76 5945316.95 10.00 625344.83 5945404.63 10.00 625316.79 ,5945499.28 10.00 625311.00v/ 5945530.00v/' 10.00 625299.96 5945597.44 0.00 625283.86 5945695.78 0.00 625267.77 5945794.11 0.00 625251.68 5945892.44 0.00 625235.60 5945990.78 0.00 625219.53 5946089.11 0.00 625203.46 5946187.44 0.00 625187.40 5946285.78 0.00 625171.34 5946384.11 0.00 625155.28 5946482.45 0.00 625139.23 5946580.79 0.00 625123.19 5946679.12 0.00 625110.00~ 5946760.00~ 0.00 625107.05 5946777.45 4.51 625086.85 5946875.22 4.51 625060.61 5946971.68 4.51 625028.47 5947066.23 4.51 624990.66 5947158.29 4.51 624947.39 5947247.29 4.51 624898.94 5947332.69 4.51 Vertical Section 4452.46 4508.65 4584.47 4649.22 4669.64 4757.23 4844.83 4932.42 4964.69 5020.22 5107.80 5192.62 5230.15 5272.10 5274.76 5343.84 5405.65 5455.66 5468.68 5495.64 5534.93 5574.23 5613.51 5652.80 5692.08 5731.35 5770.62 5809.88 5849.14 5888.39 5927.64 5959.92 5966.98 6010.12 6058.82 6112.78 6171.65 6235.08 6302.66 Comment Top Sag River: 11446.19 MD Top Shublik: 11503.5 MD Top Sad: 11831.41 MD P-21 Mid point 1/96 3:06 PM Page 3 of 4 P-21 Wp12 Vertical Section RKB MD Inc. 13800.00 104.80 13900.00 107.40 13912.79 107.70 284.93 89.65' Azi. TVDss TVDrkb 325.83 8916.65 9006.30 321.99 8888.86 8978.51 321.49 8885.00x~'8974.65 Rect. Coordinates Northing Easting 537.80n 6453.29w 615.43n 6509.84w 625.00n 6517.39w Grid Coordinates DLS Easting Northing deg/100ft 624845.60 5947413.94 4.51 624787.71 5947490.56 4.51 624780.00~/ 5947500.00',~ 4.51 Vertical Section 6374.00 6448.64 6458.40 P-21 ESL Comment 12/11/96 3:06 PM Page 4 of 4 S.5152_0 VENDOR I I I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I I [ ~ I [ I i , , , , I I t [ I I I I [ I I I I [ I I I I I I I I I I I I I I [ I I I I I I I I I I I [ ~ I I I I I I I I I I I I I I I ~ I I THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. m WELL PERMIT CHECKLISToo~,~ ~/o ~LL N~ ~4~/' ~---~-//4~ PROGI~..~.: e×pl-! derw redr~l~ servO wellbore segO a~. d±sp para reqO F~ELD ~ POOL ¢¢~¢01~0 IN~ 0~-~.. 'OS-,.: ,"'o,? GEOL *~.. 2'7'=' ~I~ /l~_r~ ON~OF~ S,,ORE ,¢,'J ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ........ N ll. Permit can be issued without conservation order .... N 12. Per~i~ can be issued without administrative approval. N 13. Can permit be approved before 15-day wait ....... N ENGINEERING REMARKS 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ................ Y N~ Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg.. Y CMT vol adequate to tie-in long string to surf csg . . . Y CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............ ~ ) N If a re-drill, has a 10-403 for abndnmnt been approved.~ > N Adequate wellbore separation proposed ......... t N If diverter required, is it adequate .......... N Drilling fluid program schematic & equip list adequatei~ '~'' N ~ BOPEs adequate ..................... I I N BOPE press rating adequate; test to ~ .0~...p~i N ~/ Choke manifold complies w/API RP-53 (May 84) N Work will occur without operation shutdown ...... N Is presence of H2S gas probable ........... N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ....... ./~Y N 34. Contact name/phone for weekly progress reports . .~ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION JDH_~ mcm X~:~,~i~'~''"''' Comments/Instructions: HOWldlf. A:\FORMS~cheklist rev 01/97 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 info'rmation. Date * ALASKA COMPUTING CENTER * * . ****************************** * ............................ * * ....... SCHLU~IBERGER ....... * * ............................ * ****************************** COMPANY NAME : BP EXPLORATION WELL NAME : P-21B FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API AKIf4~ER : 50-029-22148-02 REFERENCE NO : 97320 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/09/22 ORIGIN : FLIC REEL NAFIE : 97320 CONTINUATION # : PREVIOUS REEL : COMMENT : BP EXPLORATION, P-21B, PRUDHOE BAY, API #50-029-22148-02 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/09/22 ORIGIN : FLIC TAPE NAFiE : 97320 CONTINUATION # : 1 PREVIOUS TAPE : COF~4FaVT : BP EXPLORATION, P~21B, PRUDHOE BAY, API #50-029-22148-02 TAPE HEADER Prudhoe Bay OPEN HOLE WIRELINE LOGS WELL NA~E : API NO?4BER : OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN 1 97320 E. Bartz H. Haywood TOWNSHIP: RANGE: FNL: FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR '. GROUND LEVEL: WELL CASING RECORD 1ST STRING 2NDSTRING P-21 B 500292214802 BP EXPLORATION SCHLUMBERGER WELL SERVICES 22-SEP-97 RUN 2 RUN 3 .......... 31 liN 13E 2260 2019 89.62 86.87 55.72 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 5.500 11385.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE LDWG FORMATTED DATA ACQUIRED ON BP EXPLORATIONS P-21B WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAXREC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER: 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 SUMMARY LDWG TOOL CODE DTE BCS SDN CNTG $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 13082.0 11406.0 13012.0 11396.0 13056.0 11396.0 13034.0 11396.0 BASELINE DEPTH 88888.0 12967.5 12959.5 12940.5 12925.5 12923.0 12320.5 12305.0 12273.5 12266.5 12250.0 12247.0 12213.5 12197.5 12189.5 12175.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE BCS SDN CNTG 88884.0 88884.0 88884.0 12963.5 12963.5 12963.5 12963.5 12956.5 12956.5 12956.5 12956.5 12938.0 12938.0 12938.0 12938.0 12923.5 12923.5 12923.5 12923.5 12921.5 12921.5 12921.5 12921.5 12317.5 12317.5 12317.5 12317.5 12301.0 12301.0 12301 . 0 12301 . 0 12269.5 12269.5 12269.5 12269.5 12263.5 12263.5 12263 . 5 12263 . 5 12246.5 12246.5 12246.5 12246.5 12244.0 12244.0 12244.0 12244.0 12209.5 12209.5 12209.5 12209.5 12194.0 12194.0 12194.0 12194.0 12185.5 12185.5 12185.5 12185.5 12171.0 12171.0 12171.0 12171.