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Home My WebLink About197-1257. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU P2-27 Install K Valve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-125 50-029-22785-00-00 14330 Conductor Surface Intermediate Production Liner 9226 80 6215 12372 2112 12206 20" 9-5/8" 7" 4-1/2" 8082 37 - 117 36 - 6251 34 - 12406 12230 - 14342 37 - 117 36 - 4949 34 - 7779 8095 - 9233 14215 1500 3090 5410 7500 none 3060 5750 7240 8430 13834 - 14066 4-1/2" 12.6# 13Cr80 13Cr80 32 - 12231 8952 - 9079 Structural 4-1/2" Baker S-3 Perm , 12185 , 8071 4-1/2" K Valve: 2198 , 2178 12185 8071 Bo York Operations Manager Eric Dickerman Eric.Dickerman@hilcorp.com (907) 564-5258 PRUDHOE BAY / PT MCINTYRE OIL Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 00365548 , 0034625 32 - 8098 0 60 0 0 0 4649 0 2014 0 733 324-119 13b. Pools active after work:PT MCINTYRE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 2:37 pm, May 07, 2024 Digitally signed by Eric Dickerman (4002) DN: cn=Eric Dickerman (4002) Date: 2024.05.07 13:36:33 - 08'00' Eric Dickerman (4002) WCB 8-27-2024 RBDMS JSB 051524 DSR-5/7/24 ACTIVITYDATE SUMMARY 4/8/2024 ***WELL S/I ON ARRIVAL*** RAN 3.80" GAUGE RING w/ 4-1/2" BRUSH TO SVLN @ 2,198' MD SET DB-K VALVE IN SVLN @ 2,198' MD (ser# k-39, 664 psi @ 60*F) ***WELL S/I ON DEPARTURE*** 4/13/2024 State Test Passed Daily Report of Well Operations PBU P2-27 State Test Passed 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No Subsequent Form Required: Approved By: Date: APPROVED BY THE AOGCCCOMMISSIONER PBU P2-27 Install K Valve Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 197-125 50-029-22785-00-00 ADL 0365548 14330 Conductor Surface Intermediate Production Liner 9226 80 6215 12372 2112 12206 20" 9-5/8" 7" 4-1/2" 8082 37 - 117 36 - 6251 34 - 12406 12230 - 14342 3104 37 - 117 36 - 4949 34 - 7779 8095 - 9233 14215 1500 3090 5410 7500 none 3060 5750 7240 8430 13834 - 14066 4-1/2" 12.6# 13Cr80 13Cr80 32 - 122318952 - 9079 Structural 4-1/2" Baker S-3 Perm , 12185 , 8071 No SSSV Installed 2198 , 2178 Date: Bo York Operations Manager Eric Dickerman Eric,Dickerman@hilcorp.com 907.564.5258 PRUDHOE BAY 3-7-24 Current Pools: PT MCINTYRE OIL Proposed Pools: PT MCINTYRE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.02.23 09:20:28 - 09'00' Bo York (1248) By Grace Christianson at 1:30 pm, Feb 29, 2024 , ADL 034625 SFD SFD 2/29/2024 DSR-3/4/24MGR20MAR24 10-404 3104 * 24 hour notice for AOGCC to witness safety valve system performance test within 5 days of stabilized production. JLC 3/21/2024 P2-27 : K Valve installa on Page 1 of 3 4Well Name:P2-27 API Number: 500292278500 Current Status:Shut in Permit to Drill Number:197125 Estimated Start Date:March 2024 Rig:Slickline Regulatory Contact:Carrie Janowski Estimated Duration:1 day First Call Engineer:Eric Dickerman Cell Number:307-250-4013 Second Call Engineer:Dave Bjork Cell Number:907-440-0331 Current Bottomhole Pressure:3,984 psi at 8,800 TVDss (from P2-60 on 3/25/2020) Maximum Potential Surface Pressure:3,104 psi (using 0.1psi/ft gradient per 20 AAC 25.280(b)(4) Brief Well Summary: P2-27 is a Kuparuk producer at Pt. Mac. The well has a damaged subsurface safety valve nipple and has utilized a subsurface controlled subsurface safety valve (K valve) to allow the well to be on production. In June 2023, attempts were made to set a surface controlled subsurface safety valve but control and balance line integrity could not be established. Therefore, a K valve will be re-set. Objective: Return well to production by setting a K valve. Wellwork Procedure: 1. MIRU slickline. 2. Set 4-1/2 K Valve at 2,198 md. 3. Hand well over to Operations to put on production. 4. Conduct an SVS test within 5 days after stabilized flow. Provide 24hr notice to AOGCC inspectors for witness. P2-27 : K Valve installa on Page 2 of 3 Wellbore Schematic: P2-27 : K Valve installa on Page 3 of 3 Proposed K Valve Design: You don't often get email from eric.dickerman@hilcorp.com. Learn why this is important From:Davies, Stephen F (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] PBU P2-27 (Permit 197-125, Sundry 324-119) - Request Date:Thursday, February 29, 2024 4:35:30 PM Attachments:image004.png image005.png image006.png image007.png image001.png image002.png P2-27 - 08-23-97 (4 1-2-in LNR).pdf Please add a copy of the email below and the attached PDF to Well History File 197-125. Thanks, Steve From: Eric Dickerman <eric.dickerman@hilcorp.com> Sent: Thursday, February 29, 2024 4:13 PM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] PBU P2-27 (Permit 197-125, Sundry 324-119) - Request Steve, If you agree, Hilcorp is going to update our database to reflect a Total Depth of 14,340’ md and will make sure that is included in the 10- 404 for this operation. In going through the drilling file, it seems like there was some confusion on the rig after running the completion. The drilling reports in our files show an original TD of 14,330’ however this was corrected throughout the file and replaced with 14,340’. The only explanation I could find was a handwritten correction on the 18 Aug 1997 drilling report (see below). I have attached the liner tally that we have on file which also shows that the production liner guide shoe made it to 14,340’. The sum of the individual liner completion components plus the drill pipe also adds up to 14,340’. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Thank you, Eric Dickerman Hilcorp – LPC OE Cell: 307-250-4013 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Thursday, February 29, 2024 1:36 PM To: Eric Dickerman <eric.dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] PBU P2-27 (Permit 197-125, Sundry 324-119) - Request CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. You don't often get email from eric.dickerman@hilcorp.com. Learn why this is important Eric, Another couple of minor questions to ensure that AOGCC’s well records are accurate. On Hilcorp’s current Sundry Application, TD for the well is given as 14,330’ MD, but the production liner is listed as reaching 14,342’ MD. The original Well Completion Report form and daily operations summary from 1997 suggest TD at 14,340’ and 14,330’ MD, respectively, and the liner bottom at 14,289’ MD: A well bore diagram submitted in 2007 indicates the liner was run to 14,340’ MD: What is the actual TD of the well and what is the MD of the bottom of the production liner? Thanks, Steve Davies AOGCC From: Eric Dickerman <eric.dickerman@hilcorp.com> Sent: Thursday, February 29, 2024 10:28 AM To: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: RE: [EXTERNAL] PBU P2-27 (Permit 197-125, Sundry 324-119) - Request I apologize for the mistake. Our regulatory tech has resubmitted the sundry request to aogcc.permitting@alaska.gov that includes the well program, wellbore schematic, and the K valve design attached. The email attached includes the resubmission. Thank you, CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Eric Dickerman Hilcorp – LPC OE Cell: 307-250-4013 From: Davies, Stephen F (OGC) <steve.davies@alaska.gov> Sent: Thursday, February 29, 2024 8:53 AM To: Eric Dickerman <eric.dickerman@hilcorp.com> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Subject: [EXTERNAL] PBU P2-27 (Permit 197-125, Sundry 324-119) - Request Eric, I’m reviewing Hilcorp’s Sundry Application for planned work on the P2-27 well. Hilcorp’s application consists of only AOGCC’s Sundry Application form. It lacks the current wellbore schematic drawing and any supporting information or work program. Could Hilcorp please supply these? Thanks and Be Well, Steve Davies Senior Petroleum Geologist AOGCC CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907-793-1224 or steve.davies@alaska.gov The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have receivedthis email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of thismessage and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus andother checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not anintended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have receivedthis email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of thismessage and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus andother checks as it considers appropriate. STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMA REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Re-enter Susp Well ❑ Other: K-Valve IZ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development ICJ 1 Exploratory ❑ 5. Permit to Drill Number: 197-125 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22785-00-00 7. Property Designation (Lease Number): ADL 0365548 8. Well Name and Number: PTM P2-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PT MCINTYRE OIL 11. Present Well Condition Summary: Total Depth: measured 14330 feet Plugs measured feet CD it EB 2 6 %01b true vertical 9226 feet Junk measured 14215 feet Effective Depth: measured 14255 feet Packer true Packer measured 12185 feet +aye vertical 9184 feet true vertical 8070.57 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 133# H-40 37 - 117 37 - 117 3060 1500 Surface 6215 9-5/8" 40# L-80 36 - 6251 36 - 4949 5750 3090 Intermediate 765 7" 29# 13Cr80 11641 - 12406 7779 - 8188 8160 7020 Production Liner 2112 4-1 /2" 12.6# 13Cr8 12230 - 14342 8095 - 9233 8430 7500 Perforation Depth: Measured depth: 13834 - 13844 feet 13855 -13895 feet 13940 -13970 feet 14010 -14066 feet True vertical depth: 8952 - 8957 feet feet 8963 - 8985 feet 9010 - 9027 feet 9049 - 9079 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 32 - 12231 32 - 8095 Packers and SSSV (type, measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2" K Valve 2198 2178 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 6, , - 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 531 14372 4300 2037 1332 Subsequent to operation: 62 2624 3015 2277 1182 14. Attachments: (required Per 20 AAC 25.070.25.071. a 25.283) 15. Well Class after work: Daily Report of Well Operations RI Exploratory ❑ Development m Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil N7 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 316-093 Contact Catron, Garry R (Wipro) Email Garry.Catron@bp.com Printed Name Catron, Garry R (Wipro) Title PDC Principal Engineer Signature Phone +1 907 564 4424 Date 2/26/16 Form 10-404 Revised 5/2015 V l L_ -Or'rlylla 31)1 1 t (- RBDMS W- FEB 19 2016 Submit Original Only I Packers and SSV's Attachment PTM SW Name Type MD TVD Depscription P2-27 SSSV 2198 2177.9 4-1/2" K Valve P2-27 TBG PACKER 12185.09 8070.57 4-1/2" Baker S-3 Perm Packer P2-27 PACKER 12229.76 8094.73 4-1/2" Liner Top Packer Daily Report of Well Operations PTM P2-27 ACTIVITYDATE SUMMARY ***WELL S/I ON ARRIVAL*** SET 4-1/2" DB-DSSSV W/MEMORY GAUGES @ 2170 SLM/2198' MD 6/28/2012 ***WELL S/I ON DEPARTURE*** ***WELL FLOWING ON ARRIVAL*** PULLED SLB SPARTEK PRESSURE TEMP GAUGES FROM SVLN @ 2164' SLM/ 2198' MD. GOOD DATA. 7/5/2012 *** WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** ***WELL SHUT IN ON ARRIVAL*** MADE SEVERAL ATTEMPTS TO PASS RESTRICTION @ 3' SLM WITH 3.85" & 3.805" GAUGE RINGS WITH NO SUCCESS. DRIFT WITH 3.77" CENT AND 3.958" BRUSH. UNABLE TO PASS 5' SLM. DRIFTED TO 54' SLM W/ 3" SAMPLE BAILER WITH NO ISSUES. BAILER RETURNED EMPTY. PUMP MEHTANOL AND BRUSH FROM 0' SLM TO 100' SLM. DRIFT TO 2200' SLM WITH 4.5" BRUSH AND 2.75" GAUGE RING. DRIFTED TUBING TO SVLN @ 2170' SLM/ 2198' MD WITH 3.85" GAUGE RING. 7/8/2012 ***CONTINUED ON 7-9-12 WSR*** ***CONTINUED FROM 7-8-12 WSR*** SET 4 1/2" K-VALVE(ser.