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 12170.5 12168.0 12166.0 12165.0 12134.0 12133.5 12129.5 12128.5 12098.0 12096.5 12062.0 12060.5 12041.0 12039.0 12035.0 12032.0 12017.5 12015.0 12007.5 12005.0 12001.0 11998.0 11974.0 11972.5 11958.5 11956.0 11950.5 11949.0 11930.0 11927.5 11915.5 11914.0 11909.5 11908.0 11900.0 11897.5 11868.0 11867.0 11850.0 11849.0 11844.0 11842.0 11816.5 11814.0 11808.0 11806.0 11796.0 11794.5 11774.5 11772.5 11750.5 11749.0 11732.0 11731.0 11730.0 11728.0 11710.5 11708.0 11700.5 11697.5 11682.5 11679.5 11654.0 11651.0 11651 . 0 11647.5 11646.5 11645.5 11635.0 11635.0 11625.0 11625.0 11620.5 11619.5 11584.0 11584.0 11573.0 11573.0 11568.0 11568.0 11559.0 11558.0 11548.5 11548.0 11535.0 11534.5 11529.5 11529.5 11520.5 11520.5 11485.5 11485.5 11472.0 11475.0 11469.5 11473.0 11466.5 11469.5 11463.5 11465.5 11457.0 11457.0 11449.5 11451.5 11443.0 11445.5 11439.5 11442.0 11435.5 11438.5 12168.0 12165.0 12133.5 12128.5 12096.5 12060.5 12039.0 12032.0 12015.0 12005.0 11998.0 11972.5 11956.0 11949.0 11927.5 11914.0 11908.0 11897.5 11867.0 11849.0 11842.0 11814.0 11806.0 11794.5 11772.5 11749.0 11731.0 11728.0 11708.0 11697.5 11679.5 11651.0 11647.5 11645.5 11635.0 11625.0 11619.5 11584.0 11573.0 11568.0 11558.0 11548.0 11534.5 11529.5 11520.5 11485.5 11475.0 11473.0 11469.5 11465.5 11457.0 11451.5 11445.5 11442.0 11438.5 12168.0 12165.0 12133.5 12128.5 12096.5 12060.5 12039.0 12032 0 12015 0 12005 0 11998 0 11972 5 11956 0 11949 0 11927 5 11914 0 11908 0 11897 5 11867.0 11849.0 11842.0 11814.0 11806.0 11794.5 11772.5 11749.0 11731.0 11728.0 11708.0 11697.5 11679.5 11651.0 11647.5 11645.5 11635.0 11625.0 11619.5 11584.0 11573 0 11568 0 11558 0 11548 0 11534 5 11529 5 11520 5 11485.5 11475.0 11473.0 11469.5 11465.5 11457.0 11451.5 11445.5 11442.0 11438.5 12168.0 12165.0 12133.5 12128.5 12096.5 12060.5 12039.0 12032.0 12015.0 12005.0 11998.0 11972.5 11956.0 11949.0 11927.5 11914.0 11908.0 11897.5 11867.0 11849.0 11842.0 11814.0 11806.0 11794.5 11772.5 11749.0 11731.0 11728.0 11708.0 11697.5 11679.5 11651.0 11647.5 11645.5 11635.0 11625.0 11619.5 11584.0 11573.0 11568.0 11558.0 11548.0 11534.5 11529.5 11520.5 11485.5 11475.0 11473.0 11469.5 11465.5 11457.0 11451.5 11445.5 11442.0 11438.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 11409.0 11410.5 11410.5 11396.0 11396.5 11396.5 100.0 105.0 105.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. PASS NO. $ REMARKS: 11410.5 11410.5 11396.5 11396.5 105.0 105.0 MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED OPENHOLE LOGS. THIS DATA WAS DEPTH CORRELATED TO SPERRY SUN MWD GAI~VA RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAIVE SERV UNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 645391 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OP~4M 645391 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OHMM 645391 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE Ot{M~ 645391 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE OHM~ 645391 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~4M645391 O0 000 O0 0 1 1 1 4 68 0000000000 LiS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) SP DTE MV 645391 O0 000 O0 0 1 1 1 4 68 0000000000 TENS BCS LB 645391 O0 000 00 0 1 1 1 4 68 0000000000 TEND BCS LB 645391 O0 000 O0 0 1 1 1 4 68 0000000000 FIRES BCS 0H~645391 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMBCS DEGF 645391 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 645391 O0 000 O0 0 1 1 1 4 68 0000000000 DT BCS US/F 645391 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 645391 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 645391 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 645391 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 645391 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 645391 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 645391 O0 000 O0 0 1 1 1 4 68 0000000000 NRATCNTG 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 645391 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 645391 O0 000 O0 0 1 1 1 4 68 0000000000 F2VRA CNTG 645391 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 645391 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13084.000 ILD.DTE -999.250 ILM. DTE -999.250 SFL.DTE IDPH. DTE -999.250 IMPH.DTE -999.250 SP.DTE -999.250 TENS.BCS TEND.BCS 40.214 lVlRES.BCS 0.297 MTEM. BCS 387.300 GR.BCS DT. BCS -999.250 RHOB.SDN -999.250 DRHO.SDN -999.250 PEF. SDN CAL1.SDN -999.250 NPHI. CNTG -999.250 CPHI.CNTG -999.250 FCNT. CNTG NCNT. CNTG -999.250 CRAT. CNTG -999.250 NRAT. CNTG -999.250 CNTC. CNTG CFTC. CNTG -999.250 ENPH. CNTG -999.250 ENRA.CNTG -999.250 CFEC. CNTG DEPT. 11396.000 ILD.DTE -999.250 ILM. DTE -999.250 SFL.DTE IDPH. DTE -999.250 IMPH.DTE -999.250 SP.DTE -999.250 TENS.BCS TEND.BCS 822.344 I~RES.BCS 0.382 MTEM. BCS 222.350 GR.BCS DT. BCS 67.938 RHOB.SDN 2.730 DRHO.SDN 0.059 PEF. SDN CAL1.SDN 4.902 NPHI.CNTG 32.605 CPHI.CNTG 28.442 FCNT. CNTG NCNT. CNTG 3422.000 CRAT. CNTG 2.677 NRAT. CNTG 2.590 CNTC. CNTG CFTC. CNTG 1378.000 ENPH. CNTG 16.760 ENRA.CNTG 2.979 CFEC. CNTG -999.250 2210 000 -999 250 ~999 250 -999 250 -999 250 -999 250 -999.250 1786.438 130.750 4.794 1337.000 3297.000 1413.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE · 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION . O01CO1 DATE : 97/09/22 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 1VUM~ER : 1 DEPTH INCR_EM~2~f : 0.5000 FILE SUMMARY LDWG TOOL CODE GRCH CNTG $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (~!EASURED DEPTH) START DEPTH STOP DEPTH 11396.0 11091.0 11396.0 11091.0 BASELINE DEPTH 11396.0 11385.0 11374.5 11370.5 11348.0 11338.0 11321.5 11319.5 11317.0 11298.5 11276.0 11264.0 11238.0 11200.