# K-49A 838 psi @ 60*) ON DB-6 LOCK AND CARRIER IN SVLN @ 2170' SLM/ 2198' MD. GARTER SPRING ON Z6 CAME BACK IN UPPER RECESS INDICATING A GOOD SET. 7/9/2012 WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** Fluids Summary Bbls Type 4 Diesel • TREE = ? WELLHEAD = CNV ACTUATOR = BAKER C KB. ELEV = 47.9 BF. ELEV = KOP = 1656 Max Angle = 62' @ 5916 Dalian MD = 1364Y Datum TVD = 88W SS LI 9-5/8" CSG, 409, L-80, D = 8.835" ( 624W Minimum ID = 3.813" @ 2198' CAMCO BAL-O SVLN 7" CSG, 26#, L-80, D = 6.276' 1-A 11638' 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, D= 3.958" 1-4 1 TOPOF 4-1/2" LNR 7" CSG, 29#, 13CR, D = 6.184" 12403' PERFORATION SLAW RY REF LOG: SWS CET ON 12/08/97 ANGLE AT TOP PERF: 57 @ 13834' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OpnlSgz DATE 3-3/8' 6 13834- 13844 O 12/12/97 2-7/8" 6 13855 - 13895 O 06/02/01 3-318" 6 13940 - 13970 O 12/12/97 3-318" 6 14010 - 14066 O 12/12/97 F'BTD 14254' 4-1/2" LNR, 12.6#, 13CR, .0152 bpf, D = 3.458" 1434W MWA NOTES: WELL REQUIRES A SSSV. E CSG & 4-1/2" CHROM E TBG & LNR•*• 2198' 4-1/2" CAMCO BAL-O SVLN, D = 3.813" 2198' 4-1/2" K VALVE INSTALLED 07/09l12 GAS LF1' MANDRELS ST MD Jill TVD DEV I TYPE VLV I LATCH I PORE DATE 1 4377 3989 53 KBG-2-LS DOME NT 16 09/21/06 2 7321 5498 58 KBG-2-LS SO NT 22 09/2l/06 3 4 8844 10164 6298 7002 59 58 KBG-2-LS KBG-2-LS DMY DAY INT Nr 0 0 09/05/14 09/03114 5 6 11274 12004 7589 7973 59 57 KBG-2-LS KBG-2-LS DMY DA1' lNT lNT 0 0 12/15/97 09/05/14 7 12155 8054 57 KBG-2-LS DAY NT 0 12/15/97 12183' j—{ 7" X 4-1 /2" BKR S-3 PKR D = 3.875` 12206' J—j4-1/2" HES X NIP D = 3.813" 12217- 1222T' 4-1/2' WLEG, D= 3.958' 1 12214' ELtuD TT LOGGED O6/02/0t 12387- 13717- 4-1/2" HES X NP, D = 3.813" FISH - 3/4" X 5/8' XO 8 SAMPLE BALER, 1.75" FISH NECK LOOKING UP, 2.5' LONG DATE REV BY POINT MCINTY RE LW WELL: P2-27 PERMIT No: 197-1250 API No. 50-029-22785-00 Sec.14 T12N R14E 848.3 FEL 197.83 FNL COMVIEVTS DATE REV BY CONIMI YTS 12/12/97 ORIGINAL COMPLETION 02/03116 GRGTLH K VLV UPDATE PER STATE REGS 07/20/01 RNrTP CORRECTS — 1 GRCrTLH ADD PEWS (06102101) 09121106 JLJ/PAG GLV CIO 07l22107 RREC 0DN (07/10/07) BP Exploration (Alaska) 02/18l11 MBlJI4D ADDED SSSV SAFETY NOTE THE STATE 'ALASKA GOVERNOR BILL WALKER Ryan Daniel Alaska Wells Integrity and Compliance Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Pt McIntyre Oil Pool, PTM P2-27 Permit to Drill Number#°»1 Sundry Number: 316-093 Dear Mr. Daniel: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, �,4,- UTI-41 Cathy . Foerster Chair A01— DATED this day of February, 2016. RBDMS L-�- FEB [ 5 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate LJ Other Stimulate ❑ Pull Tabing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other K-Valve Design Q 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: 5. Permit to Drill Number: 197-125 3. Address: P.O. Box 196612 Anchorage, AK Exploratory ❑ Development Z 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-22785-00-00 " 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8• Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No Q PTM P2-27 9. Property Designation (Lease Number): Anl nrtr;Fsdu 10. Field/Pools: EB 0 4 201, • ....... v r r nM vrL 4 v,I J Gl 4 J // Ip 11. PRESENT WELL CONDITION SUMMARY - i Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14255 9184 14215 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 133# H-40 37 - 117 37 - 117 3060 1500 Surface 6215 9-5/8" 40# L-80 36 - 6251 36 - 4949 5750 3090 Intermediate 765 7" 29# 13Cr80 11641 - 12406 7779 - 8188 8160 7020 Production Liner 2112 4-1/2" 12.6# 13Cr80 12230 - 14342 8095 - 9233 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4-1/2" 12.6# 13Cr80 13Cr80 32 - 12231 Packers and SSSV Type: See Attachment Packers and SSSV MD (ft) and TVD (ft): See Attachment 4-1/2" K Valve 2198, 2177.90 12. Attachments: Proposal Summary B Wellbore Schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Daniel, Ryan be deviated from without prior written approval. Email Ryan. Daniel@bp.com Printed Name Daniel, Ryan Title Alaska Wells Integrty & Compliance Team Leader 441, Signature Phone +1 907 564 5430 Date k /�p/6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3o93 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No❑_. 1 Spacing Exception Required? Yes El No ll/ Subsequent Form Required: APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: Z _, (/ O JGINAL RBDMS LL- FEB Z 5 2016 Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approv�all.. 11-A16 Submit Form and Attachments in Duplicate Perforation Attachment PTM P2-27 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top P2-27 12/12/1997 PER 13834 13844 8951.96 P2-27 6/2/2001 APF 13855 13895 8963.49 P2-27 12/12/1997 PER 13940 13970 9010.2 P2-27 6/24/2006 BPP 1 14010 14066 9048.52 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BRIDGE PLUG BPP PULLED MLK MECHANICAL LEAK BRIDUE PLUG BPS SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF TVD Depth Base 8957.45 8985.47 9026.64 9079.28 i Packers and SSV s Attachment i 77 SW Name Type MD TVD Depscription P2-27 SSSV 2198 2177.9 4-1/2" K Valve P2-27 TBG PACKER 12185.09 8070.57 4-1/2" Baker S-3 Perm Packer P2-27 PACKER 12229.76 8094.73 4-1/2" Liner Top Packer Ve 4.1 6/6/01 Wireline Work Request P2-27 now tribution IrWireline 6PALUKA V8W*G d Wf116 Well: P2-27 AFE: APBWELIRSL (4) Reading File Date: 7/7/2012 Engineer: Stan Groff [OR: 400 FTS: IOR AWGRS Job Scope: K-valve for Rate H2S Level: Problem Description.................................................................. Well has been shut-in for an extended period. It now needs a K-valve to conform to AOGC regulations to produce. A pressure/temperature survey ---- was run and set pressures were based on this data. Initial Problem Review ial Plan - WIRELINE ACTION Set up and install K-valve to 838 psi @ 60" F. Well needs to flow at > 900 psi FTP. Valve set to close at approximately 800 psi FTP. Date Work Completed _ _ Well Status/Results Date Problem Resolved ? Y N by Well Review (Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC, Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth: (e.g. deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey: Follow-up Recommendations: Date: 07/07/12 Test Data "K" Valve Calculation Sheet Well # P2-27 Test Date 06/30/12 Gross Fluid Rate 3077 BLPD Flowing Well Head Pressure 1182 psi Flowing Well Head Temperature 121 deg F GOR 42328 scf/bbl TGLR 1337 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K" Valve Setting Depth TVD 2178 ft Flowing Tubing Pressure With Gas Lift 1182 psi Flowing Tubing Pressure Without Gas Lift N/A psi Valve set to close at 800# Pwh Flowing Tubing Pressure @ 600# Pwh 1302.6 psi "K" Valve Test Rack Set Pressure at 60 deg F 838 psi Valve Size & Volume Ratio 4-1/2" 1.314 NOTE: Well needs to flow at > 900# Pwh Valve set to close at 800# Pwh Tubing Pressure at Valve 1303 BPT (psis) 1317 >1238 <1238 emperature (deg F) at Valv 140.4 _ a 1.479E-05 2.45542E-05 b 1.1847592 1.1554936 Base Pressure 1140.98601 c -1338.867 -13 77.5817 Base Temp (TV-60) 80.4 1114.5636 1113.909287 Corrected Pressure 1113.90929 psia TCF 0.84553612 olume Ratio for Valve Size = 1.314 Pb @ 66-=—1 1101.73357 Test Rack Pressure = 838 Volume Ratios 4 1/2" & 5 1/2" 1.314 31/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 MES =Minimum ID = 3.813 @ 2198' CAMCOBA L-0 SVLN 4-1/2-TBG,12,6#,13CR.0152bpf,ID=3.958- 1--j 12226- P• ERFORATUN SL#JWRY W LOG: SVVS CET ON 12/08/97 I ANGLE AT TOP FEW: 57 @ 1383,V Note: Refer to Production DB for histor"I perf data mmmmg_•W 13834-1384• 13855 - 13895 13940 - 13970 • 14010 - 14066 I PBTD —L_11254!_J- 4-1/2" LW 12.6#, 13CP, .0152 bpf, 113 = 3.958* am Um 53 58 59 58 9 57 IM, m 57 12206- J--j4-1I2-FiESXNIPID=3-813- �7* 13717- 4-1/2-FESXNF,0=3.813• 'FISH 3/4*X5t8"XO&SAMPLEBALEP, POINT WINLY RE LUT WELLi P2-27 PEFMT No: 197-1250 API W -%-029-22785-00 See 14 TI 2N R1 4E 848-3 FR 197-83 FNL mms IF I.S1 g Mv z BP Exploration (Alaska) K8.2 by BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 May 20, 2012 Mr. Jim Regg t NO AUG 0 ZU"Z Alaska Oil and Gas Conservation Commission 333 West 70' Avenue Anchorage, Alaska 99501 f Subject: Corrosion Inhibitor Treatments of GPMA PM-2 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA PM-2 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 RPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) GPMA PM-2 Date: 04rAOM12 Well Name PTD # API # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date it bbls ft na gal P2-01 1970730 50029227610000 0.3 NA 0.3 NA 1.70 6/22/2009 P2-03 1970440 50029227490000 2.0 NA 2.0 NA 10.20 6/22/2009 P2-04 1981560 50029229070000 1.0 NA 1.0 NA 5.10 6/22/2009 P2-06 1931030 50029223880000 4.0 NA 4.0 NA 30.60 6AM009 P2-07 1940580 50029224690000 2.0 NA 2.0 NA 13.60 6/22/2009 P2-08A 2061690 50029228960100 0.8 NA 0.8 NA 4.30 6/21/2009 132-09 1980660 50029228760000 0.3 NA 0.3 NA 0.85 6/21/2009 P2-10 1980970 50029228860000 0.3 NA 0.3 NA 1.70 6/21/2009 P2-11A 2060260 50029229230100 3.5 NA 3.5 NA 69.70 6/21/2009 P2-12 1931150 50029223950000 Sealed conductor NA NA NA NA NA P2-13 1970600 50029227570000 0.5 NA 0.5 NA 2.60 6/21/2009 P2-14 1981050 50029228880000 1.5 NA 1.5 NA 10.20 6/21/2009 132-15A 2070320 50029224090100 Sealed conductor NA NA NA NA NA P2-16 1931230 50029223970000 3.0 NA 3.0 NA 28.10 6/20/2009 P2-17 1981370 50029229020000 0.8 NA 0.8 NA 3.40 6/20/2009 P2-18 1940600 50029224710000 0.8 NA 0.8 NA 2.60 6/20/2009 P2-19A 2070120 50029227650100 0.3 NA 0.3 NA 0.90 6/20/2009 132-20 1960590 5D029226640000 0.5 NA 0.5 NA 2.60 6/20/2009 122-21 1940530 50029224670000 0.8 NA 0.8 NA 3.40 6/20/2009 P2-22 1972490 50029228500000 1.0 NA 1.0 NA 7.70 6/20/2009 P2-23 1940320 50029224530000 1.3 NA 1.3 NA 11.10 6/20/2009 132-24 1980080 SM29228540000 1.5 NA 1.5 NA 1020 6/15/2009 P2-25 1971110 50029227760000 1.8 NA 1.8 NA 17.90 6/10/2009 132-27 1971250 50029227850000 1.3 NA 1.3 NA 8.50 6/10/2009 132-28 1950440 50029225510000 3.3 NA 3.3 NA 37.40 4/18/2012 132-29 1931470 50029224070000 10.3 NA 10.3 NA 71.40 6/15/2009 P2-30 1920950 50029222890000 2.8 NA 2.8 NA 17.90 6/10/2009 P2-31 1940360 50029224560000 2.2 NA 2.2 NA 21.30 6/20/2009 132-32 1951350 50029225930000 Surface casing leak NA NA NA NA NA P2-33B 1972310 50029228120200 2.0 NA 2.0 NA 16.60 6/9/2009 P2-34 1950660 50029225580000 1.5 NA 1.5 NA 11.50 6/9/2009 P2-35 1951790 50029226200000 1.0 NA 1.0 NA 13.60 6/9/2009 P2-36A 2060220 50029228010100 1.1 NA 1.1 NA 6.00 6/9/2009 P2-37A 2050570 50029225760100 2.0 NA 2.0 NA 23.00 6/9/2009 P2-39 2111230 50029234540000 0.8 NA 0.8 NA 10.20 4/30/2012 P2-40 1972260 50029228370000 0.5 NA 0.5 NA 5.10 6/9/2009 132-41 1952050 50029226330000 1.5 NA 1.5 NA 17.00 6/9/2009 P2-42 1931430 50029224050000 19.3 NA 19.3 NA 121.60 6/20/2009 P2-43 2050240 50029232500000 0.8 NA 0.8 NA 6.00 6/8/2009 P2-44 1960630 50029226660000 2.3 NA 2.3 NA 23.80 6/8/2009 P2-45B 2080210 50029227690200 0.8 NA 0.8 NA 5.10 6/8/2009 P2-46 1931320 50029224010000 2.3 NA 2.3 NA 25.50 6/8/2009 132-47 1951900 50029226280000 0.0 NA 0.0 NA NA NA P2-48 1921260 50029223090000 0.2 NA 02 NA 1.70 4/18/2012 P2-49 1920240 50029222520000 2.5 NA 2.5 NA 18.70 6/7/2009 132-50B 1950960 50029222610200 2.0 NA 2.0 NA 23.00 6/8/2009 P2-51 1920380 50029222620000 0.3 NA 0.3 NA 0.85 617/2009 132-52 1972010 50029228260000 3.8 NA 3.8 NA 47.60 6/7/2009 P2-53 1960410 50029226560000 2.0 NA 2.0 NA 21.30 617r"9 132-54A 2030300 50029224700100 0.8 NA 0.8 NA 3.40 6!7/2009 132-55 1920820 50029222830000 4.0 NA 4.0 NA 79.90 6/22/2009 P2-56 1951620 50029226100000 2.8 NA 2.8 NA 17.90 6/7/2009 P2-57A 2022140 50029221830100 15.5 NA 15.5 NA 77.40 6/22/2009 P2-58 1900080 50029220000000 Sealed conductor NA NA NA NA NA P2-59A 1982010 50029220960100 Sealed conductor NA NA NA NA NA P2-00 1910910 1500292219200DOI 8.3 1 NA 8.3 NA 1 56.10 1 3/1Moll 2 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth WPII .Inh it 1 n.. NO.4908 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 09/29/08 17-12 11978484 PRODUCTION PROFILE _ 09/19/08 1� 1 P2-27 12017505 PRODUCTION PROFILE _ 09/08/08 1 1 18-05A 11999048 FREE POINT INDICATOR LOG 3 09/16/08 1 1 E-36 12034922 SCMT 09/13/08 1 1 06-13A 12066547 MEM PROD PROFILE . b(p— /0 09/05/08 1 1 12-09 12083409 MEM DENSITY LOG `� _ ( 09/06/08 1 1 13-14 11978482 PROD PROFILE — -'�l 09/13/08 1 1 L-214A 11970843 INJECTION PROFILE U _ C1�4q 09/05/08 1 1 L-210 12031511 INJECTION PROFILE 09/02/08 1 1 L-216 11970842 INJECTION PROFILE — _ 09/04/08 1 1 V-221 12034920 INJECTION PROFILE 1 09/09/08 1 1 L-2051-4 40016965 OH MWD/LWD EDIT 06/26/08 (2 PRINTS & 1 CD HAND DELIVERED SEPARATELY) DI CAcc Af�ll�.lnwl cnnc ncnrnr n BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: 1(tip d { Il if, Alaska Data & Consulting Services 2525 Gambell Street, Sul 400 Anchorage, AK 9 03-2 8 ATTN: Beth — Received by. • �-M Kt'UL-1 V L—v • STATE OF ALASKA • OCT 0 4 2006 ALASKA OIL AND GAS CONSERVATION COMMIS I NJUE 6"Nfihorage &Gas Cons. Commis REPORT OF SUNDRY WELL OPERA 1. Operations Performed: Abandon[] Repair Well[] Plug Perforations❑ Stimulate ❑ Other❑X CMIT-TxIA Alter Casing❑ Pull Tubing❑ Perforate New Pool[] Waiver❑ Time Extension[] Change Approved Program[] Operation Shutdown[] Perforate ❑ Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska), Inc. Name: 4. Current Well Class: Development ❑X Exploratory[] 5. Permit to Drill Number: 7-12 0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic❑ Service[] 50-029-22785-00-00 7. KB Elevation (ft): 9. Well Name and Number: 47.90 P2-27 8. Property Designation: ADL-0365548 10. Field/Pool(s): Pt McIntyre Oil Field / Pt McIntyre Oil Pool 11. Present Well Condition Summary: Total Depth measured 14340 feet true vertical 9232.0 feet Plugs (measured) None Effective Depth measured 14254 feet Junk (measured) Fish --- Sample Bailer @ 14215 true vertical 9184.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20" 133# J-55 36 - 110 36.0 - 110.0 3060 1500 SURFACE 43 9-5/8" 40# L-80 34 - 6248 34.0 - 4947.0 5750 3090 SURFACE 3759 7" 26# L-80 32 - 11638 32.0 - 7778.0 7240 5410 PRODUCTION 10245 7" 29# 13Cr80 11638 - 12403 7778.0 - 8186.0 8160 7020 LINER 748 4-1/2" 12.6# 13Cr80 12235 - 14340 8098.0 - 9232.0 8430 7500 Perforation depth: Measured depth: 13834-13844, 13855-13895, 13940-13970, 14010-14066 True vertical depth: 8952-8957, 8963-8985, 9010-9027, 9049-9076 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# 13Cr80 @ 29 - 12227 Packers & SSSV (type & measured depth): 7" Baker S-3 Packer @ 12183 4-1/2" Cameo BAL-o SVLN @ 2198 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Daily Average Production or Infection Data Prior to well operation Subsequent to operation Oil-Bbl Gas-Mcf water-Bbl Casing Pressure Tubing Pressure 308 1654 5986 1 --- 1088 113 3668 3024 --- 1212 Copies of Logs and Surveys run _ ass after proposed work: Exploratory❑ Aus after proposed work: Development❑X Service[] Daily Report of Well Operations _ X Oil❑X Gas[] WAG ❑ GINJ❑ WINJ❑ WDSPL❑ Prepared by DeWayne R. Schnorr (907) 564-5174. 17. 1 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 DeWayne R. Schnorr I N/A Printed Name DeWayne R. Schnorr 19 Title Petroleum Engineer Signature 'A. -Ao?- Phone 564-5174 Date 10/3/06 nMIt-%IKI A I Form 1U-4U4 Revised 4/2UU4 t 1 R I U IMi L P2-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/29/2006 ** WELL SHUT IN UPON ARRIVAL**{post glv) SET 4 1/2" K-VALVE (ON CARRIER, OAL- 83", S/N- K-44A, ON DB LOCK, DOME-870 PSI @ 60 DEGREES) @ 2167, SLM. Z-6 INDICATES GOOD SET. ** TURNED WELL OVER TO DSO TO POP** 09/26/2006 BOPD: 113 BWPD: 3,024 MCFPD: 3,668 AL Rate: 1,997 09/21/2006 SET 1" DOME (16/64" 2438#) IN STA #1 @ 4349' SLM SET 1" S/O (22/64") IN STA #2 @ 7296' SLM. PULL CATCHER - EMPTY ***LEFT WELL SHUT IN*** **NOTE: OBSTRUCTION IN TBG @ 12,089' SLM, SEE PREVIOUS WSR FOR DETAILS** 09/20/2006 DRIFTED W/ 3.65 CENT, TEL, SAMPLE BAILER TO 14201' MD. SAMPLE BAILER EMPTY RAN SBHPS AS PER PROCEDURE - (GOOD DATA) ATTEMPTED TO SET 4.5" X-LOCK CATCHER, UNABLE TO PASS @ 12,166' SLM. SET 4.5" WHIDDON @ 12,092' SLM PULLED 1" DGLV FROM STA'S # 1 & 2. 09/19/2006 ***WELL SHUT IN ON ARRIVAL*** RIGGING UP SLICKLINE UNIT. 09/17/2006 PULLED 4.5" WRP @ 12165' SLM. ***WELL LEFT SHUT IN*** 09/16/2006 *** WELL SHUT IN PRIOR TO ARRIVAL *** (pre static/glv's) DRIFT W/3.80" GAUGE RING TO 12198' SLM. LATCHED WRP @ 12165' SLM, POOH W/PLUG. 09/04/2006 T/1/0=0/200/0 MIT-T to 3000 psi. - PASSED Lost 180 psi first 15 minutes, lost 40 psi second 15 minutes. Bled down to initial starting pressure. FWP's=0/200/0 08/30/2006 T/1/0=50/0/0 MIT IA to 3000 psi (PASSED) (Eval Tx IA com) Pressured IA up to 3000 psi with 61 bbls crude. MIT- IA lost 120 psi in 15 minutes and 40 psi in 2nd 15 minutes. For a 08/30/2006 T/I/0 = 0/0/0 MITIA to 3000psi. Pumped 89bbls crude down IA. No pressure increase. Will attempt at a later time. FWHP's = 0/0/0 08/29/2006 T/1/0=30/70/0+. Temp=Sl. WHP's. (Post bleed for secure). No change in TP or OAP overnight. IAP increased 10 psi overnight. 08/28/2006 T/1/0=600/1120/0. Temp=Sl. Bleed WHP's as low as possible. (Pre-FB). TBG FL @ Surface. IA FL @ 4778' between sta#1 & sta#2 (84 bbl). AL line pressure @ 1320 psi, AL SI @ IA casing valve and AL lateral valve. Bled IAP from 1120 psi to 60 psi in 6 hours 45 minutes. During IA bleed TP decreased 300 psi to 300 psi. Bled TP from 300 psi to 30 psi in 2 hours 45 minutes. 55 gallons of fluids were returned during TP bleed. OA remained @ 0 psi during bleeds. Final WHP's=30/60/0. 08/27/2006 T/1/0=550/1120/0+. Temp=Sl. A/L SI @ casing valve. Monitor WHP's. TBG pressure increased 50 psi, and the IAP increased 110 psi overnight. 08/26/2006 T/I/0 = 500/1010/0+. Temp = SI. T & IA FLs (pre FB). Tubing FL @ 3355' (above sta #1). IA FL @ 3955' (above sta #1). 2' integral flange is installed on the IA. Page 1 P2-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 08/22/2006 (secure problem well) RIH W/ 3.73 CENT. 2' X 1.875 STEM & 3.75 CENT. DRIFTED TO 12225' SLM.RIH W/ KJ,TEL & 3.75 CENT. TAG EOT @ 12211'SLM ( ELMD 12214') RIH W/ KJ, 2.75 CENT. TEL & 2.80 . TAG EOT @ 12219' SLM .RIH W/ HES ETD & 3.74" WF- WRP SET @ 12194' SLM. BLEED TUBING DOWN FROM 1000 PS1 TO 280 PSI. GOOD TEST RDMO. *** WELL LEFT S/I TURNED OVER TO DSO. *** 08/21/2006 MADE AN ATTEMPT TO SET TTP IN X-NIPP. @ 12206' MD W/ NO SUCCESS RUN KJ, 3.68" CENT, TEL, 2.80" SWEDGE LOCATE TT @ 1221 1'SLM +16' CORRECTION = 12227' MD RIH W/ 4.5 BLB & 3.80 FLUTED SWEDGE SD @ 12185' SLM +16' = 12201' MD (X-NIPPLE @ 12206' MD), UNABLE TO WORK THRU. 08/20/2006 *** WELL S/I ON ARRIVAL *** RUN 4.5" BRUSH/3.50" GAUGE RING TO X NIPPLE 12217' SLM. ATTEMPT TO RUN PX TTP, CANNOT PASS 2500'SLM. B&F TBG W/BL BRUSH & 3.805" GAUGE RING W/HOT CRUDE. UNABLE TO PASS THROUGH PKR W/3.805" GAUGE (METAL MARKS ON GAUGE RING). RIH W/PX TTP, SAT DOWN AT PKR @ 12176' SLM COULD NOT PASS THROUGH. RIH W/3.60, STEM, 3.80, STEM, 2.80" DRIFT/BARBELL SET UP. 08/16/2006 T/1/0=2030/1140/0+. Temp=Sl. Monitor WHP's (post TIFL). A/L casing valve was open. Lateral valve was shut. Shut in casing valve with 1140 psi. Tubing & OA pressure remained unchanged, IAP increased 60 psi overnight. 08/15/2006 T/1/0=2030/2270/0+. Temp=Sl. TIFL. INCONCLUSIVE (Post DGLV). IA FL @ 11096' between sta#4 & sta#5 (195 bbl). Bled IAP from 2270 psi to 1200 psi in the first hour. Heavy gas fog from DHD U/R tank, SI for FL shot. FL shot inconclusive. SI bleed for 2 hours. IAP decreased 30 psi to 1170 psi while SI. The only readable kick on the FL was the SSSV. Resumed IAP bleed for 20 minutes, Bled IAP from 1170 psi to 1030 psi. FL shot unreadable. Monitor for 1 hour. No change in TP or OAP during monitor. IAP increased 50 psi to 1080 psi during monitor. IA FL is unreadable/inconclusive. Final WHP's=2030/1080/0. 08/13/2006 SET 4 1/2" SLIP -STOP CATCHER SUB @ 10,358' SLM. PULLED LGLV & SET DGLV @ STA # 1 - 4,342', AND STA # 2 - 7,295' SLM. PULLED S/O & SET DGLV @ STA # 4 - 10,140' SLM PULLED 4 1/2" SSCS. (EMPTY) RDMO. ****LEFT WELL SHUT-IN**** 08/12/2006 **** WELL SHUT IN **** (dummy off sta's 1,2,&4) DRIFTED TO TOP OF SSSV @ 2,158' SLM. PULLED 4 1/2" K-VALVE @ 2,162' SLM. (SERIAL# K-44A) ****JOB IN PROGESS**** 08/11/2006 T/1/0=2560/2270/0+, Temp=Sl. Monitor WHP's post TIFL (eval high IAP). A/LP shut-in @ lateral valve, casing valve open to IA. IA FL is inconclusive. S/O @ 101 64'TBGP remained unchanged, IAP increased 20 psi, OAP remained unchanged. 08/10/2006 TIO= 2640/2650/0. TIFL Failed (DSO call in High IAP), K-Valve set in BVN. SI IA casing valve bled A/L spool to zero psi monitor for 10 mins no increase in psi from skid. Initial IA FL Inconclusive. Bled IAP from 2650 psi to 1500 psi in 1.5 hrs IA FL still inconclusive, (so) @ 10164' . SI bleed monitor for 1 hr. IAP increased 650 psi in 1 hr. Final WHPs= 2560/2250/0 ** Note: Notified DSO that A/L lateral SI and flagged ** Page 2 • • P2-27 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 6 Diesel --- PT Surface Equipment 340 Crude 346 ITOTAL Page 3 TREE _ ? WELLHEAD= CIW ACTUATOR = BAKER C KB. ELEV = 47.9' BF. ELEV = KOP = 1656' Max Angle = 62 @ 5916' Datum MD = 13643' Datum TV D = 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.835" 6248' Minimum ID = 3.813" @ 2198' CAMCO BAL-O SVLN, HES X NIPPLE 7" CSG, 26#, L-80, ID = 6.276" — 4-1/2" TBG, 12.6#, 13CR, .0152 bpf, ID = 3.958" 12226' TOPOF 4-1/2" LNR 12235' 7" CSG, 29#, 13CR, ID = 6.184" 12403' PERFORATION SUMMARY REF LOG: SWS CET ON 12/08/97 ANGLE AT TOP PERF: 57 @ 13834' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 13834 - 13844 O 12/12/97 2-7/8" 6 13855 - 13895 O 06/02/01 3-3/8" 6 13940 - 13970 O 12/12/97 3-3/8" 6 14010 - 14066 O 12/12/97 PBTD 14254' 4-1/2" LNR, 12.6#, 13CR, .0152 bpf, ID = 3.958" 14 14-UW P2-27 CHROME TBG & LNR*** 2198' 1-14-1/2" CAMCO BAL-O SVLN, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4377 3989 53 KBG-2-LS DOME INT 16 09/21/06 2 7321 5498 58 KBG-2-LS SO INT 22 09/21/06 3 8844 6298 59 KBG-2-LS DMY INT 0 12/12/97 4 10164 7002 58 KBG-2-LS DMY INT 0 08/13/06 5 11274 7589 59 KBG-2-LS DMY INT 0 12/15/97 6 12004 7973 57 KBG-2-LS DMY INT 0 12/15/97 7 112155180541 57 1 KBG-2-LS I DMY I INT 1 0 12/15/97 12183' 1-1 7" X 4-1 /2" BAKER S-3 PKR, ID = 3.875" 12206' 1-14-1 /2" HES X NIP, ID = 3.813" 1j 2217' I-14-1/2" HES X NIP, ID = 3.813" 12227' 5" TUBING TAIL, WLEG 12214' ELMD TT LOGGED 06/02/01 12387'-14-1/2" HES X NIP, ID = 3.813" 13717' 1 4-1 /2" HES X NIP, ID = 3.813" 14215' 1 FISH - 3/4" X 5/8" XO & SAMPLE BAILER 1.75" FISH NECK LOOKING UP, 2.5' LONG DATE REV BY COMMENTS DATE I REV BY COMMENTS 12/12/97 ORIGINAL COMPLETION 09/17/061 CJNlTLH WFDWRPPULLED 07/20/01 RN/TP CORRECTIONS 09/21/06 JLJ/PAG GLV C/O 10/18/01 GRC/TLH ADD PERFS (06/02/01) 06/24/06 JRA/PJC PULL BRIDGE PLUG 08/13/06 BSE/PJC I GLV C/O 08/22/06 GJF/TLH I SET X NIPPLE PLUG POINT MCINTYRE UNIT WELL: P2-27 PERMIT No: 197-1250 API No: 50-029-22785-00 Sec.14 T12N R14E 848.3 FEL 197.83 FNL BP Exploration (Alaska) ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development Exploratory_ RKB 47.9 feet 3. Address 7. Unit or Property name P. O. Box 196612 Stratigraphic_ Anchorage, AK 99519-6612 Service_ Point McIntyre Unit 4. Location of well at surface 8. Well number 148' FNL, 1399' FEL, Sec. 14, T12N, R14E, UM (asp's 681638, 5998437) P2-27 9. Permit number / approval number At top of productive interval 426' FNL, 1203' FEL, Sec. 12, T12N, R14E, UM (asp's 689465, 6003634) 197-125 10. API number At effective depth 50-029-22785 11. Field / Pool At total depth 197' FNL, 849' FEL, Sec. 12, T12N, R14E, UM (asp's 689813, 6003872) Point McIntyre Oil Pool 12. Present well condition summary Total depth: measured 14340 feet Plugs (measured) Tagged PBTD @ 13949' SLM on 5/25/2001. true vertical 9232 feet Through Tubing Retrievable Bridge Plug set @ 13984' MD on 121511998 Effective depth: measured 13949 feet Junk (measured) true vertical 9015 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 110, 20" 260 Sx AS 110, 110, Surface 6201' 9-5/8" 1550 Sx CS III & 612 Sx Class G 6249' 4948' Production 12355' 7" 275 Sx Class G 12403' 8186' Liner 2112' 4-1 /2" 475 Sx Class G 14340' 9232' Perforation depth: measured 13834' - 13844'; 13855' - 13895'; 13940' - 13970'; (Isolated below Bridge Plug 14010' - 14066'). true vertical 8952' - 8958'; 8964' - 8985.5'; 9010' - 9027'; (Isolated below Bridge Plug 9049' - 9079'). Tubing (size, grade, and measured depth) 4-1/2% 12.6#, 13CR-80 Tubing @ 12229' MD. R E C El V E;'-D Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker S-3 Packer @ 12183' MD. 4-1/2" Camco BAL-0 SVLN (profile damaged) @ 2198' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation5/02/2001 398 275 4236 - 839 Subsequent to operation6/04/2001 1672 1185 6213 - 834 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations X Oil _X Gas _ Suspended _ Service a to the best of my knowledge. 17. I herVew Are—is4truedorrect Signed Title: PT Mac Surveillance Engineer Date June 21, 2001. Bill M Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 • ' _^ ` SUBMIT IN DUPLICATE P2-27 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 5/25/2001: RIH w/ 2-7/8" dummy gun & tagged PBTD @ 13949' SLM. 6/02/2001: MIRU ELU. PT'd equip. RIH w/ perforating guns & tied in to SWS CET Log dated 12/08/1997. Shot 40' of add perforations in 2 separate runs as follows: 13855' - 13895' (Zones U134 & UB3) Used 2-7/8" carriers & all shots @ 6 SPF, 600 phasing, & random orientation. POOH w/ guns - ASF. RD ELU. Placed well BOL & obtained a representative welltest. Page 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001 M A T E I A L U N D E R T H IS M A R K E R C:LORIJMFILM.DOC AOGCC Geological Materials Inventory TD 1 a -r PERMIT 97-125 ARCO Log to Sent Received Box 8172 SPERRY MPT/GR/EWR4/CNP/SLD 11/12/1997 11/19/1997 CET 12100-14232 ! " i 12/23/1997 12/23/1997 DGR/CNP/SLD-MD 'cx 8532-14331 11/13/1997 11/19/1997 DGR/CNP/SLD-TVD ,V"*' 6087-9178 11/13/1997 11/19/1997 DGR/EWR4-MD ae"I' 8532-14331 11/13/1997 11/19/1997 DGR/EWR4-TVD U/1' 6135-9178 11/13/1997 11/19/1997 MWD SRVY PERRY 584-14330 9/10/1997 9/17/1997 PROD -DEFT _ � 13750-14120 9/22/1998 9/24/1998 STAT PRES SRVY t/ 13553-13922 12/23/1997 12/23/1997 ljj-407 Completion Date 1 .f�° �� Daily well ops q JAL Are dry ditch samples required? yes ::�o And received? . yes _. no Was the well cored? yes �t10 Analysis _description received? Are tests required?