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 11396.5 11396.5 11386.0 11386.0 11373.5 11373.5 11370.0 11370.0 11349.0 11349.0 11340.0 11340.0 11322.0 11322.0 11320.0 11320.0 11317.5 11317.5 11302.0 11302.0 11279.0 11279.0 11267.5 11267.5 11242.0 11242.0 11204.0 11204.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 11193.5 11197.5 11197.5 11164.5 11167.5 11167,5 11151.5 11155.0 11155,0 11122.0 11127.5 11127.5 11119.5 11125.0 11125,0 11116.0 11121.0 11121.0 100.0 105.0 105,0 $ REMARKS: THIS FILE CONTAINS THE MAIN LOG GAMMA RAY AND CNTG CURVES THAT WERE ACQUIRED UP INTO CASING. ALL CURVES HAVE BEEN DEPTH CORRELATED TO SPERRY SUN MWD GAMMA RAY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAl~E 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 645391 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH BCS GAPI 645391 O0 000 O0 0 2 1 1 4 68 0000000000 TENS BCS LB 645391 O0 000 O0 0 2 1 1 4 68 0000000000 TEND BCS LB 645391 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 645391 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 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) FCNT CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 645391 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 645391 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 645391 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 11396.000 GRCH~BCS 130.750 TENS.BCS 1786.438 TEND.BCS NPHI.CNTG 32.605 CPHI.CNTG 28.442 FCNT. CNTG 1337.000 NCNT. CNTG CRAT. CNTG 2.677 NRAToCNTG 2.590 CNTC. CNTG 3297.000 CFTC. CNTG EIVPH. ClFTG 16.760 ENRAoCNTG 2.979 CFEC. CNTG 1413.000 CNEC. CNTG DEPT. 11091.000 GRCH~BCS 78.666 TENS.BCS 2610.000 TEND.BCS NPHI.CNTG 48.816 CPHIoCNTG 43.809 FCNT. CNTG 467.233 NCNT. CNTG CRAT. CNTG 3.557 NRAT~CNTG 3.461 CNTC. CNTG 1542.064 CFTC. CNTG ENPH. CNTG 50.916 ENRA~CNTG 6.340 CFEC. CNTG 513.039 CNEC. CNTG 822.344 3422.000 1378.000 4199.000 1279.548 1723.560 455.522 3252.496 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAFIE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 9 FILE HEADER FILE~ER 3 RAW OPEN HOLEMAIN 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 NUM~ER: 1 TOOL STRING NUMBER: 1 PASS NU24BER: 2 DEPTH INCRE~IENT: 0.5000 FILE SU24FL~RY VENDOR TOOL CODE START DEPTH DTE 13086.0 BHC 13018.0 LDT 13062.0 CNTG 13036.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIFiE 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 .......... 11390.0 11390.0 11390.0 11390.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAN~4A RAY BHC BOREHOLE SONIC CNTG COMP. NEUTRON DTE PHASOR INDUCTION LDT LITHO DENSITY $ 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 (OI-iM~) AT TEMPERATURE (DEGF) : MUD AT FiF~SURED TEMPERATURE (MT): 22-MAY-97 8C0-609 1130 22-MAY-97 430 23-MAY-97 13106.0 13100.0 11091.0 13084.0 1800.0 TOOL NUMBER SGH-K SDT-C CNC-GA 16 DIC-EB 262 HLDC-AA 4.750 11385.0 11396.0 N-Vis/Sea Water 8.70 43.0 9.0 205.0 0.277 108.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 10 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): 0.308 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 345 MUD CAKE AT (BHT) : 58.0 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): E P I THERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Ail tools run in combination & conveyed by drill pipe (TLC No standoffs / bowsprings / or tool turners run on string due to hole. Maximum OD of tools: 3.63" Sandstone matrix; MDEN = 2.65 g/cc used for all porosity computations. Density correction may be slightly high due tool moving from side to side. Caliper may show undergaug hole due to Density not being pad side down. Sonic is spiky due to road noise/no standoffs on tool. THIS FILE CONTAINS THE RAW OPENHOLE DATA CLIPPED AT CASING ONLY. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 216 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 11 ** SET TYPE - CHAN ** NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG 2'TPE CI. dtSS MOD~t. JMB S.~IP ELi~ CODE (HEX) DEPT FT 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP DTE I4~IHO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH DTE OH~ff4645391 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP DTE l~4~IO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH DTE OH~M645391 O0 000 O0 0 3 1 1 4 68 0000000000 Ci)ER DTE ~i~IO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IDERDTE OH~4 645391 O0 000 O0 0 3 1 1 4 68 0000000000 C~IERDTE f4MHO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 II4ER DTE OHPff4 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CDVR DTE ~ivlHO645391 O0 000 O0 0 3 1 1 4 68 0000000000 IDVR DTE Ot{~I 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CMVRDTE I4MHO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IMVRDTE OH~4M645391 O0 000 O0 0 3 1 1 4 68 0000000000 CILDDTE t4FIHO 645391 O0 000 O0 0 3 1 1 4 68 0000000000 ILD DTE Ot{MM 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CILMDTE I4M~IO645391 O0 000 O0 0 3 1 1 4 68 0000000000 ILM DTE OHMM 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IDQF DTE 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IMQF DTE 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IIRDDTE ~vi~IO645391 O0 000 O0 0 3 1 1 4 68 0000000000 IIXDDTE l~4~0 645391 O0 000 O0 0 3 1 1 4 68 0000000000 IIRMDTE ~ff4~O645391 O0 000 O0 0 3 1 1 4 68 0000000000 IIXPIDTE f~4}IO645391 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU DTE OPiMM 645391 O0 000 O0 0 3 1 1 4 68 0000000000 SP DTE MV 645391 O0 000 O0 0 3 1 1 4 68 0000000000 TENS BHC LB 645391 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMBHC DEGF 645391 O0 000 O0 0 3 1 1 4 68 0000000000 I4RES BHC 0P~4~1645391 O0 000 O0 0 3 1 1 4 68 0000000000 HTENBHC LB 645391 O0 000 O0 0 3 1 1 4 68 0000000000 GR BHCGAPI 645391 O0 000 O0 0 3 1 1 4 68 0000000000 DT BHC US/F 645391 O0 000 O0 0 3 1 1 4 68 0000000000 DPHILDT PU 645391 O0 000 O0 0 3 1 1 4 68 0000000000 RHOB LDT G/C3 645391 O0 000 O0 0 3 1 1 4 68 0000000000 DRHOLDT G/C3 645391 O0 000 O0 0 3 1 1 4 68 0000000000 PEF LDT 645391 O0 000 O0 0 3 1 1 4 68 0000000000 LSHVLDT V 645391 O0 000 O0 0 3 1 1 4 68 0000000000 SSHVLDT V 645391 O0 000 O0 0 3 1 1 4 68 0000000000 LSRHLDT G/C3 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CALI LDT IN 645391 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CArT PU 645391 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNT 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 RCEF CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 RCEN CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNT PU 645391 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH CNT PU 645391 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA CNT 645391 O0 000 O0 0 3 1 1 4 68 0000000000 RIWR CNT 645391 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR CNT PU 645391 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) RCNT CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNT CPS 645391 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. IMPH. DTE IPiER . DTE IMVR . DTE ILM. DTE I IXD . DTE SP. DTE HTEN. BHC RHOB. LDT SSHV. LDT ENRA.CNT RCEN. CNT R TNR o CNT 13102. 500 3 465 3 464 3 464 3 445 35 644 0 000 -1557 664 2 318 1173 000 3. 424 4068. 750 2. 053 4284. 956 DEPT. 11396.000 IMPH. DTE 1950.000 IMER.DTE 1950.000 IMVR.DTE 2.492 ILM.DTE 1950.000 IIXD.DTE 3141.294 SP.DTE 99.313 HTEN. BHC 843.403 RHOB.LDT 2.704 SSHV. LDT 1180.500 ENRA. CNT 2.608 RCEN. CNT 4820.152 RTATR.CNT 2.196 CNTC. CNT 4009.391 CIDP.DTE 300.134 IDPH.DTE 3.332 CIMP.DTE CDER.DTE 299. 707 IDER.DTE 3. 337 CMER.DTE CDVR.DTE 300.432 IDVR.DTE 3.329 CMVR.DTE CILD.DTE 302.551 ILD.DTE 3.305 CILM. DTE IDQF. DTE O. 000 IMQF. DTE O. 000 IIRD.DTE IIRM. DTE 271. 306 IIJ~4. DTE 15. 075 SFLU. DTE TENS.BHC 2401.000 MTEM. BHC 387.300 MRES.BHC GR.BHC 23.938 DT.BHC 75.500 DPHI.LDT DRHO.LDT 0.104 PEF.LDT 2.106 LSHV. LDT LSRH. LDT 2.214 CALI.LDT 4.264 ENPH. CNT CFEC. CNT 1253.828 CNEC. CNT 4293.610 RCEF. CNT NPHI.CNT 23.079 TNPH. CNT 22.227 TNRA.CNT NPOR.CNT 22.227 RCNT. CNT 4850.867 RCFT. CNT CFTC. CNT 2162.865 CIDP.DTE 133.708 IDPH.DTE 7.479 CIMP.DTE CDER.DTE 255.548 IDER.DTE 3. 913 CMER.DTE CDVR.DTE 749. 344 IDVR.DTE 1. 335 CMVR.DTE CILD.DTE -32. 400 ILD.DTE 1950. 000 CILM. DTE IDQF. DTE O. 000 IMQF.DTE O. 000 IIRD.DTE IIRM. DTE -443. 346 IIXM.DTE -1066. 651 SFLU. DTE TENS.BHC 1749.000 MTEM. BHC 222.809 ~RES.BHC GR.BHC 136.188 DT. BHC 64.800 DPHI.LDT DRHO.LDT 0.031 PEF.LDT 4.648 LSHV. LDT LSRH. LDT 2.673 CALI.LDT 4.890 ENPH. CNT CFEC. CNT 1853.734 CNEC. CNT 4834.599 RCEF. CNT NPHI. CNT 25.074 TNPH. CNT 23.472 TNRA.CNT NPOR.CNT 21.699 RCNT. CNT 4800.224 RCFT. CNT CFTC. CNT 1935.832 288.610 288.659 288.665 290.251 254.673 3.595 0.297 20.145 1131.500 20.532 1315.915 2.008 2301.134 -179.807 -61.819 401.283 -450.367 -22.520 7.521 0.381 -3.256 1133.000 13.865 1941.831 2.178 2065.671 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 13 **** FILE TRAILER **** FILE NAI~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUM~ER: TOOL STRING NUMBER: PASS NUM~ER: DEPTH INC~: FILE SUFmlARY FILE HEADER FILE NUMBER 4 RAW OPEN HOLEMAIN 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. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH DTE 13086.0 11390.0 BHC 13018.0 11390.0 LDT 13062.0 11390.0 CNTG 13036.0 11390.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIIKE 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 22-MAY-97 8C0-609 1130 22-MAY-97 430 23-MAY-97 13106.0 13100.0 11091.0 13084.0 1800.0 TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 14 GR GAM~A RAY BHC BOREHOLE SONIC CNTG COMP. NEUTRON DTE PHASOR INDUCTION LDT LITHO DENSITY $ 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 (OF2V~I) AT TEMPERATURE (DEGF) : MUD AT FiEASURED TE~IPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : SGH-K SDT- C CNC-GA 16 DIC-EB 262 HLDC-AA 4.750 11385.0 11396.0 N-Vis/Sea Water 8.70 43.0 9.0 205.0 0.277 108.0 0.308 58.0 0.345 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL SANDSTONE 2.65 TOOL STANDOFF (IN): 1.0 REMARKS: Ail tools run in combination & conveyed by drill pipe (TLC No standoffs / bowsprings / or tool turners run on string due to hole. Maximum OD of tools: 3.63" Sandstone matrix; FIDEN = 2.65 g/cc used for all porosity computations. Density correction may be slightly high due tool moving from side to side. Caliper may show undergaug hole due to Density not being pad side down. Sonic is spiky due to road noise/no standoffs on tool. THIS FILE CONTAINS THE RAW OPENHOLE DATA CLIPPED AT CASING ONLY. ALL CURVES SAMPLED AT 0.1667 '. $ LIS FORMAT DATA · 22-SEP-1997 12:00 PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 72 20 4 66 1 5 66 6 73 7 65 8 68 O. 166 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 NUFiB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 645391 O0 000 O0 0 4 1 1 4 68 0000000000 TT1 BHC US 645391 O0 000 O0 0 4 1 i 4 68 0000000000 TT2 BHC US 645391 O0 000 O0 0 4 1 1 4 68 0000000000 TT3 BHC US 645391 O0 000 O0 0 4 1 1 4 68 0000000000 TT4 BHC US 645391 O0 000 O0 0 4 1 1 4 68 0000000000 * * DA TA * * DEPT. 13102. 834 TT1.BHC -999.250 TT2.BHC -999.250 TT3 .BHC -999.250 TT4. BHC -999. 250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 16 **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE . 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAF~E : EDIT .005 SERVICE : FLIC VERSION · O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUFiBER: TOOL STRING NUMBER: PASS--ER: DEPTH INCREMENT: FILE SUAm~ARY FILE HEADER FILE NOY4~ER 5 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH DTE 13080.0 12820.0 BHC 13020.0 12820.0 LDT 13062.0 12820.0 CNTG 13038.0 12820.0 $ 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) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY 22-MAY-97 8C0-609 1130 22-MAY-97 430 23-MAY-97 13106.0 13100.0 11091.0 13084.0 1800.0 TOOL NUMBER SGH-K LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 17 BHC BOREHOLE SONIC CNTG COMP. NEUTRON DTE PHASOR INDUCTION LDT LITHO DENSITY $ 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 (OHlVl~) 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): SDT-C CNC-GA 16 DIC-EB 262 H LD C - AA 4.750 11385.0 11396.0 N-~s/Sea Water 8.70 43.0 9.0 205.0 0.277 108.0 0.308 58.0 O. 345 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): EPITHERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REM_ARKS: Ail tools run in combination & conveyed by drill pipe (TLC No standoffs / bowsprings / or tool turners run on string due to hole. Maximum OD of tools: 3.63" Sandstone matrix; MDEN = 2.65 g/cc used for all porosity computations. Density correction may be slightly high due tool moving from side to side. Caliper may show undergaug hole due to Density not being pad side down. Sonic is spiky due to road noise/no standoffs on tool. THIS FILE CONTAINS THE RAW OPENHOLE REPEAT DATA. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE 18 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 216 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 4 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAM~ SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELEM CODE (HEX) DEPT FT 645391 O0 000 OO 0 5 1 1 4 68 0000000000 CIDP DTE fq~lHO 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IDPH DTE 0H~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CIMP DTE F~4~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IMPH DTE 0H~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CDER DTE Fk4~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IDER DTE OH~ 645391 O0 000 O0 0 5 1 1 4 68 0000000000 CM~RDTE ~/i~0 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IMER DTE 0~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CDVRDTE ~0 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IDVRDTE 0H~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CMVRDTE ~4~0 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IMVRDTE 0Pi~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CILDDTE f~4~tO 645391 O0 000 O0 0 5 1 1 4 68 0000000000 ILD DTE 0H~645391 O0 000 O0 0 5 1 1 4 68 0000000000 CILMDTE f~4~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 ILM DTE OH~4~ 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IDQF DTE 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IMQF DTE 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IIRDDTE f~4~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IIXDDTE ~0 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IIRMDTE f~4~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 IIXMDTE f4M~O 645391 O0 000 O0 0 5 1 1 4 68 0000000000 SFLU DTE OH~f645391 O0 000 O0 0 5 1 1 4 68 0000000000 SP DTE MV 645391 O0 000 O0 0 5 1 1 4 68 0000000000 GR BHC GAPI 645391 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 19 NAME SERV UNIT SERVICE API API API API FILE NI]M~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS BHC LB 645391 MTEMBHC DEGF 645391 f4RES BHC OH~M 645391 HTENBHC LB 645391 DT BHC US/F 645391 DPHI LDT PU 645391 RHOB LDT G/C3 645391 DRHO LDT G/C3 645391 PEF LDT 645391 LSHVLDT V 645391 SSHVLDT V 645391 LSRHLDT G/C3 645391 CALI LDT IN 645391 ENPH CNT PU 645391 ENRA CNT 645391 CFEC CNT CPS 645391 CNEC CNT CPS 645391 RCEF CNT CPS 645391 RCEN CNT CPS 645391 NPHI CNT PU 645391 TNPH CNT PU 645391 TNRA CNT 645391 RTNR CNT 645391 NPOR CNT PU 645391 RCNT CNT CPS 645391 RCFT CNT CPS 645391 CNTC CNT CPS 645391 CFTC CNT CPS 645391 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13103. 000 CIDP.DTE IMPH.DTE 3.397 CDER.DTE IM~R.DTE 3. 396 CDVR.DTE IMVR.DTE 3. 396 CILD.DTE ILM. DTE 3.378 IDQF.DTE IIXD.DTE 35.179 IIRM. DTE SP.DTE O. 000 GR.BHC f4RES. BHC O . 3 69 HTEN. BHC RHOB.LDT 2. 650 DRHO.LDT SSHV. LDT 1169.500 LSRH. LDT ENRA. CNT 3.074 CFEC. CNT RCEN. CNT 4395. 880 NPHI. CNT RTNR. CNT 2.176 NPOR. CNT CNTC. CNT 4117.141 CFTC. CNT 297.325 296.881 297.547 299.704 0.000 276.597 24 295 -1381 429 0 532 2 118 1508 982 25 480 24 058 1958.775 IDPH.DTE 3. 363 CIMP.DTE IDER.DTE 3. 368 CMER.DTE IDVR.DTE 3. 361 CMVR.DTE ILD.DTE 3. 337 CILM. DTE IMQF.DTE O. 000 IIRD.DTE IIX~.DTE 15. 301 SFLU. DTE TENS.BHC 1836. 000 MTEM. BHC DT.BHC 74.300 DPHI.LDT PEF. LDT 3. 955 LSHV. LDT CALI. LDT 3.616 ENPH. CNT CNEC. CNT 4638. 820 RCEF. CNT TNPH . CNT 24.058 TNRA . CNT RCNT. CNT 4660. 889 RCFT. CNT 294.410 294. 468 294. 429 296. 025 252. 466 3 594 411 482 0 023 1130 000 17 774 1583 705 2. 129 2083. 997 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 20 DEPT. IMPH. DTE IMER . DTE IMVR . DTE ILM. DTE I IXD . DTE SP . DTE MRES.BHC RtIOB. LDT SSHV. LDT ENRA. CNT RCEN. CNT R TNR o CNT CNTCo CNT 12821.500 1.892 1.879 1.860 2.209 67.160 -29.563 0 398 2 317 1171 500 3 403 3844 276 2 186 4592 994 CIDP. DTE CDER . DTE CDVR . DTE CILD. DTE IDQF. DTE I IRM. DTE GR.BHC HTEN. BHC DRHO. LDT LSRH. LDT CFEC. CNT NPHI. CNT NPOR. CNT CFTC. CNT 480. 013 IDPH.DTE 492. 501 IDER.DTE 499. 060 IDVR.DTE 422.517 ILD. DTE O. 000 IMQF.DTE 468. 891 IIX~.DTE 24. 827 TENS.BHC 560. 272 DT. BHC O. 091 PEF. LDT 2.226 CALI. LDT 1231.1 O1 CNEC. CArT 24. 739 TNPH. CNT 22. 982 RCNT. CNT 2232. 342 2.083 CIMP. DTE 2.030 CMER . DTE 2. 