-..,_ �1 ncz Received? i Well is in compliance Initial Comments Wednesday, October 13, 1999 Page 1 of 1 Schlumberger GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well Job # NO. 11500 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Floppy Color Log Description Date BL RF Sepia Disk Print P2-14PB 98469 PDC GR/CCL 980621 1 1 1 P2-17 fix- �'-7 98470 CET/CBT e- 980819 1 1 1 P 2-19 PRODUCTION PROFILE 980709 1 1 P2-19 PRODUCTION PROFILE DEFT IMAGES 980709 1 1 1 P2-27 PRODUCTION PROFILE W/DEFT 980817 1 1 SIGNED: ,V.� ---- — --- k-------------------- DATE: -2 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ll,..® Oil ElGas ❑ Suspended ❑Abandoned ❑ Service 1. Status of Well Classification of Servic Ui.41 2. Name of Operator ARCO Alaska Inc. 7. Permit Number 97-125 , 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 _ 8. API Number 50-029-227 5 -77 4. Location of well at surface 148 SNL, 1399 EWL, SEC. 14, T12N, R14E, UM // At top of productive interval /-R % -� ' ` f 4857' NSL, 4069' EWL, SEC. 12, T12N, R14E, UM > At total depth rr 5081' NSL, 4416' EWL, SEC. 12, T12N, R14E, UM ' ores. Comma 9. Unit or Lease a ��+ �ht)rar.)8 Point McIntyre 10. Well Number P2-27 11. Field and Pool Point McIntyre 5. Elevation in feet (indicate KB, DF, etc.) 6. KBE = 47.9' Lease Designation and Serial No. ADL 365548 12. Date Spudded 8/5/97 13. Date T.D. Reached 8/18/97 14. Date Comp., usp., or Aband. 12/12/97 15. Water depth, if offshore N/A MSL 16. No. of Completions One 17. Total Depth (MD+TVD) 14340 9232 FT 18. Plug Back Depth (MD+TVD) 14255 9184 FT19. Directional Survey 20. ®Yes ❑No Depth where SSSV set 21. 2198' MD I Thickness of Permafrost 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, MWD, LWD, ESS, GR/RES 23. CASING LINER AND CEMENTING RECORD CASING SIZE WT. PER FT. GRADE SETTING DEPTH HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM 20" 133# H-40 36' 110, 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 6249' 12-1/4" 1550 sx Coldset III, 612 sx Class 'G' 7" 26#/29# L-80/13CR80 32' 12403' 8-1/2" 275 sx Class 'G' 4-1/2" 12.6# 13CR80 12228' 14340' 8-1/2" 475 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 spf MD TVD MD TVD 13834'-13844' 8952'-8957' 13940'-13970' 9010'-9026' 14010'-14066' 9048'-9079' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, 13CR80 12229' 12183' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 100 bbls diesel 27. PRODUCTION TEST Date First Production December 13, 1997 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS -OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 4-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL ,N91on Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids Depth Depth recovered and gravity, GOR, and time of each phase. H RZ 13790' 8928' Kalubik 13820' 8944' Ku paru k 13834' 8952' 2 � t9c 81 Alaska Oil! & U«s COM (;ommis5� Anchorage 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. 1 hereby certify that the f oing is tr e d co ect to the best of my knowledge Signed Steve Shultz Title Engineering Supervisor Date Pl97- 5 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. /Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in -situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, Other -explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Performance Enquiry Report Operator ARCO Date 02:50, 03 Dec 97 Page 1 The analysis is from - 21:30, 11 Aug 97 - to - 21:30, 11 Aug 97 Programs in Result Table: P2-27 Well Type Time From Time To Duration Description E.M.W.(equivalent mud weight) Hole Size MDR P2-27 Event 21:30, 11 Aug 97 21:30, 11 Aug 97 0 hr 0 min Obtained leak off 14.4 8-1/2 Progress Report Facility Pt Mac 2 Well P2-27 Rig Doyon 14 Date/Time Duration Activity 05 Aug 97 06:00-08:30 2-1/2 hr Installed Bell nipple 08:30-10:00 1-1/2 hr Installed Drillstring handling equipment 10:00-12:00 2 hr Installed Kelly/top drive hose 12:00-13:00 1 hr Cleared Bell nipple 13:00-15:00 2 hr Circulated at 40.0 ft 15:00-17:30 2-1/2 hr Made up BHA no. 1 17:30-18:45 1-1/4 hr Held safety meeting 18:45-19:00 1/4 hr Washed to 117.0 ft 19:00-20:00 1 hr Functioned downhole tools at 117.0 ft 20:00-21:30 1-1/2 hr Drilled to 271.0 ft 21:30-02:00 4-1/2 hr Rigged up Survey wireline unit 06 Aug 97 02:00-02:30 1/2 hr Drilled to 362.0 ft 02:30-03:00 1/2 hr Took Gyro survey at 362.0 ft 03:00-03:30 1/2 hr Drilled to 391.0 ft 03:30-04:00 1/2 hr Serviced Shaker discharge line 04:00-04:15 1/4 hr Drilled to 451.0 ft 04:15-04:45 1/2 hr Took Gyro survey at 451.0 ft 04:45-05:15 1/2 hr Drilled to 481.0 ft 05:15-06:00 3/4 hr Took Gyro survey at 481.0 ft 06:00-06:15 1/4 hr Drilled to 511.0 ft 06:15-06:45 1/2 hr Took Gyro survey at 511.0 ft 06:45-07:30 3/4 hr Drilled to 600.0 ft 07:30-08:00 1/2 hr Took Gyro survey at 600.0 ft 08:00-09:00 1 hr Drilled to 689.0 ft 09:00-10:00 1 hr Took Gyro survey at 689.0 ft 10:00-06:00 20 hr Drilled to 2274.0 ft 07 Aug 97 06:00-23:30 17-1/2 hr Drilled to 3696.0 ft 23:30-00:00 1/2 hr Circulated at 3696.0 ft 08 Aug 97 00:00-01:00 1 hr Pulled out of hole to 1600.0 ft 01:00-02:00 1 hr R.I.H. to 3696.0 ft 02:00-06:00 4 hr Drilled to 3980.0 ft 06:00-06:00 24 hr Drilled to 5715.0 ft 09 Aug 97 06:00-19:00 13 hr Drilled to 6258.0 ft 19:00-20:00 1 hr Circulated at 6258.0 ft 20:00-21:45 1-3/4 hr Pulled out of hole to 3000.0 ft 21:45-23:00 1-1/4 hr R.I.H. to 6258.0 ft 23:00-00:00 1 hr Circulated at 6285.0 ft 10 Aug 97 00:00-02:30 2-1/2 hr Pulled out of hole to 197.0 ft 02:30-05:00 2-1/2 hr Pulled BHA 05:00-06:00 1 hr Serviced Block line 06:00-07:00 1 hr Rigged up Casing handling equipment 07:00-07:15 1/4 hr Held safety meeting 07:15-14:30 7-1/4 hr Ran Casing to 6248.0 ft (9-5/8in OD) 14:30-15:45 1-1/4 hr Circulated at 6248.0 ft 15:45-16:00 1/4 hr Held safety meeting 16:00-17:30 1-1/2 hr Mixed and pumped slurry - 363.000 bbl 17:30-18:15 3/4 hr Displaced slurry - 463.000 bbl 18:15-18:30 1/4 hr Flow check 18:30-20:30 2 hr Circulated at 2024.0 ft 20:30-20:45 1/4 hr Held safety meeting 20:45-21:30 3/4 hr Mixed and pumped slurry - 290.000 bbl 21:30-22:00 1/2 hr Displaced slurry - 154.000 bbl 22:00-00:00 2 hr Removed Bell nipple 11 Aug 97 00:00-04:00 4 hr Rigged up BOP stack Page 1 Date 02 December 97 Facility Pt Mac 2 Progress Report Well P2-27 Rig Doyon 14 Date/Time Duration Activity 04:00-05:00 1 hr Removed Casing handling equipment 05:00-06:00 1 hr Tested BOP stack 06:00-10:00 4 hr Tested BOP stack 10:00-12:00 2 hr Made up BHA no. 2 12:00-13: 00 1 hr R.I.H. to 2024.0 ft 13:00-13:30 1/2 hr Drilled installed equipment - DV collar 13:30-15:30 2 hr R.I.H. to 6121.0 ft 15:30-16:30 1 hr Circulated at 6121.0 ft 16:30-17:30 1 hr Tested Casing - Via string 17:30-18:30 1 hr Held drill (Kick (well kill)) 18:30-20:00 1-1/2 hr Drilled cement to 6278.0 ft 20:00-21:00 1 hr Circulated at 6278.0 ft 21:00-21:30 1/2 hr Performed formation integrity test 21:30-06:00 8-1/2 hr Drilled to 6986.0 ft 12 Aug 97 06:00-03:00 21 hr Drilled to 8532.0 ft 13 Aug 97 03:00-04:00 1 hr Circulated at 8532.0 ft 04:00-06:00 2 hr Pulled out of hole to 3842.0 ft 06:00-07:30 1-1/2 hr Pulled out of hole to 175.0 ft 07:30-08:00 1/2 hr Pulled BHA 08:00-10:00 2 hr Made up BHA no. 3 10:00-12:00 2 hr R.I.H. to 6248.0 ft 12:00-13:00 1 hr Serviced Block line 13:00-16:00 3 hr R.I.H. to 8502.0 ft 16:00-16:30 1/2 hr Reamed to 8532.0 ft 16:30-06:00 13-1/2 hr Drilled to 9501.0 ft 14 Aug 97 06:00-04:45 22-3/4 hr Drilled to 11005.0 ft 15 Aug 97 04:45-05:30 3/4 hr Circulated at 11005.0 ft 05:30-06:00 1/2 hr Pulled out of hole to 10035.0 ft 06:00-06:30 1/2 hr Pulled out of hole to 8500.0 ft 06:30-07:30 1 hr R.I.H. to 11005.0 ft 07:30-06:00 22-1/2 hr Drilled to 12313.0 ft 16 Aug 97 06:00-04:45 22-3/4 hr Drilled to 13655.0 ft 17 Aug 97 04:45-06:00 1-1/4 hr Circulated at 13655.0 ft 06:00-09:00 3 hr Pulled out of hole to 6248.0 ft 09:00-10:00 1 hr Serviced Block line 10:00-12:45 2-3/4 hr R.I.H. to 13655.0 ft 12:45-13:00 1/4 hr Held safety meeting 13:00-13:30 1/2 hr Circulated at 13655.0 ft 13:30-01:15 11-3/4 hr Drilled to 14330.0 ft 18 Aug 97 01:15-02:15 1 hr Circulated at 14330.0 ft 02:15-03:00 3/4 hr Pulled out of hole to 13655.0 ft 03:00-03:30 1/2 hr R.I.H. to 14330.0 ft 03:30-05:00 1-1/2 hr Circulated at 14330.0 ft 05:00-06:00 1 hr Pulled out of hole to 12890.0 ft 06:00-10:30 4-1/2 hr Pulled out of hole to 185.0 ft 10:30-11:00 1/2 hr Pulled BHA 11:00-12:00 1 hr Downloaded MWD tool 12:00-12:30 1/2 hr Pulled BHA 12:30-16:00 3-1/2 hr Conducted electric cable operations 16:00-19:30 3-1/2 hr Tested BOP stack 19:30-20:00 1/2 hr Installed Bore protector 20:00-21:00 1 hr Made up BHA no. 4 21:00-22:00 1 hr Installed Kelly cocks 22:00-23:00 1 hr Made up BHA no. 4 Page 2 Date 02 December 97 Facility Pt Mac 2 Progress Report Well P2-27 Rig Doyon 14 Page 3 Date 02 December 97 Date/Time Duration Activity 23:00-02:30 3-1/2 hr R.I.H. to 6183.0 ft 19 Aug 97 02:30-03:30 1 hr Serviced Block line 03:30-06:00 2-1/2 hr R.I.H. to 10469.0 ft 06:00-07:00 1 hr R.I.H. to 13185.0 ft 07:00-10:00 3 hr R.I.H. to 13928.0 ft 10:00-13:45 3-3/4 hr Reamed to 14330.0 ft 13:45-16:00 2-1/4 hr Circulated at 14330.0 ft 16:00-01:00 9 hr Laid down 8590.0 ft of 5in OD drill pipe 20 Aug 97 01:00-02:00 1 hr Pulled BHA 02:00-02:30 1/2 hr Downloaded MWD tool 02:30-03:00 1/2 hr Pulled BHA 03:00-03:30 1/2 hr Removed Bore protector 03:30-05:00 1-1/2 hr Rigged up Casing handling equipment 05:00-05:15 1/4 hr Held safety meeting 05:15-06:00 3/4 hr Ran Casing to 280.0 ft (7in OD) 06:00-18:00 12 hr Ran Casing to 12310.0 ft (7in OD) 18:00-05:00 11 hr Worked stuck pipe at 12410.0 ft 21 Aug 97 05:00-05:30 1/2 hr Rigged up Cement unit 05:30-06:00 1/2 hr Circulated at 12410.0 ft 06:00-06:30 1/2 hr Circulated at 12410.0 ft (cont...) 06:30-06:45 1/4 hr Held safety meeting 06:45-07:15 1/2 hr Pumped Synthetic based mud spacers - volume 90.000 bbl 07:15-07:45 1/2 hr Mixed and pumped slurry - 57.500 bbl 07:45-08:15 1/2 hr Displaced slurry - 472.000 bbl 08:15-09:00 3/4 hr Tested Casing 09:00-10:00 1 hr Rigged down Casing handling equipment 10:00-13:30 3-1/2 hr Laid down 6000.0 ft of Drillpipe 13:30-14:30 1 hr Removed BOP stack 14:30-16:00 1-1/2 hr Installed Slip & seal assembly 16:00-17:00 1 hr Rigged up BOP stack 17:00-18:00 1 hr Tested Seal assembly 18:00-18:30 1/2 hr Rigged up Drill -string handling equipment 18:30-18:45 1/4 hr Held safety meeting 18:45-22:30 3-3/4 hr Serviced Top ram 22:30-01:00 2-1/2 hr Tested Top ram 22 Aug 97 01:00-01:15 1/4 hr Installed Bore protector 01:15-01:30 1/4 hr Held safety meeting 01:30-02:30 1 hr Made up BHA no. 5 02:30-06:00 3-1/2 hr Singled in drill pipe to 3500.0 ft 06:00-12:30 6-1/2 hr Singled in drill pipe to 12325.0 ft (cont...) 12:30-13:30 1 hr Circulated at 12325.0 ft 13:30-14:00 1/2 hr Tested Casing - Via annulus and string 14:00-16:00 2 hr Drilled installed equipment - Float collar 16:00-17:00 1 hr Serviced Block line 17:00-18:30 1-1/2 hr Drilled cement to 12406.0 ft 18:30-02:00 7-1/2 hr Washed to 14330.0 ft 23 Aug 97 02:00-04:00 2 hr Circulated at 14330.0 ft 04:00-04:15 1/4 hr Flow check 04:15-05:15 1 hr Pulled out of hole to 12356.0 ft 05:15-05:45 1/2 hr R.I.H. to 14330.0 ft 05:45-06:00 1/4 hr Circulated at 14330.0 ft 06:00-08:00 2 hr Circulated at 14330.0 ft (cont...) 08:00-08:30 1/2 hr Flow check 08:30-09:30 1 hr Laid down 1160.0 ft of 3-1/2in OD drill pipe Facility Pt Mac 2 Progress Report Well P2-27 Rig Doyon 14 Page 4 Date 02 December 97 Date/Time Duration Activity 09:30-09:45 1/4 hr Circulated at 13170.0 ft 09:45-13:30 3-3/4 hr Pulled out of hole to 870.0 ft 13:30-14:30 1 hr Pulled BHA 14:30-15:30 1 hr Rigged up Casing handling equipment 15:30-16:00 1/2 hr Held safety meeting 16:00-22:00 6 hr Ran Liner to 2150.0 ft (4-1/2in OD) 22:00-22:15 1/4 hr Held safety meeting 22:15-06:00 7-3/4 hr Ran Drillpipe on landing string to 12403.0 ft 24 Aug 97 06:00-08:00 2 hr Circulated at 12406.0 ft 08:00-09:30 1-1/2 hr Ran Liner in stands to 14289.0 ft 09:30-14:00 4-1/2 hr Washed to 14330.0 ft 14:00-14:15 1/4 hr Held safety meeting 14:15-15:00 3/4 hr Pumped Inhibited brine spacers - volume 90.000 bbl 15:00-15:45 3/4 hr Mixed and pumped slurry - 96.000 bbl 15:45-17:00 1-1/4 hr Displaced slurry - 115.000 bbl 17:00-17:30 1/2 hr Retrieved downhole equipment - Liner hanger 17:30-18:00 1/2 hr Circulated at 12238.0 ft 18:00-19:00 1 hr Rigged down Cement unit 19:00-22:00 3 hr Pulled out of hole to 0.0 ft 22:00-00:30 2-1/2 hr Made up BHA no. 6 25 Aug 97 00:30-04:00 3-1/2 hr R.I.H. to 9240.0 ft 04:00-05:00 1 hr Fished at 9240.0 ft 05:00-06:00 1 hr Circulated at 12238.0 ft 06:00-06:30 1/2 hr Circulated at 12238.0 ft (cont...) 06:30-10:00 3-1/2 hr Pulled out of hole to 2895.0 ft 10:00-10:45 3/4 hr Laid down fish 10:45-12:15 1-1/2 hr Pulled out of hole to 15.0 ft 12:15-12:30 1/4 hr Pulled BHA 12:30-14:30 2 hr R.I.H. to 5000.0 ft 14:30-15:30 1 hr Serviced Block line 15:30-18:30 3 hr R.I.H. to 12238.0 ft 18:30-21:00 2-1/2 hr Functioned downhole tools at 12230.0 ft 21:00-22:00 1 hr Functioned Tie back packer 22:00-00:00 2 hr Reverse circulated at 12225.0 ft 26 Aug 97 00:00-02:00 2 hr Flow check 02:00-03:00 1 hr Reverse circulated at 12225.0 ft 03:00-06:00 3 hr Laid down 5000.0 ft of 3-1/2in OD drill pipe 06:00-10:00 4 hr Laid down 11000.0 ft of 3-1/2in OD drill pipe (cont...) 10:00-11:00 1 hr Tested Casing - Via annulus and string 11:00-12:00 1 hr Laid down 1085.0 ft of 3-112in OD drill pipe 12:00-12:15 1/4 hr Pulled BHA 12:15-14:30 2-1/4 hr Worked on BOP - Top ram 14:30-14:45 1/4 hr Held safety meeting 14:45-18:00 3-1/4 hr Ran Tubing to 3150.0 ft (4-1/2in OD) 18:00-18:30 1/2 hr Held safety meeting 18:30-20:00 1-1/2 hr Repaired Tubing handling equipment 20:00-20:30 1/2 hr Ran Tubing to 7500.0 ft (4-1/2in OD) 20:30-21:00 1/2 hr Repaired Tubing handling equipment 21:00-06:00 9 hr Ran Tubing to 4-1 /2in (10500.0 ft OD) 27 Aug 97 06:00-07:00 1 hr Ran Tubing to 10600.0 ft (4-1/2in OD) (cont...) 07:00-08:00 1 hr Installed SCSSSV nipple assembly 08:00-12:30 4-1/2 hr Ran Tubing to 12194.0 ft (4-1/2in OD) 12:30-14:00 1-1/2 hr Space out tubulars 14:00-15:30 1-1/2 hr Installed Tubing hanger Facility Pt Mac 2 Progress Report Well P2-27 Rig Doyon 14 Date/Time Duration Activity 15:30-22:30 7 hr Laid down 2120.0 ft of Tubing 22:30-00:30 2 hr Installed SCSSSV control line 28 Aug 97 00:30-05:00 4-1/2 hr Ran Tubing to 12223.0 ft (4-1/2in OD) 05:00-06:00 1 hr Installed Tubing hanger 06:00-07:30 1-1/2 hr Installed Tubing hanger (cont...) 07:30-08:30 1 hr Reverse circulated at 12228.0 ft 08:30-09:00 1/2 hr Rigged down Tubing handling equipment 09:00-12:15 3-1/4 hr Rigged down All functions 12:15-14:30 2-1/4 hr Installed Xmas tree 14:30-15:30 1 hr Prepare mouse/rat hole 15:30-18:30 3 hr Rig moved 100.00 % Page 5 Date 02 December 97 81-15-98 09:25A P.06 r , UM - HKUU HLHbKH FRX NU.'. 9072634894 - EL Well Work Log Date 12/12/97 Descriptit,ii 3 3/8" HSD, 6SPF-DP PERFORATE (IN PROGRESS) DS-Well P2-27 FTP/ITP PSI IA PSI 7FRO OA PSI 150 psi SITP ZERO13'@ riD 13987' SSSV nipple CAMCO BAL-O SSSV Information OOH Tubular or Casing Problems PBTD CIE #j,, SWS ✓ S22,373 C/E#2 CIE #3 CIE #4 CIE #5 Diesel (Recov.) Diesel (non RecoN AFE # 2BO210 CC# PMDS009DH Class y3<) Activity Time Log Entry 09:00 MIRU SWS UNIT 8293: FNG:.JOHNSON 11:30 PRESURE TEST BOP/RISER TO 3000# 11,45 RIH WITH CCL/26' 3 3/8" HSD,6 SPF PERF GUN 12:40 TIE INTO CET DATED 12/8/97 13:05 SHOOT 14040-14066 TBG PRESS AFTER SHOOTING= 910 PSI 15:00 IRIH WITH CCL/30' 3 3/8" HSD,6 SPF PERF GUN 16:15 SHOOT 14010-14040 17:45 RIH WITH CCL/30' 3 3/8" HSD,6 SPF PERF GUN 19:05 ISHOOT13940-13970 19:15 POOH 20:00 AT SURFACE, RIG DOWN FOR NIGHT Results Summary - Address each objective listed in Job request - e. a. splits. GOC pick, channels, etc PERFORATED: 13940'-13970', 6 SPF, DP 14010'-14066, 6SPF, DP Perforating Interval (BRCS depths) & Gun Info. (insert more lines as necessary) Top (H) Bottom SPF Grams/EHD/TTP Phasinc Orient O/B/U Zone Ad/Report 13940 13970 6 20.5/0.4/21,9 60 RANDOM B UB2,1 INITIAL 14010 14066 6 20.5/0.4/21.9 60 RANDOM B UB1,LC4 INITIAL P or 1PROF: Well rate (attach WS30) SBHPS Pump in L (LDL, PNL, etc.) BOPD: F/ITP: I IVID:1 I Note fluid pumped and bbls behin t. Gas: I GOR: SS: 1pipe in "log entry" section next to ea BWPD: I WC (%): Press: 1pa&s made L Gas: Choke O: Temp: Signed Page No of Grea Sarber 1 1 ,FROM:- ARCO ALASKA FAX NO.: 9072634894 01-15-98 09:25A P.05 - EL Well Work Log = _ :~ J ;� Date 12/13/97 Descriptitni 3 3/8" HSD, 6SPF-DP PERFORATE - STATIC BHP SURVEY DS-Weil P2-27 FTP/ITP PSI IA PSI ZERO OA PSI 150 psi SITP 970 psi Min ID 3.813'@ 13987' SSSV nipple CAMCO BAL-O SSSV Information OOH Tubular or Casing Problems PBTD C/E #1 / SWS $9,099 C/E#2 0A - of U f C/E #3 C/E #4 C/E #5 Diesel (Recov.) Diesel (non Reco AFE # „- 2B0210 CC# �= Class PMDS009DH Activity �- Time Log Entry 08:00 MIRU SWS UNIT 8293: ENG: JOHNSON 08:45 PRESURE TEST BOP/RISEN TO 3000# 09:00 RIH WITH CCL/10' 3 3/8" HSD, 6 SPF PERF GUN 10:00 TIE INTO CET DATED 12/8/97 10:40 SHOOT 13834-13844 10:45 POOH 13:45 RIH WITH WT BAR/GR/TE=L -CCL/TEMP-PRESS 15:00 TIE INTO CET DATED 12/8/91 15:09 MAKE PRESSURE STOP AT 13922 MD (9000SS) 4468.4 PSI 15:38 MAKE PRESSURE STOP AT 13740 MD (8900SS) 4426.0 PSI 15:59 MAKE PRESSURE STOP AT 13553 MD (8800SS) 4382.2 PSI 16:20 POOH 17:00 AT SURFACE, RIG DOWN 18,00 LEAVE LOCATION Results Summary - Address each objective listed in Job request - e. a. splits, GOC Dick, channels, etc PERFORATED: 13834-13844', 6 SPF, DP PRESSURE AT 13922' (9000SS)= 4468.4 PSIA PRESSURE AT 13740' (8900SS)= 4426.0 PSIA PRESSURE AT 13553' 880OSS = 4382.2 PSIA PGffora ing Interval (BHCS depths) & Gun Into. (insert more lines as necessary) Top (ft) Bottom SPF Grams/EHD/TTP Phasing Orient O/B/IJ Zone Ad/Reperf 13834 13844 6 20.5/0.4/21.9 60 RANDOM B U134 INITIAL P or IPROF: Well rate (attach WS30) SBHPS Pump in L (LDL, PNL, etc.) BOPD: F/ITP: MD: t Note fluid pumped and bbis behin t. Gas: GOR: SS: pipe in "log entry' section next to ea BWPD: WC (): Press: pass made L Gas: Choke,*: Tem Signed Page No of Greg Sarber 1 1 SPE' -SUN DRILLING SERVICES GE 1 ANCHORAGE ALASKA 1 ,5--pA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 MWD SURVEY 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC TRUE SUB -SEA LOURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. .00 .00 -47.90 0 0 N .00 E .00 .00N .00E .00 34.50 34.50 -13.40 0 0 N .00 E .00 .00N .00E .00 170.00 169.99 122.09 0 54 S 46.00 E .66 .74S .77E .26 239.00 238.98 191.08 0 54 S 43.30 E .06 1.51S 1.53E .49 289.00 288.98 241.08 0 24 N 79.30 E 1.53 1.76S 1.97E .73 349.00 348.98 301.08 0 24 N 17.60 E .68 1.52S 2.24E 1.09 378.00 377.98 330.08 0 30 N 4.90 E .49 1.30S 2.28E 1.24 408.00 407.98 360.08 0 48 N 1.50 W 1.03 .96S 2.28E 1.42 496.00 495.97 448.07 0 48 N .40 W .00 .27N 2.26E 2.06 584.00 583.96 536.06 0 42 N 1.30 E .11 1.42N 2.27E 2.68 640.00 639.95 592.05 0 40 N 1.31 E .05 2.09N 2.29E 3.05 730.51 730.45 682.55 1 22 N 20.47 E .86 3.64N 2.68E 4.20 820.30 820.21 772.31 1 23 N 43.81 E .62 5.44N 3.81E 6.12 909.60 909.47 861.57 1 55 N 21.95 E .91 7.61N 5.12E 8.38 999.02 998.83 950.93 2 20 N 17.74 E .51 10.74N 6.24E 10.99 1088.35 1087.98 1040.08 4 31 N 31.65 E 2.58 15.48N 8.64E 15.55 1182.49 1181.77 1133.86 5 27 N 35.03 E 1.05 22.31N 13.16E 23.00 1277.30 1275.97 1228.07 7 19 N 36.66 E 1.98 30.85N 19.36E 32.79 1371.04 1368.90 1321.00 7 45 N 39.73 E .62 40.51N 26.97E 44.37 1466.20 1463.09 1415.19 8 37 N 48.89 E 1.65 50.14N 36.45E 57.52 1561.44 1557.11 1509.21 9 39 N 55.97 E 1.60 59.31N 48.46E 72.56 1655.66 1649.93 1602.03 10 10 N 56.04 E .54 68.38N 61.91E 88.77 1749.67 1742.18 1694.28 11 56 N 60.06 E 2.06, 77.87N 77.23E 106.79 1845.20 1835.34 1787.44 13 34 N 60.16 E 1.71 88.39N 95.53E 127.88 1940.52 1927.93 1880.03 13 55 N 59.68 E .38 99.75N 115.13E 150.53 2035.22 2019.86 1971.96 13 50 N 60.94 E .33 111.00N 134.86E 173.22 2130.36 2112.25 2064.35 13 45 N 62.02 E .28 121.83N 154.80E 195.87 2223.49 2202.47 2154.57 14 56 N 53.03 E 2.70 134.25N 174.17E 218.88 2319.32 2294.95 2247.05 15 27 N 50.86 E .80 149.74N 193.95E 243.86 2411.94 2384.18 2336.28 15 37 N 51.75 E .31 165.25N 213.32E 268.51 2507.21 2475.54 2427.64 17 19 N 52.67 E 1.81 181.79N 234.67E 295.39 2603.86 2567.24 2519.34 19 26 N 53.85 E 2.23 200.00N 259.09E 325.75 2697.59 2655.20 2607.30 20 56 N 55.37 E 1.70 218.72N 285.47E 358.05 2792.73 2743.64 2695.74 22 19 N 57.24 E 1.62 238.16N 314.65E 393.09 2887.11 2830.08 2782.18 24 58 N 55.52 E 2.91 259.14N 346.16E 430.93 ORIGINAL S E P 17 19 �,fF" O!i Cc 08 Go IIS. C0flirpl r31l Alichllrage SPF -SUN DRILLING SERVICES PAGE 2 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 MWD SURVEY 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC TRUE SUB -SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 2981.31 2914.17 2866.27 28 33 N 56.04 E 3.81 282.99N 381.24E 473.33 3077.08 2997.73 2949.83 29 55 N 58.31 E 1.83 308.33N 420.55E 520.09 3171.90 3079.34 3031.44 31 16 N 59.42 E 1.55 333.27N 461.87E 568.34 3266.53 3159.58 3111.68 32 45 N 59.57 E 1.56 358.73N 505.09E 618.49 3361.07 3238.09 3190.19 34 55 N 60.27 E 2.33 385.11N 550.63E 671.09 3455.38 3314.82 3266.92 36 10 N 56.82 E 2.51 413.72N 597.37E 725.88 3550.56 3391.00 3343.10 37 29 N 54.22 E 2.15 446.03N 644.37E 762.87 3646.04 3467.32 3419.42 36 22 N 54.98 E 1.27 479.26N 691.13E 840.13 3740.98 3542.83 3494.93 38 13 N 55.45 E 1.98 512.08N 738.37E 897.60 3833.35 3614.04 3566.14 40 53 N 56.16 E 2.92 545.13N 787.03E 956.38 3929.78 3686.15 3638.25 42 17 N 56.94 E 1.56 580.40N 840.45E 1020.37 4024.73 3755.65 3707.75 43 35 N 57.35 E 1.39 615.49N 894.79E 1085.05 4119.00 3822.75 3774.85 45 38 N 57.79 E 2.20 650.99N 950.66E 1151.25 4214.33 3887.10 3839.20 49 25 N 56.43 E 4.00 688.12N 1010.36E 1221.55 4309.27 3947.58 3899.68 51 25 N 57.73 E 2.18 726.81N 1072.46E 1294.71 4400.12 4002.89 3954.99 53 33 N 57.24 E 2.39 765.54N 1133.21E 1366.76 4497.81 4059.30 4011.40 55 53 N 56.16 E 2.55 809.33N 1199.85E 1446.48 4592.66 4111.08 4063.18 57 55 N 55.53 E 2.21 853.94N 1265.59E 1525.87 4687.41 4160.61 4112.71 59 2 N 55.24 E 1.22 899.82N 1332.06E 1606.56 4781.72 4208.73 4160.83 59 35 N 56.58 E 1.35 945.28N 1399.23E 1687.62 4876.09 4256.23 4208.33 59 57 N 57.65 E 1.06 989.55N 1467.70E 1769.15 4971.20 4304.27 4256.37 59 22 N 57.15 E .77 1033.77N 1536.86E 1851.23 5065.42 4352.65 4304.75 58 49 N 58.31 E 1.20. 1076.94N 1605.21E 1932.07 5159.87 4402.25 4354.35 57 48 N 57.02 E 1.59 1119.92N 1673.12E 2012.44 5254.53 4452.06 4404.16 58 41 N 58.81 E 1.86 1162.66N 1741.31E 2092.92 5349.97 4501.26 4453.36 59 15 N 59.31 E .74 1204.71N 1811.46E 2174.69 5443.37 4548.58 4500.68 59 52 N 59.55 E .70 1245.66N 1880.79E 2255.18 5538.00 4595.55 4547.65 60 36 N 59.31 E .81 1287.44N 1951.52E 2337.30 5629.47 4640.82 4592.92 60 3 N 58.76 E .80 1328.33N 2019.67E 2416.77 5727.78 4690.46 4642.56 59 17 N 58.33 E .87 1372.61N 2092.06E 2501.62 5622.74 4737.96 4690.06 60 40 N 58.70 E 1.49 1415.55N 2162.17E 2583.83 5916.44 4783.25 4735.35 61 31 N 60.27 E 1.72 1457.19N 2232.83E 2665.81 6010.11 4828.28 4780.38 61 0 N 60.70 E .68 1497.66N 2304.31E 2747.86 6104.64 4874.57 4826.67 60 20 N 60.86 E .71 1537.89N 2376.24E 2830.18 6200.80 4922.85 4874.95 59 22 N 59.62 E 1.51 1579.16N 2448.42E 2913.26 SPE "-SUN DRILLING SERVICES PAGE 3 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 MWD SURVEY 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC TRUE SUB -SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 6275.92 4961.58 4913.68 58 33 N 58.99 E 1.30 1612.01N 2503.77E 2977.61 6371.99 5012.03 4964.13 58 5 N 58.39 E .72 1654.50N 2573.62E 3059.36 6465.99 5060.90 5013.00 59 15 N 59.24 E 1.46 1696.07N 2642.31E 3139.64 6561.11 5110.01 5062.11 58 35 N 58.44 E 1.00 1738.22N 2712.02E 3221.09 6655.56 5158.92 5111.02 59 1 N 58.97 E .67 1780.19N 2781.06E 3301.88 6750.23 5207.63 5159.73 59 1 N 58.91 E .06 1822.07N 2850.60E 3383.04 6845.68 5256.40 5208.50 59 31 N 59.56 E .78 1864.04N 2921.10E 3465.06 6940.96 5304.97 5257.07 59 10 N 59.76 E .40 1905.44N 2991.84E 3547.00 7034.80 5352.46 5304.56 60 1 N 59.82 E .90 1946.17N 3061.79E 3627.89 7128.86 5399.76 5351.86 59 35 N 59.28 E .67 1987.37N 3131.87E 3709.16 7224.26 5447.85 5399.95 59 51 N 59.83 E .57 2029.12N 3202.91E 3791.51 7317.18 5495.80 5447.90 57 59 N 59.98 E 2.02 2069.02N 3271.75E 3871.04 7411.30 5545.88 5497.98 57 43 N 60.37 E .45 2108.65N 3340.89E 3950.67 7505.30 5595.64 5547.74 58 21 N 58.68 E 1.67 2149.1ON 3409.61E 4030.38 7599.45 5645.38 5597.48 57 51 N 58.10 E .75 2191.00N 3477.69E 4110.32 7695.00 5696.38 5648.48 57 37 N 57.70 E .43 2233.93N 3546.14E 4191.12 7789.62 5746.21 5698.31 58 48 N 57.87 E 1.27 2276.81N 3614.18E 4271.54 7884.34 5795.35 5747.45 58 41 N 58.31 E .42 2319.61N 3682.92E 4352.52 7979.44 5845.30 5797.40 57 56 N 58.55 E .82 2361.98N 3751.87E 4433.44 8073.08 5895.17 5847.27 57 42 N 58.34 E .32 2403.45N 3819.40E 4512.69 8169.69 5946.26 5898.36 58 27 N 59.72 E 1.44 2445.64N 3889.71E 4594.66 8264.27 5995.70 5947.80 58 31 N 58.56 E 1.05 2487.00N 3958.92E 4675.27 8358.89 6044.93 5997.03 58 46 N 57.71 E .81. 