004 CMVR. DTE 2.367 CILM. DTE O. 000 IIRD.DTE 32.3 O1 SFLU. DTE 1908. 000 MTEM. BHC 84 . 900 DPHI. LDT 2. 406 LSHV. LDT 4.155 ENPH. CNT 4189. 654 RCEF. CNT 23.827 TNRA . CNT 5214. 092 RCFT. CNT 528.620 532.117 537.748 452.785 377.209 2.175 316.161 20.181 1131.000 20.371 1252.261 2.111 2364.941 ** END OF DATA ** **** FILE TRAILER **** FILE NAI4E : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 6 RAW OPEN HOLEREPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SUF~T%RY VENDOR TOOL CODE START DEPTH STOP DEPTH DTE 13080.0 12820.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 21 BHC LDT CNTG $ LOG HEADER DATA 13020.0 13062.0 13038.0 12820.0 12820.0 12820.0 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 GAM~ RAY BHC BOREHOLE SONIC CNTG COMP. NEUTRON DTE PHASOR INDUCTION LDT LITHO DENSITY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS f4IID TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OHI~I~) AT TEMPERATURE (DEGF) : MUD AT MEASUR_ED 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 (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): 22-MAY-97 8C0-609 1130 22-MAY-97 430 23-MAY-97 13106.0 13100.0 11091.0 13084.0 1800.0 TOOL NUMBER SGH-K SDT-C CNC-GA 16 DIC-EB 262 HLDC-AA 4.750 11385.0 11396.0 N-Vis/Sea Water 8.70 43.0 9.0 205.0 0.277 108.0 0.308 58.0 O. 345 65.0 E P I THERMAL SANDSTONE 2.65 1.0 REMARKS: Ail tools run in combination & conveyed by drill pipe (TLC LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 22 No standoffs / bowsprings / or tool turners run on string due to hole. Maximum OD of tools: 3.63" Sandstone matrix; PiDEN = 2.65 g/cc used for all porosity computations. Density correction may be slightly high due tool moving from side to side. Caliper may show undergaug hole due to Density not being pad side down. Sonic is spiky due to road noise/no standoffs on tool. THIS FILE CONTAINS THE RAW OPENHOLE REPEAT DATA. ALL CURVES SAMPLED AT 0.1667'. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 2 3 4 66 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 20 1 O. 166 FT 51 0 FT 68 1 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 645391 O0 000 O0 0 6 1 1 4 68 0000000000 TTi BHC US 645391 O0 000 O0 0 6 1 1 4 68 0000000000 TT2 BHC US 645391 O0 000 O0 0 6 1 1 4 68 0000000000 TT3 BHC US 645391 O0 000 O0 0 6 1 1 4 68 0000000000 TT4 BHC US 645391 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 23 DEPT. 13103.334 TT4.BHC -999.250 TT1.BHC -999.250 TT2.BHC -999. 250 TT3 . BHC -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAi~E : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAi~E : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUM~ER 7 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUFff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11396.0 11091.0 CNTG 11396.0 11091.0 $ 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) : 22-MAY-97 8C0-609 1130 22-MAY-97 430 23-MAY-97 13106.0 13100.0 11091.0 13084.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 24 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GAMMA RAY SGH-K BHC BOREHOLE SONIC SDT-C CNTG COMP. NEUTRON CNC-GA 16 DTE PHASOR INDUCTION D I C- EB 262 LDT LITHO DENSITY HLDC-AA $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 4.750 11385.0 11396.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~) 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): N-Vis/Sea Water 8.70 43.0 9.0 205.0 0.277 108.0 O. 308 58.0 O. 345 65.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): EPITHERMAL MATRIX: SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REMARKS: Ail tools run in combination & conveyed by drill pipe (TLC No standoffs / bowsprings / or tool turners run on string due to hole. Maximum OD of tools: 3.63" Sandstone matrix; FiDEN = 2.65 g/cc used for all porosity computations. Density correction may be slightly high due tool moving from side to side. Caliper may show undergaug hole due to Density not being pad side down. Sonic is spiky due to road noise/no standoffs on tool. THIS FILE CONTAINS THE RAW MAIN LOGS ACQUIRED UP INTO CASING. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 25 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE 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 645391 O0 000 O0 0 7 1 1 4 68 0000000000 GRCH BHC GAPI 645391 O0 000 O0 0 7 1 1 4 68 0000000000 TENS BHC LB 645391 O0 000 O0 0 7 1 1 4 68 0000000000 HTENBHC LB 645391 O0 000 O0 0 7 1 1 4 68 0000000000 ENPH CNT PU 645391 O0 000 O0 0 7 1 1 4 68 0000000000 ENR3~ CNT 645391 O0 000 O0 0 7 1 1 4 68 0000000000 CFEC CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 CNEC CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 RCEFClFT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 RCEN CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI CNT PU 645391 O0 000 O0 0 7 1 1 4 68 0000000000 TNPH CNT PU 645391 O0 000 O0 0 7 1 1 4 68 0000000000 TIVRA CNT 645391 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR CNT 645391 O0 000 O0 0 7 1 1 4 68 0000000000 NPOR CNT PU 645391 O0 000 O0 0 7 1 1 4 68 0000000000 RCNTCNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC CNT CPS 645391 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 22-SEP-1997 12:00 PAGE: 26 DEPT. 11396. 000 GRCH. BHC ENPH . CNT 13 ~ 865 ENRA . CNT RCEF. CNT 1941. 831 RCEN. CNT TArRA . CNT 2.178 RTNR. CNT RCFT. CNT 2065. 671 CNTC. CNT DEPT. 11085.000 GRCH.BHC ENPH. CNT 50.916 ENRA . CNT RCEF. CNT 627. 915 RCEN. CNT TNRA . CNT 3. 241 R TNR . CNT RCFT. CNT 561. 