2529.65N 4027.54E 4756.07 8453.78 6094.32 6046.42 58 30 N 56.85 E .82 2573.45N 4095.70E 4837.08 8534.40 6136.20 6088.30 58 54 N 58.29 E 1.61 2610.39N 4153.85E 4905.97 8629.41 6185.64 6137.74 58 22 N 58.14 E .57 2653.12N 4222.81E 4987.10 8724.64 6235.63 6187.73 58 17 N 57.62 E .47 2696.22N 4291.46E 5068.15 8821.26 6286.11 6238.21 58 42 N 57.28 E .53 2740.54N 4360.90E 5150.53 8915.45 6334.90 6287.00 58 54 N 58.30 E .95 2783.48N 4429.07E 5231.10 9011.42 6384.97 6337.07 58 12 N 59.31 E 1.16 2825.89N 4499.10E 5312.96 9107.79 6436.22 6388.32 57 32 N 58.05 E 1.30 2868.31N 4568.81E 5394.55 9204.16 6487.99 6440.09 57 28 N 56.91 E 1.00 2912.00N 4637.35E 5475.83 9300.45 6539.56 6491.66 57 46 N 57.51 E .61 2956.04N 4705.71E 5557.14 9395.93 6590.74 6542.84 57 24 N 56.12 E 1.29 3000.15N 4773.16E 5637.72 9492.29 6642.68 6594.78 57 21 N 56.84 E .63 3044.97N 4840.82E 5718.85 SPE .-SUN DRILLING SERVICES PAGE 4 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 MWD SURVEY 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC TRUE SUB -SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9587.61 6693.67 6645.77 57 57 N 58.13 E 1.31 3088.25N 4908.73E 5799.38 9684.07 6745.13 6697.23 57 34 N 59.09 E .93 3130.75N 4978.38E 5880.96 9780.37 6797.25 6749.35 56 53 N 59.13 E .71 3172.32N 5047.86E 5961.92 9876.34 6849.22 6801.32 57 31 N 58.78 E .73 3213.93N 5116.98E 6042.58 9972.93 6900.59 6852.69 58 12 N 59.84 E 1.17 3255.67N 5187.32E 6124.35 10068.46 6951.11 6903.21 57 56 N 59.72 E .30 3296.48N 5257.38E 6205.39 10164.08 7001.79 6953.89 58 2 N 59.78 E .13 3337.33N 5327.43E 6286.43 10260.64 7053.00 7005.10 57 52 N 59.18 E .56 3378.90N 5397.94E 6368.26 10357.64 7104.89 7056.99 57 27 N 57.64 E 1.41 3421.82N 5467.75E 6450.20 10452.11 7155.63 7107.73 57 34 N 57.63 E .13 3464.48N 5535.06E 6529.89 10548.04 7206.64 7158.74 58 10 N 58.08 E .75 3507.70N 5603.84E 6611.13 10645.09 7257.67 7209.77 58 22 N 58.03 E .21 3551.38N 5673.89E 6693.68 10740.45 7307.96 7260.06 57 58 N 57.56 E .60 3594.56N 5742.45E 6774.70 10836.08 7358.31 7310.41 58 28 N 58.82 E 1.24 3637.41N 5811.53E 6855.99 10932.59 7409.03 7361.13 58 6 N 58.76 E .39 3679.96N 5881.76E 6938.09 11027.80 7459.75 7411.85 57 31 N 58.37 E .71 3721.98N 5950.51E 7018.66 11123.33 7510.57 7462.67 58 11 N 58.01 E .77 3764.61N 6019.24E 7099.55 11219.21 7560.64 7512.74 58 50 N 57.86 E .70 3808.02N 6088.54E 7181.31 11315.86 7610.56 7562.66 58 57 N 58.45 E .53 3851.69N 6158.84E 7264.07 11411.23 7659.55 7611.65 59 13 N 58.23 E .35 3894.64N 6228.49E 7345.89 11507.01 7709.10 7661.20 58 28 N 58.18 E .79 3937.82N 6298.15E 7427.86 11602.01 7758.62 7710.72 58 42 N 58.36 E .29 3980.46N 6367.11E 7508.93 11698.99 7809.52 7761.62 57 58 N 58.27 E .75. 4023.82N 6437.35E 7591.48 11795.12 7860.81 7812.91 57 31 N 57.54 E .79 4067.01N 6506.23E 7672.78 11891.03 7912.08 7864.18 57 50 N 56.69 E .82 4111.02N 6574.29E 7753.82 11986.90 7963.30 7915.40 57 33 N 56.00 E .67 4155.93N 6641.75E 7834.83 12082.26 8014.63 7966.73 57 18 N 55.85 E .29 4200.96N 6708.31E 7915.15 12178.12 8066.53 8018.63 57 7 N 56.05 E .26 4246.09N 6775.09E 7995.69 12273.49 8117.98 8070.08 57 34 N 54.85 E 1.16 4291.63N 6841.23E 8075.92 12369.93 8168.94 8121.04 58 37 N 54.98 E 1.08 4338.69N 6908.22E 8157.68 12464.87 8218.59 8170.69 58 18 N 55.55 E .61 4384.79N 6974.72E 8238.51 12560.70 8269.08 8221.18 58 5 N 56.56 E .92 4430.27N 7042.29E 8319.91 12655.97 8319.51 8271.61 57 58 N 56.10 E .43 4475.08N 7109.55E 8400.71 12752.80 8371.13 8323.23 57 35 N 56.78 E .71 4520.37N 7177.82E 8482.61 12849.13 8423.46 8375.56 56 34 N 56.51 E 1.08 4564.84N 7245.37E 8563.45 SPF '-SUN DRILLING SERVICES PAGE 5 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 MWD SURVEY 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC TRUE SUB -SEA LOURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 12944.15 8475.57 8427.67 56 54 N 57.81 E 1.19 4607.92N 7312.13E 8642.90 13041.18 8528.01 8480.11 57 40 N 58.73 E 1.13 4650.85N 7381.56E 8724.53 13136.53 8578.43 8530.53 58 27 N 58.29 E .91 4693.12N 7450.57E 8805.45 13231.60 8628.16 8580.26 58 28 N 58.10 E .17 4735.83N 7519.43E 8886.48 13327.52 8678.54 8630.64 58 9 N 58.41 E .42 4778.77N 7588.84E 8968.10 13422.65 8729.22 8681.32 57 27 N 57.86 E .89 4821.27N 7657.21E 9048.60 13518.68 8780.88 8732.98 57 28 N 58.05 E .17 4864.22N 7725.83E 9129.55 13614.39 8832.14 8784.24 57 45 N 58.66 E .62 4906.63N 7794.63E 9210.37 13709.92 8883.74 8835.84 56 50 N 57.86 E 1.18 4948.91N 7863.00E 9290.76 13805.53 8936.09 8888.19 56 45 N 57.01 E .75 4991.98N 7930.43E 9370.76 13902.42 8989.29 8941.39 56 37 N 57.81 E .70 5035.59N 7998.65E 9451.74 13998.71 9042.08 8994.18 56 52 N 57.28 E .52 5078.81N 8066.60E 9532.26 14095.26 9095.17 9047.27 56 24 N 57.33 E .48 5122.36N 8134.47E 9612.90 14192.33 9149.09 9101.19 56 6 N 57.10 E .37 5166.07N 8202.33E 9693.61 14287.51 9202.31 9154.41 55 54 N 55.79 E 1.16 5209.69N 8268.09E 9772.49 14330.00 9226.13 9178.23 55 54 N 55.79 E .00 5229.47N 8297.18E 9807.65 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE -DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 9807.68 FEET AT NORTH 57 DEG. 46 MIN. EAST AT MD = 14330 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 57.92 DEG. GYRODATA SURVEYS PRESENTED FROM 0.00'MD TO -584.00' MD TIE-IN SURVEY AT 584.00' MD PROJECTED SURVEY AT 14,330.00' MD SPE" '-SUN DRILLING SERVICES PAGE 6 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -47.90 .00 N .00 E .00 1000.00 999.81 951.91 10.78 N 6.25 E .19 .19 2000.00 1985.66 1937.76 106.91 N 127.50 E 14.34 14.15 3000.00 2930.59 2882.69 287.98 N 388.65 E 69.41 55.07 4000.00 3737.74 3689.84 606.29 N 880.43 E 262.26 192.85 5000.00 4318.94 4271.04 1047.21 N 1557.68 E 681.06 418.80 6000.00 4823.38 4775.48 1493.33 N 2296.59 E 1176.62 495.56 7000.00 5335.07 5287.17 1931.01 N 3035.73 E 1664.93 488.31 8000.00 5856.21 5808.31 2371.07 N 3766.73 E 2143.79 478.85 9000.00 6378.95 6331.05 2820.94 N 4490.75 E 2621.05 477.27 10000.00 6914.85 6866.95 3267.23 N 5207.21 E 3085.15 464.10 11000.00 7444.82 7396.92 3709.68 N 5930.54 E 3555.18 470.03 12000.00 7970.33 7922.43 4162.11 N 6650.91 E 4029.67 474.49 13000.00 8505.99 8458.09 4632.79 N 7351.82 E 4494.01 464.34 14000.00 9042.79 8994.89 5079.39 N 8067.51 E 4957.21 463.20 14330.00 9226.13 9178.23 5229.47 N 8297.18 E 5103.87 146.66 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE -DIMENSION MINIMUM CURVATURE METHOD. SPE"� -SUN DRILLING SERVICES PAGE 7 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB -SEA DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION .00 .00 -47.90 .00 N .00 E .00 47.90 47.90 .00 .00 N .00 E .00 .00 147.91 147.90 100.00 .50 S .52 E .01 .01 247.92 247.90 200.00 1.61 S 1.62 E .02 .01 347.92 347.90 300.00 1.53 S 2.23 E .02 .00 447.93 447.90 400.00 .41 S 2.27 E .03 .01 547.94 547.90 500.00 .98 N 2.26 E .04 .01 647.95 647.90 600.00 2.18 N 2.29 E .05 .01 747.97 747.90 700.00 4.03 N 2.83 E .07 .02 848.00 847.90 800.00 5.92 N 4.28 E .10 .03 948.05 947.90 900.00 8.82 N 5.60 E .15 .05 1048.15 1047.90 1000.00 12.85 N 7.05 E .24 .10 1148.47 1147.90 1100.00 19.66 N 11.30 E .57 .33 1249.00 1247.90 1200.00 27.95 N 17.21 E 1.10 .53 1349.85 1347.90 1300.00 38.31 N 25.15 E 1.95 .85 1450.84 1447.90 1400.00 48.62 N 34.72 E 2.94 .99 1552.09 1547.90 1500.00 58.43 N 47.16 E 4.19 1.26 1653.60 1647.90 1600.00 68.18 N 61.61 E 5.70 1.51 1755.52 1747.90 1700.00 78.48 N 78.28 E 7.62 1.92 1858.12 1847.90 1800.00 89.90 N 98.16 E 10.22 2.60 1961.10 1947.90 1900.00 102.24 N 119.40.E 13.20 2.97 2064.10 2047.90 2000.00 114.35 N 140.90 E 16.20 3.00 2167.06 2147.90 2100.00 125.98 N 162.51 E 19.16 2.97 2270.52 2247.90 2200.00 141.60 N 183.86 E 22.62 3.45 2374.27 2347.90 2300.00 158.97 N 205.36 E 26.37 3.75 2478.26 2447.90 2400.00 176.57 N 227.81 E 30.36 4.00 2583.35 2547.90 2500.00 195.98 N 253.58 E 35.45 5.09 2689.77 2647.90 2600.00 217.14 N 283.17 E 41.87 6.42 2797.34 2747.90 2700.00 239.12 N 316.13 E 49.44 7.57 2906.84 2847.90 2800.00 263.93 N 353.15 E 58.94 9.50 3019.71 2947.90 2900.00 293.25 N 396.47 E 71.81 12.87 3135.12 3047.90 3000.00 323.56 N 445.45 E 87.22 15.41 3252.65 3147.90 3100.00 354.93 N 498.61 E 104.75 17.53 3373.03 3247.90 3200.00 388.50 N 556.58 E 125.13 20.39 3496.36 3347.90 3300.00 426.96 N 617.61 E 148.46 23.32 SPEF -SUN DRILLING SERVICES PAGE 8 ANCHORAGE ALASKA ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB -SEA DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 3621.92 3447.90 3400.00 471.05 N 679.41 E 174.02 25.57 3747.46 3547.90 3500.00 514.36 N 741.70 E 199.56 25.54 3878.14 3647.90 3600.00 561.45 N 811.39 E 230.24 30.68 4014.03 3747.90 3700.00 611.51 N 888.57 E 266.13 35.89 4155.48 3847.90 3800.00 665.02 N 973.05 E 307.58 41.45 4309.78 3947.90 3900.00 727.02 N 1072.79 E 361.88 54.30 4477.49 4047.90 4000.00 799.96 N 1185.87 E 429.59 67.71 4662.70 4147.90 4100.00 887.74 N 1314.66 E 514.80 85.22 4859.45 4247.90 4200.00 981.84 N 1455.53 E 611.55 96.74 5056.24 4347.90 4300.00 1072.81 N 1598.53 E 708.34 96.79 5246.52 4447.90 4400.00 1159.12 N 1735.46 E 798.62 90.28 5442.02 4547.90 4500.00 1245.07 N 1879.78 E 894.12 95.50 5643.66 4647.90 4600.00 1334.71 N 2030.18 E 995.76 101.64 5843.03 4747.90 4700.00 1424.74 N 2177.28 E 1095.13 99.37 6050.56 4847.90 4800.00 1514.96 N 2335.15 E 1202.66 107.53 6249.69 4947.90 4900.00 1600.49 N 2484.59 E 1301.79 99.13 6440.56 5047.90 5000.00 1684.89 N 2623.53 E 1392.66 90.87 6634.15 5147.90 5100.00 1770.72 N 2765.33 E 1486.25 93.59 6828.92 5247.90 5200.00 1856.72 N 2908.65 E 1581.02 94.77 7025.68 5347.90 5300.00 1942.19 N 3054.95 E 1677.78 96.76 7224.37 5447.90 5400.00 2029.16 N 3202.98.E 1776.47 98.69 7415.08 5547.90 5500.00 2110.23 N 3343.67 E 1867.18 90.72 7604.20 5647.90 5600.00 2193.12 N 3481.10 E 1956.30 89.12 7792.86 5747.90 5700.00 2278.29 N 3616.54 E 2044.98 88.68 7984.33 5847.90 5800.00 2364.14 N 3755.41 E 2136.44 91.46 8172.83 5947.90 5900.00 2446.99 N 3892.01 E 2224.93 88.49 8364.61 6047.90 6000.00 2532.27 N 4031.68 E 2316.71 91.79 8557.06 6147.90 6100.00 2620.58 N 4170.36 E 2409.16 92.45 8747.99 6247.90 6200.00 2706.85 N 4308.24 E 2500.09 90.93 8940.63 6347.90 6300.00 2794.81 N 4447.41 E 2592.73 92.64 9129.55 6447.90 6400.00 2878.02 N 4584.39 E 2681.65 88.93 9316.09 6547.90 6500.00 2963.14 N 4716.87 E 2768.19 86.54 9501.96 6647.90 6600.00 3049.42 N 4847.64 E 2854.06 85.87 9689.24 6747.90 6700.00 3132.99 N 4982.12 E 2941.34 87.28 9873.88 6847.90 6800.00 3212.85 N 5115.21 E 3025.98 84.63 SPE .-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 9 ARCO ALASKA INC. DATE OF SURVEY: 081897 POINT MACINTYRE / P2-27 500292278500 JOB NUMBER: AK-MM-70226 NORTH SLOPE BOROUGH KELLY BUSHING ELEV. = 47.90 FT. COMPUTATION DATE: 9/ 6/97 OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB -SEA DEPTH TRUE SUB -SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 10062.42 6947.90 6900.00 3293.90 N 5252.96 E 3114.52 88.54 10251.04 7047.90 7000.00 3374.73 N 5390.96 E 3203.14 88.62 10437.69 7147.90 7100.00 3457.96 N 5524.78 E 3289.79 86.65 10626.46 7247.90 7200.00 3542.98 N 5660.43 E 3378.56 88.76 10816.17 7347.90 7300.00 3628.62 N 5797.01 E 3468.27 89.71 11005.74 7447.90 7400.00 3712.22 N 5934.67 E 3557.84 89.58 11194.58 7547.90 7500.00 3796.81 N 6070.69 E 3646.68 88.84 11388.45 7647.90 7600.00 3884.33 N 6211.84 E 3740.55 93.87 11581.38 7747.90 7700.00 3971.22 N 6352.10 E 3833.48 92.93 11771.08 7847.90 7800.00 4056.13 N 6489.12 E 3923.18 89.70 11958.18 7947.90 7900.00 4142.38 N 6621.65 E 4010.28 87.10 12143.79 8047.90 8000.00 4229.98 N 6751.17 E 4095.89 85.61 12329.55 8147.90 8100.00 4318.91 N 6880.00 E 4181.65 85.76 12520.61 8247.90 8200.00 4411.52 N 7013.89 E 4272.71 91.06 12709.43 8347.90 8300.00 4500.29 N 7147.19 E 4361.53 88.82 12893.52 8447.90 8400.00 4585.25 N 7276.30 E 4445.62 84.09 13078.39 8547.90 8500.00 4667.17 N 7408.44 E 4530.49 84.87 13269.35 8647.90 8600.00 4752.83 N 7546.75 E 4621.45 90.96 13457.36 8747.90 8700.00 4836.84 N 7681.98 E 4709.46 88.01 13643.93 8847.90 8800.00 4919.62 N 7815.98 E 4796.03 86.57 13827.08 8947.90 8900.00 5001.79 N 7945.55.E 4879.18 83.15 14009.36 9047.90 9000.00 5083.62 N 8074.10 E 4961.46 82.27 14190.20 9147.90 9100.00 5165.11 N 8200.84 E 5042.30 80.84 14330.00 9226.13 9178.23 5229.47 N 8297.18 E -5103.87 61.57 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS Schlumberger GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie Well Job # NO. 11664 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Greater Point McIntyre Area Floppy Log Description Date BL RF Sepia Disk 12/23/97 P 1-14 CB - 2016 (A C_ INJECTION PROFILE 971023 1 1 P2-27 - 1 a "" CET 971208 1 1 P2-27 STATIC PRESSURE 971212 1 1 P2-32 _ - I, PRODUCTION PROFILE 971124 1 1 P2-33 7-- V-I 8 RFT 971116 1 1 P 2-41 QtS- DOG PRODUCTION PROFILE 971024 1 1 P2-48 :� - I (r, PRODUCTION PROFILE 971026 1 1 P2-48 PRODUCTION PROFILE DEFT IMAGES 971026 1 1 SIGNED: - ------------- DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Sperry -sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska November 13, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. 