341 CNTC. CNT 136.188 TENS.BHC 2.608 CFEC. CNT 4820.152 NPHI.CNT 2.196 NPOR.CNT 4009.391 CFTC. CNT 75.605 TENS.BHC 6.340 CFEC. CNT 3268.081 NPHI.CNT 3.123 NPOR.CNT 1542.064 CFTC. CNT 1749.000 1853.734 25.074 21.699 1935.832 2792.000 557.804 43.034 44.440 492.914 HTEN. BHC CNEC. CNT TNPH. CNT RCNT. CNT HTEN. BHC CNEC. CNT. TNPH. CNT RCNT. CNT 843.403 4834.599 23.472 4800.224 1201.280 3252.496 43.809 1956.362 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 97/09/22 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAFIE : EDIT DATE : 97/09/22 ORIGIN : FLIC TAPE NA~E : 97320 CONTINUATION # : 1 PREVIOUS TAPE : COM~EN~ : BP EXPLORATION, P-21B, PRUDHOE BAY, API #50-029-22148-02 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/09/22 ORIGIN : FLIC REEL NAM~ : 97320 CONTINUATION # : PREVIOUS REEL : COF~4F2~f : BP EXPLORATION, P-21B, PRUDHOE BAY, API #50-029-22148-02 Sperry-Sun Drilling Services LIS Scan Utility Tue Sep 02 08:30:33 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/02 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 ..................... 97/09/02 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: Date O I - 0 3 - 0 % RECEIVED SEP 1 0 A~ Oil & Ga~ CoD~. Commi~ioD Anchorage P-21B 500292214802 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 02-SEP-97 MWD RUN 3 MWD RUN 6 MWD RUN 7 AK-MM-70116 AK-MM-70116 AK-MM-70116 M. HALL M. HALL M. HALL J. HABERTHUR D. STOLTZ D. STOLTZ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MWD RUN 9 MWD RUN 10 AK-MM-70116 AK-M/~-70116 AK-M~-70116 M. HALL M. HALL J. FOLEY D. STOLTZ D. STOLTZ D. STOLTZ JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION MWD RUN 11 MWD RUN 13 AK-MM-70116 AK-MM-70116 M. HALL M. HALL D. STOLTZ D. STOLTZ SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 31 liN 13E 2260 2019 89.60 86.80 54.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 7.000 10491.0 5.500 11391.0 8.500 3.500 13671.0 4.750 13671.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND ARE NOT PRESENTED. 3. MWD RUN 3 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 4 AND 5 MADE NO FOOTAGE AND ARE NOT PRESENTED. 5. MWD RUNS 6 THROUGH 9 ARE DIRECTIONAL WITH NATURAL GAMMA RAY PROBE (NGP) UTILIZING SCINTILLATION DETECTOR. 6. MWD RUN 10 WAS DIRECTIONAL ONLY. 7. GAMMA RAY DATA FROM 12835'MD, 9077'TVD TO 13035'MD, 9063'TVD IS OBTAINED FROM A MEASUREMENT AFTER DRILLING (MAD) PASS PERFORMED WHILE TRIPPING IN THE HOLE FOR MWD RUN 11. 8. MWD RUN 11 THROUGH 13 WERE DIRECTIONAL WITH NATURAL G~ RAY PROBE (NGP) ~ -- UTILIZING SCINTILLATION DETECTOR. 9. DEPTH SHIFTING/CORRECTION IS WAIVED AS PER THE PHONE MESSAGE FROM D. DOUGLAS FOR DONNA MESSER OF BP EXPLORATION (ALASKA), INC. ON 06/03/97. 10. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13671'MD, 8954'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SGRD = SMOOTHED GAMMA RAY. SGRD-M= SMOOTHED GAMMA RAY OBTAINED FROM MAD PASS. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 10765.5 13600.5 ROP 10804.5 13670.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 3 10804.0 11393.0 6 11393.0 11577.0 7 11577.0 12134.0 8 12134.0 12157.0 9 12157.0 12415.0 10 12415.0 13105.0 11 13105.0 13440.0 13 13440.0 13671.0 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 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10765.5 13670.5 12218 5811 10765.5 ROP 2.973 2531.25 123.786 5733 10804.5 Last Reading 13670.5 13670.5 GR 18.3625 598.032 77.9974 4689 10765.5 13600.5 First Reading For Entire File .......... 10765.5 Last Reading For Entire File ........... 13670.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10765.5 11352.5 ROP 10804.5 11392.5 $ LOG HEADER DATA DATE LOGGED: 05-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.96 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11393.0 TOP LOG INTERVAL (FT) : 10804.0 BOTTOM LOG INTERVAL (FT): 11393.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 39.2 MTkXIMUM ANGLE: 69.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0726CG6 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) : 8.500 8.5 LSND 10.30 49.0 9.0 8O0 2.9 .000 .000 .000 -.000 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 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 61.7 First Name Min Max Mean Nsam Reading DEPT 10765.5 11392.5 11079 1255 10765.5 GR 47.6045 159.713 116.073 1175 10765.5 ROP 9.3334 1912.5 89.5395 1177 10804.5 Last Reading 11392.5 11352.5 11392.5 First Reading For Entire File .......... 10765.5 Last Reading For Entire File ........... 11392.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comraent Record FILE HEADER FILE NUMBER: 3 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 11353.5 11520.5 ROP 11393.0 11576.5 $ LOG HEADER DATA DATE LOGGED: 16-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.96 DOWNHOLE SOFTWARE VERSION: CIM 5.46 - DATA TYPE (MEMORY OR REAL-TIME): MEMORY- TD DRILLER (FT): 11577.0 TOP LOG INTERVAL (FT): 11393.0 BOTTOM LOG INTERVAL (FT): 11577.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 71.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMYIA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS TOOL NUMBER NGP 125 4.750 4.8 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 N-VI S / S EAWAT ER 8.60 35.0 9.8 19600 24.0 000 000 000 000 .-6 60.9 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 Name Min Max Mean Nsam DEPT 11353.5 11576.5 11465 447 GR 54.0873 598.032 176.014 335 ROP 2.973 1838.67 81.0723 368 First Reading 11353.5 11353.5 11393 Last Reading 11576.5 11520.5 11576.5 First Reading For Entire File .......... 11353.5 Last Reading For Entire File ........... 11576.