5 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs P2-27, AK-MM-70226 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Jim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 P2-27: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22785-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22785-00 2" x 5" MD Neutron & Density Logs: 50-029-22785-00 2" x 5" TVD Neutron & Density Logs: 50-029-22785-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 3 4 a ks-3sa(Dir51"v'<—:K % .ram &A.(L `Tvo ,�•� -� h.�. c&L -7 I YPep 5631 Silverado Way, Suite G . Anchorage, Alaska 99518 • (907) 563-3256 Fax (907) 563-7252 A Dresser Industries, Inc. Company Sperry -sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Lags - P2-27, AK-MM-70226 November 12, 1997 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: Tim Galvin, Sperry -Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22785-00 foxy �►- jr �; .:.-�� JlS �r rC�tif ..'►�'.��: •.,��j:a:4;��tr n�. 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 . (907) 563-3256 . Fax (907) 563-7252 A Dresser Industries, Inc. Company Sperry -sun DRILLING SERVICES September 10, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data P2-27 Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well P2-27 MWD survey Tie -In point at 584.00' and a Projected survey at 14,330.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments C E S EP 17 1997 A%314a Oil & Gas Gr011s. 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 . (907) 563-3256 . Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION July 2, 1997 Steve Shultz Senior Drilling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Point McIntyre P2-27 BP Exploration (Alaska) Inc. Permit No. 97-125 Sur. Loc. 148'SNL, 1399'EWL, Sec. 14. T12N, R14E, UM Btmnhole Loc. 217'SNL, 4463'EWL, Sec. 12, T12N, R14E, UM Dear Mr. Shultz: 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Gaine, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA 0=z_ AND GAS CONSERVATION CONi.,j,1SSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ® Drill ❑ Redrill Flb. Type of well ElExploratory ❑ Stratigraphic Test ® Development Oil [IRe-EntryElDeepen ❑ Service ❑ Development Gas ❑ Sin le Zone ❑ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 45' Point McIntyre 3. Address 6. Property Designation 4.0c P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL.365s*—TZ-f 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 148' SNL, 1399' EWL, SEC. 14, T12N, R14E, UM Point McIntyre 8. Well Number At top of productive interval Number U-630610 425' SNL, 4127' EWL, SEC. 12, T12N, R14E, UM P2-27 At total depth 9. Approximate spud date Amount $200,000.00 217' SNL, 4463' EWL, SEC. 12, T12N, R14E, UM 07/10/97 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 034624, 5063' P2-25, 4.16' at 1500' TVD 3601 14317' MD / 9189' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e) (2)) Kick Off Depth 800' MD Maximum Hole Angle 58.25° 1 Maximum surface 3470 psig, At total depth (TVD) 8800' / 4350 psig 18. Casing Program Size Specifications Setting Depth Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 133# H-40 BTC 80' 45' 45' 125' 125' 260 sx Arctic Set (Approx.) 12-1 /4" 9-5/8" 40# L-80 BTC-Mod 6210' 1 44' 44' 6254' 4946' 692 sx CS III, 612 sx 'G', 979 sx CS III 8-1/2" 7" 26# L-80 BTCM/NSCC 10004' 43' 43' 13552' 8787' 257 sx Class 'G' 8-1/2" 7" 26# 13CR BTCM/NSCC 765' 13552' 8787' 14317' 9189' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) ORIGINAL true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate; Production Liner 6 as Qons. Q%11 55 101 J Perforation depth: measured�� true vertical 20. Attachments ® Filing Fee ❑ Property Plat ❑ BOP Sketch ❑ Diverter Sketch ® Drilling Program ® Drilling Fluid Program ❑ Time vs Depth Plot ❑ Refraction Analysis ❑ Seabed Report ❑ 20 AAC 25.050 Requirements Contact Engineer Name/Number: Greg Hobbs, 564-4191 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the fog Ming is true d cor ct to the best of my knowledge Signed Steve Shultz i. %." > Title Senior DrillingEngineer eer Date �' f Commission Use Only Permit Number API Number Z- Approval Date -l^ —/ See cover letter I _ 2 — --Z _ for other requirements Conditions of Approval: Samples Required ❑ Yes ,® No Mud Log Required ❑ Yes No Hydrogen Sulfide Measures Yes ❑ No Directional Survey Required JK Yes ❑ No JN Required Working Pressure for BOPE ❑ 2M; ❑ 3M; X 5M; ❑ 10M; ❑ 15M Other: Original Slgl16U d� David W. Johnston by order of Approved By Commissioner the commission Date 1-c� Form 10-401 Rev. 12-01-85 Submit In Triplicate Well Name: I P2-27 Type of Well (producer or injector): jProducer Surface Location: 148' FNL, 1399' FWL, SEC 14, T 12N, R 14E Target Location: 425' FNL, 4127' FWL, SEC 12, T12N, R14E Bottom Hole Location: 217' FNL, 4463' FWL, SEC 12, T 12N, R 14E AFE Number: 2B0210 Rig: DOYON 14 Estimated Start Date: 7/10/97 Days to complete 125 MD: 14317 TVD: 9189' brt RTE: 45.0 Well Design (conventional, slimhole, etc.): I Ultra-Slimhole 7" Lon stria Formation Markers: Formation Tops MD TVD Base of Permafrost 1791 1781 SV1 (T3) 5855 4736 9 5/8" Casing Point 6254 4946 9-5/8" csg shoe below S V 1 & above K-15 K15 (U nu) 6710 5186 Shallow as? 10.1 EMW a possibility. West Sak 10245 7046 9.5 ppg minimum mud weight required K-10 13787 8910 HRZ 13797 8915 K-5/HRZ same depth, 9.6-9.9 EMW Kalubik 13835 8935 Ku aruk 13852 8944 10.0 ppg Min EMW OWC 14177 9115 TD 14317 9189 7" casing shoe. 140' MD below OWC Miluveach 9294 Casine/Tubing Program: Hole Size Csg/Tbg O.D. Wt/Ft Grade Conn Length Top MD/TVD Btm MD/TVD 30" 20" 133# H40 BTC 80' 45/45' 125'/125' 12 1/4" 9 5/8" 40# L-80 BTC-Mod 6210' 44/44' 6254'/4946' 8 1/2" 7" 26# L-80 13CR BTCM / NSCC 10004' 765' 43/43' 13552'/8787 13552'/8787' 14317'/9189' Tubing 41/2" 12.6# 13CR80 NSCT L 13710' 42'/42' 13752'/8892' Mud Program: Surface Mud Properties: Sp ud 12 1/4" hole section Density ( ) Funnel Vis Yield Point 10 sec gel 0 min gel pH Fluid Loss 8.6-9.5 100-300 30-70 20-60 40-80 9-10 6-8cc Production Mud Properties: LSND 8 1/2" hole section Density ( ) Plastic Vis Yield Point 10 sec gel 1 10 min gel pH Fluid Loss 8.8-10.0 8-15 20-30 5-15 < 30 9.0-9.5 6-12cc Production Mud Properties: 6% KCL 8-1/2" hole section Density () Plastic Vis Yield Point 10 sec gel 1 10 min gel pH Fluid Loss 10.0 - 10.2 8-15 25-30 12-15 < 30 9.0-9.5 4-6cc Cement Data: Casing First Stage: Second Stage: Comments Sxs/Wt/Yield Sxs/Wt/Yield 9-5/8" surface Coldset III: 979/12.2/1.92 Two stage job: casing 692/12.2/1.92 (assumes 200% First stage Coldset III lead to 6254' . excess in permafrost) from 2000' -4829' @ 50% ES cementer Class G: excess followed by Class G @ at 2000' 612/15.8/1.15 tail from shoe to 4829' (750' NID. TVD) @ 50% excess + 80' shoe. Second stage Coldset III circulated to surface. Casing/Liner Lead:Sxs/Wt/Yield Tail: Sxs/Wt/Yield Comments 7" none 257/15.8/1.15 Class "G". Volume based on cement to 1000' above the Kuparuk with 50% excess + 80' shoe. I Open Hole Logs: 112 1/4" MWD Directional onlv I 81/2" MWD DIR to K-10 8 1/2" LWD DIR/GR/RES/DEN/NEU from K-10 to TD. Log tops (GR/RES) on trip in hole. No open hole lots required. I Cased Hole Logs: I GR/CBT (CBT may be reauested prior to runninc tubing). I 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. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: 800' MD Maximum Hole Angle: 58.25 degrees Close Approach Well: P2-25 - 4.16' allowable deviation at 1500' P2-28 - 5.3l' allowable deviation at 594' P2-29 - 8.47' allowable deviation at 998' Drilling and Completion Scope 1. Move rig to P2-27. NU riser and flowlines. Diverter waived. 2. Directionally drill 12 1/4" surface hole to —6254' MD. 3. Run and cement 9 5/8" casing. Cement to surface. 4. Drill 8-1/2" production hole with MWD DIR to top of K-10 at 13,787' MD. 5. Change over mud system to 6% KCL. 6. Complete GR/RES MAD pass from shoe to K-10 while RIH. Drill 8-1/2" production hole with LWD DIR/GR/DEN/NEU/RES to TD at 14,317' MD. 7. Run and cement 7" L-80/13CR casing. 8. Run 4-1/2" 13CR production tubing with 7"x4-1/2" packer, 4-1/2" SSSV, and 4-1/2"xl" GLMs. 9. Secure well, RDMO. Drilling Hazards/Contingencies • The original reservoir pressure is 4350 psi at 8800' ss. The expected reservoir pressure is 4350 psi at 8800' ss. Abnormally pressured formations are not expected in this well. • Tight hole has been experienced in the lower Sagavanirktok, below the surface casing shoe which were set into the SW sand. This has caused stuck pipe incidents and bit/BHA balling Gumbo problems. • Coal stringer in the lower Ugnu have caused stuck pipe. • No major instances of lost circulation problems have occurred on Pt Mac 2 wells. • Gas cut mud has been experienced in the Colville shales in neighboring wells. A 10.1 ppg mud may be required here. 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 H 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. GH 6/5/97 Shared Services Drilling Structure : Pt Mac 2 Field : Point Mac Location : Alaska /PZ-77 Well Plan 2 a�� . ��11 11,01 - - - - - - WELL PROFILE DATA ------ ---- Point - - - - Tie on LID 0 Inc 0.00 Dir 0.00 TVII florin Eos1 DL5 (deg/10011) 0 U U U.lNr End of Turn End of Build 701) 1200 O.OU 5.00 52.00 52.00 70U 0 U U.W 1199 13 17 1.00 End of Build IEnd ofBuild I60u 1752 11.01) 14.00 54.O0 56.00 1596 47 62 1.50 1744 65 89 2.00 .-800 _ op 2325 14.00 56.00 2300 143 204 0.00 t) d of Wid 4530 58.25 58.06 4043 825 1278 2.00 fJ angel 13852 58.25 58.06 6944 5014 7999 0.00 r, d of Hold 14177 58.25 58.06 9115 5161 8233 0.00 r) dof Hold 14317 58.25 58.06 9189 5223 8334 0.00 t>U 0 Tie on (1) 800 1.00 End of Turn U 3:0 f j� - 4g'00 End of Build 7150 .00 1600 9`�. of Build PRELIMINARY 13.98 d of uild ase ermafrost ; 1791'MD -}- 2400 16 Kick off Point 18.00 200...00 ll 2 99 d3200 �3 � U 4000 y1 � y 7.�9 End of Build V �- 4800 - T-3 (SVt) : 5855'MD \ 9 5/8" CASING : 6254'MD _ Surface Casing D K-15:6710'MD 5600 6400 - II 7200 WEST SAK : 10245' M D `/ V 8000 - \ i800 - K-1U IK3 1 7 MD! U KKgqHLLR7qq.13 }}��7'tA� KUPARUK . 1�385.2 D r, TD. 7- CM6' ?1� IMID \� 9 600 Production Casting 10400 -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10- Sc a I e 1 800.00 Vertical Section on 57.92 azimuth with reference 0.00 N, 0.00 E from P2-27 N TRUEHORTH - - - - TARGET DATA - - - - w 9,u Uk m N dh Ew --Hang-- I x:2 5e.25 58.04 e944 5014 7990 T.,gct P2-0 689517, 6003637 p 2 z-7 Shared Services Drilling Structure : Pt Mac 2 Field : Point Mac Location : Alaska - - - - - - WELL PROFILE DATA - - - - - - - - - - Point - - - - MD Inc Dir TVD North East US (deg/ 10011) Tim on 0 0.0C1 0.00 0 O 0 O.00 End of Turn 700 0.00 52.00 700 0 0 0.00 End of Build 1200 5.00 52.00 1199 13 17 1.00 End of Build 1600 11.00 54.00 1596 47 62 1.50 End of Build 1752 14.00 56.00 1744 65 89 2.00 KOP 2325 14.00 56.00 2300 143 204 0.00 End of Build 4538 58.25 58.06 4043 825 1278 2.00 Torget 13852 58.25 58.06 8944 5014 7999 0.00 End of Hold 14177 58.25 - 58.06 9115 5161 8233 0.00 End of Hold 14317 58.25 58.06 9189 5223 8334 0.00 Scale 1 : 800.00 East = -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 720C 640C 560Ci 4800 I I 4000 .� 3200 T y O 2400 1600 800 r; 0 •a, ) u t7, _000 7200 6400 5600 4800 A 4000 3200 O 2400. 