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 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: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11506.5 ROP 11579.5 $ 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 12060.5 12131.0 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 (OHM/~) AT TEMPERATURE (DEGF) 18-MAY-97 ISC 4.96 CIM 5.46 MEMORY 12134.0 11577.0 12134.0 75.9 91.9 - TOOL NUMBER NGP 15 4.750 4.8 N-VI S / S EAWAT ER 8.60 41.0 8.5 20800 24.0 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 .000 .000 .000 .000 .6 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 63.3 First Name Min Max Mean Nsam Reading DEPT 11506.5 12131 11818.8 1250 11506.5 GR 22.7942 400 65.9224 1109 11506.5 ROP 11.524 1940.63 130.876 1104 11579.5 First Reading For Entire File .......... 11506.5 Last Reading For Entire File ........... 12131 Last Reading 12131 12060.5 12131 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 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: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12061.0 ROP 12134.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12088.0 12157.0 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 (OHMS4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 18-MAY-97 ISC 4.96 CIM 5.46 MEMORY 12157.0 12134.0 12157.0 .0 .0 TOOL NUMBER NGP 125 4.750 4.8 N-VI S / S EAWAT E R 8.80 48.0 8.5 27500 6.5 .000 .000 .000 .000 63.3 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 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 GR MWD 8 AAPI 4 1 68 4 2 ROP MWD 8 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12061 12157 12109 193 12061 GR 20.6048 32.5124 24.0736 55 12061 ROP 71.8913 117.397 98.836 47 12134 Last Reading 12157 12088 12157 First Reading For Entire File .......... 12061 Last Reading For Entire File ........... 12157 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 Maximum Physical Record..65535 File Type ................ LO Frevious 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: 9 DEPTH.INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12088.5 12343.5 ROP 12157.5 12415.0 $ LOG HEADER DATA DATE LOGGED: 19-MAY-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 4.96 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12415.0 TOP LOG INTERVAL (FT): 12157.0 BOTTOM LOG INTERVAL (FT) : 12415.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 81.6 FL~XIMUMANGLE: 83.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER NGP SPC 15 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4.750 4.8 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: N-VI S / S EAWAT ER 8.70_ 40.0 - 8.7 28500 35.0 .000 .000 .000 .000 67.8 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): .6 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 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 12088.5 12415 12251.8 654 12088.5 GR 18.3625 124.995 35.2955 511 12088.5 ROP 17.2768 306.445 110.611 516 12157.5 Last Reading 12415 12343.5 12415 First Reading For Entire File .......... 12088.5 Last Reading For Entire File ........... 12415 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 12418.0 $ 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: 13105.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NONE $ 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 Lo99ing Direction ................. Down Optical log depth units ........... Feet 21-MAY- 97 ISC 4.96 CIM 5.46 MEMORY 13105.0 12415.0 13105.0 83.7 98.2 TOOL NUMBER 4.750 4.8 N-VI S / S EAWAT ER 8.50 40.0 9.0 19400 6.8 .000 .000 _ .000- .000 72.8 .6 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 10 FT/H 4 1 68 4 2 First Name Min Max Mean Nsam Reading DEPT 12418 13105 12761.5 1375 12418 ROP 5.4151 1646.26 138.732 1375 12418 Last Reading 13105 13105 First Reading For Entire File .......... 12418 Last Reading For Entire File ........... 13105 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 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: 11 DEPTH INCREMENT: .5000 FILE SUM>iARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12835.0 13369.5 ROP 13105.5 13439.5 $ 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: 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 (OHlq~l) 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 24 -MAY- 97 ISC 4.96 CIM 5.46 MEMORY 13440.0 13105.0 13440.0 99.6 102.7 TOOL NUMBER NGP 15 4.750 4.8 N-VIS/SEAWATER 8.70 44.0 9.0 20000 6.6 .000 .000 .000 .000 -17.7 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 11 FT/H 4 1 68 ROP MWD 11 FT/H 4 1 68 Name Min Max Mean Nsam DEPT 12835 13439.5 13137.2 1210 GR 18.42 118.991 34.0141 1070 ROP 4.401 2531.25 171.809 669 First Reading 12835 12835 13105.5 Last Reading 13439.5 13369.5 13439.5 First Reading For Entire File .......... 12835 Last Reading For Entire File ........... 13439.5 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 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 ....... 97/09/02 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: 13 DEPTH INCREMENT: .5000 FILE SUM~U~RY VENDOR TOOL CODE START DEPTH GR 13370.0 ROP 13441.5 $ 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) : STOP DEPTH 13600.5 13670.5 26-MAY-97 ISC 4.96 CIM 5.46 MEMORY 13671.0 13440.0 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 (OHN~4) 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 13671.0 13574.0 100.1 TOOL NUMBER NGP 15 4.750 4.8 N-VI S / S EAWAT ER 8.80 47.0 8.8 23500 6.4 .000 .000 .000 .000 77.2 .6 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 Name Min Max Mean Nsam First Reading Last Reading DEPT 13370 13670.5 13520.2 602 GR 23.2011 440.044 99.1626 462 ROP 6.8036 1944.61 133.816 459 13370 13370 13441.5 13670.5 13600.5 13670.5 First Reading For Entire File .......... 13370 Last Reading For Entire File ........... 13670.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/02 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/02 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 ..................... 97/09/02 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