1600 800 0 0 0 l 0 0 0 -800 0 -800 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 :rtical Section 57.92 <B 46.40 MD Inc. Azi. TVDss TVDrkb 0.00 0.00 0.00 -46.40 0.00 100.00 0.00 52.00 53.60 100.00 200.00 0.00 52.00 153.60 200.00 300.00 0.00 52.00 253.60 300.00 400.00 0.00 52.00 353.60 400.00 500.00 0.00 52.00 453.60 500.00 600.00 0.00 52.00 553.60 600.00 700.00 0.00 52.00 653.60 700.00 800.00 1.00 52.00 753.59 799.99 900.00 2.00 52.00 853.56 899.96 1000.00 3.00 52.00 953.46 999.86 1100.00 4.00 52.00 1053.28 1099.68 1200.00 5.00 52.00 1152.97 1199.37 1300.00 6.50 52.84 1252.46 1298.86 1400.00 8.00 53.37 1351.66 1398.06 1500.00 9.50 53.73 1450.49 1496.89 1600.00 10.99 54.00 1548.90 1595.30 1600.37 11.00 54.00 1549.26 1595.66 1700.00 12.97 55.42 1646.71 1693.11 1751.90 14.00 56.00 1697.18 1743.58 1790.88 14.00 56.00 1735.00 1781.40 1800.00 14.00 56.00 1743.85 1790.25 1900.00 14.00 56.00 1840.88 1887.28 2000.00 14.00 56.00 1937.91 1984.31 2100.00 14.00 56.00 2034.94 2081.34 2200.00 14.00 56.00 2131.97 2178.37 2300.00 14.00 56.00 2229.00 2275.40 2325.35 14.00 56.00 2253.60 2300.00 2400.00 15.49 56.24 2325.79 2372.19 2500.00 17.49 56.51 2421.67 2468.07 2600.00 19.49 56.72 2516.50 2562.90 2700.00 21.49 56.89 2610.17 2656.57 2800.00 23.49 57.04 2702.56 2748.96 2900.00 25.49 57.16 2793.56 2839.96 3000.00 27.49 57.27 2883.06 2929.46 3100.00 29.49 57.36 2970.95 3017.35 3200.00 31.49 57.44 3057.12 3103.52 3300.00 33.48 57.52 3141.47 3187.87 3400.00 35.48 57.58 3223.89 3270.29 5/19/97 9:53 AM Rect. Coordinates Northing Easting 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.00n 0.00e 0.54n 0.69e 2.15n 2.75e 4.83n 6.19e 8.59n 11.00e 13.42n 17.18e 19.52n 25.12e 27.09n 35.22e 36.12n 47.45e 46.61 n 61.82e 46.65n 61.87e 58.58n 78.77e 65.40n 88.77e 70.67n 96.59e 71.91 n 98.42e 85.43n 118.47e 98.96n 138.53e 112.49n 158.59e 126.02n 178.64e 139.55n 198.70e 142.98n 203.78e 153.56n 219.56e 169.28n 243.20e 186.73n 269.68e 205.89n 298.97e 226.73n 331.03e 249.24n 365.83e 273.39n 403.33e 299.14n 443.47e 326.47n 486.21 e 355.34n 531.49e 385.72n 579.27e Grid Coordinates Easting Northing 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.20 5998437.30 681638.87 5998437.85 681640.90 5998439.51 681644.27 5998442.28 681648.99 5998446.15 681655.06 5998451.12 681662.86 5998457.40 681672.77 5998465.21 681684.79 5998474.52 681698.90 5998485.34 681698.96 5998485.38 681715.57 5998497.70 681725.41 5998504.75 681733.10 5998510.21 681734.90 5998511.48 681754.63 5998525.48 681774.37 5998539.47 681794.10 5998553.46 681813.83 5998567.45 681833.57 5998581.45 681838.57 5998584.99 681854.09 5998595.95 681877.35 5998612.21 681903.42 5998630.27 681932.25 5998650.11 681963.82 5998671.70 681998.08 5998695.02 682034.99 5998720.03 682074.52 5998746.71 682116.61 5998775.03 682161.20 5998804.95 682208.25 5998836.44 DLS deg/100ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1.00 1.00 1.00 1.00 1.00 1.50 1.50 1.50 1.50 1.50 2.00 2.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 Page 1 of 5 Vertical Section Comment 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.87 3.47 7.81 13.88 21.69 31.66 44.23 59.39 77.13 77.20 97.86 109.95 119.37 Base Permafrost: 1791'MD 121.58 145.76 169.94 194.11 218.29 242.47 248.60 267.59 295.97 327.67 362.66 400.91 442.35 486.94 534.63 585.36 639.06 695.68 6*4 � All 1. � o erticai Section 57.92 KB 46.40 MD Inc. Azi. TVDss TVDrkb 3500.00 37.48 57.64 3304.29 3350.69 3600.00 39.48 57.70 3382.57 3428.97 3700.00 41.48 57.75 3458.62 3505.02 3800.00 43.48 57.80 3532.37 3578.77 3900.00 45.48 57.84 3603.71 3650.11 4000.00 47.48 57.88 3672.56 3718.96 4100.00 49.48 57.92 3738.84 3785.24 4200.00 51.48 57.95 3802.47 3848.87 4300.00 53.48 57.99 3863.37 3909.77 4400.00 55.48 58.02 3921.46 3967.86 4500.00 57.48 58.05 3976.68 4023.08 4538.37 58.25 58.06 3997.09 4043.49 4600.00 58.25 58.06 4029.52 4075.92 4700.00 58.25 58.06 4082.14 4128.54 4800.00 58.25 58.06 4134.76 4181.16 4900.00 58.25 58.06 4187.38 4233.78 5000.00 58.25 58.06 4240.00 4286.40 5100.00 58.25 58.06 4292.63 4339.03 5200.00 58.25 58.06 4345.25 4391.65 5300.00 58.25 58.06 4397.87 4444.27 5400.00 58.25 58.06 4450.49 4496.89 5500.00 58.25 58.06 4503.12 4549.52 5600.00 58.25 58.06 4555.74 4602.14 5700.00 58.25 58.06 4608.36 4654.76 5800.00 58.25 58.06 4660.98 4707.38 5855.14 58.25 58.06 4690.00 4736.40 5900.00 58.25 58.06 4713.60 4760.00 6000.00 58.25 58.06 4766.23 4812.63 6100.00 58.25 58.06 4818.85 4865.25 6200.00 58.25 58.06 4871.47 4917.87 6254.21 58.25 58.06 4900.00 4946.40 6300.00 58.25 58.06 4924.09 4970.49 6400.00 58.25 58.06 4976.72 5023.12 6500.00 58.25 58.06 5029.34 5075.74 6600.00 58.25 58.06 5081.96 5128.36 6700.00 58.25 58.06 5134.58 5180.98 6710.30 58.25 58.06 5140.00 5186.40 6800.00 58.25 58.06 5187.20 5233.60 6900.00 58.25 58.06 5239.83 5286.23 5/19/97 9:53 AM Rect. Coordinates Northing Easting 417.56n 629.48e 450.84n 682.06e 485.51 n 736.95e 521.52n 794.08e 558.84n 853.38e 597.41 n 914.78e 637.20n 978.21 e 678.15n 1043.58e 720.22n 1110.82e 763.34n 1179.84e 807.48n 1250.57e 824.67n 1278.14e 852.40n 1322.61 e 897.38n 1394.78e 942.37n 1466.94e 987.35n 1539.10e 1032.34n 1611.26e 1077.32n 1683.42e 1122.31 n 1755.58e 1167.29n 1827.74e 1212.28n 1899.90e 1257.26n 1972.07e 1302.25n 2044.23e 1347.23n 2116.39e 1392.22n 2188.55e 1417.02n 2228.34e 1437.20n 2260.71 e 1482.19n 2332.87e 1527.17n 2405.03e 1572.16n 2477.19e 1596.55n 2516.32e 1617.14n 2549.35e 1662.13n 2621.52e 1707.11 n 2693.68e 1752.1On 2765.84e 1797.08n 2838.00e 1801.72n 2845.43e 1842.07n 2910.16e 1887.05n 2982.32e Grid Coordinates Easting Northing 682257.70 5998869.44 682309.48 5998903.94 682363.54 5998939.88 682419.81 5998977.21 682478.22 5999015.91 682538.70 5999055.91 682601.17 5999097.17 682665.56 5999139.63 682731.80 5999183.25 682799.79 5999227.98 682869.46 5999273.75 682896.62 5999291.59 682940.43 5999320.34 683011.51 5999367.00 683082.60 5999413.66 683153.68 5999460.31 683224.76 5999506.97 683295.85 5999553.63 683366.93 5999600.29 683438.02 5999646.94 683509.10 5999693.60 683580.19 5999740.26 683651.27 5999786.92 683722.36 5999833.57 683793.44 5999880.23 683832.64 5999905.96 683864.52 5999926.89 683935.61 5999973.55 684006.69 6000020.21 684077.78 6000066.86 684116.32 6000092.16 684148.86 6000113.52 684219.95 6000160.18 684291.03 6000206.84 684362.12 6000253.49 684433.20 6000300.15 684440.52 6000304.96 684504.28 6000346.81 684575.37 6000393.47 DLS deg/100ft 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 2.00 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 Page 2of5 Vertical Section 755.13 817.36 882.28 949.81 1019.88 1092.39 1167.26 1244.40 1323.72 1405.11 1488.47 1520.97 1573.37 1658.41 1743.44 1828.47 1913.51 1998.54 2083.58 2168.61 2253.65 2338.68 2423.72 2508.75 2593.79 2640.68 2678.82 2763.85 2848.89 2933.92 2980.02 3018.96 3103.99 3189.03 3274.06 3359.10 3367.85 3444.13 3529.16 Comment T-3 (SV1) : 5855'MD 9 5/8" CASING: 6254'MD K-15 : 6710'MD ertical Section 57.92 KB 46.40 MD Inc. Azi. TVDss TVDrkb 7000.00 58.25 58.06 5292.45 5338.85 7100.00 58.25 58.06 5345.07 5391.47 7200.00 58.25 58.06 5397.69 5444.09 7300.00 58.25 58.06 5450.32 5496.72 7400.00 58.25 58.06 5502.94 5549.34 7500.00 58.25 58.06 5555.56 5601.96 7600.00 58.25 58.06 5608.18 5654.58 7700.00 58.25 58.06 5660.80 5707.20 7800.00 58.25 58.06 5713.43 5759.83 7900.00 58.25 58.06 5766.05 5812.45 8000.00 58.25 58.06 5818.67 5865.07 8100.00 58.25 58.06 5871.29 5917.69 8200.00 58.25 58.06 5923.91 5970.31 8300.00 58.25 58.06 5976.54 6022.94 8400.00 58.25 58.06 6029.16 6075.56 8500.00 58.25 58.06 6081.78 6128.18 8600.00 58.25 58.06 6134.40 6180.80 8700.00 58.25 58.06 6187.03 6233.43 8800.00 58.25 58.06 6239.65 6286.05 8900.00 58.25 58.06 6292.27 6338.67 9000.00 58.25 58.06 6344.89 6391.29 9100.00 58.25 58.06 6397.51 6443.91 9200.00 58.25 58.06 6450.14 6496.54 9300.00 58.25 58.06 6502.76 6549.16 9400.00 58.25 58.06 6555.38 6601.78 9500.00 58.25 58.06 6608.00 6654.40 9600.00 58.25 58.06 6660.63 6707.03 9700.00 58.25 58.06 6713.25 6759.65 9800.00 58.25 58.06 6765.87 6812.27 9900.00 58.25 58.06 6818.49 6864.89 10000.00 58.25 58.06 6871.11 6917.51 10100.00 58.25 58.06 6923.74 6970.14 10200.00 58.25 58.06 6976.36 7022.76 10244.93 58.25 58.06 7000.00 7046.40 10300.00 58.25 58.06 7028.98 7075.38 10400.00 58.25 58.06 7081.60 7128.00 10500.00 58.25 58.06 7134.22 7180.62 10600.00 58.25 58.06 7186.85 7233.25 10700.00 58.25 58.06 7239.47 7285.87 5/19/97 9:53 AM Rect. Coordinates Northing Easting 1932.04n 3054.48e 1977.02n 3126.64e 2022.01 n 3198.81 e 2067.00n 3270.97e 2111.98n 3343.13e 2156.97n 3415.29e 2201.95n 3487.45e 2246.94n 3559.61 e 2291.92n 3631.77e 2336.91 n 3703.93e 2381.89n 3776.10e 2426.88n 3848.26e 2471.86n 3920.42e 2516.85n 3992.58e 2561.83n 4064.74e 2606.82n 4136.90e 2651.80n 4209.06e 2696.79n 4281.22e 2741.77n 4353.39e 2786.76n 4425.55e 2831.74n 4497.71 e 2876.73n 4569.87e 2921.71 n 4642.03e 2966.70n 4714.19e 3011.68n 4786.35e 3056.67n 4858.51 e 3101.65n 4930.67e 3146.64n 5002.84e 3191.62n 5075.00e 3236.61 n 5147.16e 3281.60n 5219.32e 3326.58n 5291.48e 3371.57n 5363.64e 3391.78n 5396.06e 3416.55n 5435.80e 3461.54n 5507.96e 3506.52n 5580.13e 3551.51 n 5652.29e 3596.49n 5724.45e Grid Coordinates Easting Northing 684646.45 6000440.12 684717.54 6000486.78 684788.62 6000533.44 684859.71 6000580.10 684930.79 6000626.75 685001.88 6000673.41 685072.96 6000720.07 685144.04 6000766.73 685215.13 6000813.39 685286.21 6000860.04 685357.30 6000906.70 685428.38 6000953.36 685499.47 6001000.02 685570.55 6001046.67 685641.64 6001093.33 685712.72 6001139.99 685783.80 6001186.65 685854.89 6001233.30 685925.97 6001279.96 685997.06 6001326.62 686068.14 6001373.28 686139.23 6001419.94 686210.31 6001466.59 686281.40 6001513.25 686352.48 6001559.91 686423.56 6001606.57 686494.65 6001653.22 686565.73 6001699.88 686636.82 6001746.54 686707.90 6001793.20 686778.99 6001839.85 686850.07 6001886.51 686921.16 6001933.17 686953.09 6001954.13 686992.24 6001979.83 687063.32 6002026.48 687134.41 6002073.14 687205.49 6002119.80 687276.58 6002166.46 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 Page 3 of 5 Vertical Section 3614.20 3699.23 3784.27 3869.30 3954.34 4039.37 4124.41 4209.44 4294.47 4379.51 4464.54 4549.58 4634.61 4719.65 4804.68 4889.72 4974.75 5059.78 5144.82 5229.85 5314.89 5399.92 5484.96 5569.99 5655.03 5740.06 5825.09 5910.13 5995.16 6080.20 6165.23 6250.27 6335.30 6373.51 6420.34 6505.37 6590.41 6675.44 6760.47 Comment WEST SAK : 10245'MD ertical Section 57.92 KB 46.40 MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Grid Coordinates DLS Vertical Northing Easting Easting Northing deg/100ft Section Comment 10800.00 58.25 58.06 7292.09 7338.49 3641.48n 5796.61 e 687347.66 6002213.12 0.00 6845.51 10900.00 58.25 58.06 7344.71 7391.11 3686.46n 5868.77e 687418.75 6002259.77 0.00 6930.54 11000.00 58.25 58.06 7397.34 7443.74 3731.45n 5940.93e 687489.83 6002306.43 0.00 7015.58 11100.00 58.25 58.06 7449.96 7496.36 3776.43n 60:13.09e 687560.92 6002353.09 0.00 7100.61 11200.00 58.25 58.06 7502.58 7548.98 3821.42n 6085.25e 687632.00 6002399.75 0.00 7185.65 11300.00 58.25 58.06 7555.20 7601.60 3866.40n 6157.42e 687703.08 6002446.40 0.00 7270.68 11400.00 58.25 58.06 7607.82 7654.22 3911.39n 6229.58e 687774.17 6002493.06 0.00 7355.72 11500.00 58.25 58.06 7660.45 7706.85 3956.37n 6301.74e 687845.25 6002539.72 0.00 7440.75 11600.00 58.25 58.06 7713.07 7759.47 4001.36n 6373.90e 687916.34 6002586.38 0.00 7525.78 11700.00 58.25 58.06 7765.69 7812.09 4046.34n 6446.06e 687987.42 6002633.03 0.00 7610.82 11800.00 58.25 58.06 7818.31 7864.71 4091.33n 6518.22e 688058.51 6002679.69 0.00 7695.85 11900.00 58.25 58.06 7870.94 7917.34 4136.31 n 6590.38e 688129.59 6002726.35 0.00 7780.89 12000.00 58.25 58.06 7923.56 7969.96 4181.30n 6662.54e 688200.68 6002773.01 0.00 7865.92 12100.00 58.25 58.06 7976.18 8022.58 4226.28n 6734.70e 688271.76 6002819.66 0.00 7950.96 12200.00 58.25 58.06 8028.80 8075.20 4271.27n 6806.87e 688342.85 6002866.32 0.00 8035.99 12300.00 58.25 58.06 8081.42 8127.82 4316.25n 6879.03e 688413.93 6002912.98 0.00 8121.03 12400.00 58.25 58.06 8134.05 8180.45 4361.24n 6951.19e 688485.01 6002959.64 0.00 8206.06 12500.00 58.25 58.06 8186.67 8233.07 4406.22n 7023.35e 688556.10 6003006.30 0.00 8291.09 12600.00 58.25 58.06 8239.29 8285.69 4451.21 n 7095.51 a 688627.18 6003052.95 0.00 8376.13 12700.00 58.25 58.06 8291.91 8338.31 4496.19n 7167.67e 688698.27 6003099.61 0.00 8461.16 12800.00 58.25 58.06 8344.54 8390.94 4541.18n 7239.83e 688769.35 6003146.27 0.00 8546.20 12900.00 58.25 58.06 8397.16 8443.56 4586.17n 7311.99e 688840.44 6003192.93 0.00 8631.23 13000.00 58.25 58.06 8449.78 8496.18 4631.15n 7384.16e 688911.52 6003239.58 0.00 8716.27 13100.00 58.25 58.06 8502.40 8548.80 4676.14n 7456.32e 688982.61 6003286.24 0.00 8801.30 13200.00 58.25 58.06 8555.02 8601.42 4721.12n 7528.48e 689053.69 6003332.90 0.00 8886.34 13300.00 58.25 58.06 8607.65 8654.05 4766.11 n 7600.64e 689124.77 6003379.56 0.00 8971.37 13400.00 58.25 58.06 8660.27 8706.67 4811.09n 7672.80e 689195.86 6003426.21 0.00 9056.40 13500.00 58.25 58.06 8712.89 8759.29 4856.08n 7744.96e 689266.94 6003472.87 0.00 9141.44 13600.00 58.25 58.06 8765.51 8811.91 4901.06n 7817.12e 689338.03 6003519.53 0.00 9226.47 13700.00 58.25 58.06 8818.13 8864.53 4946.05n 7889.28e 689409.11 6003566.19 0.00 9311.51 13787.16 58.25 58.06 8864.00 8910.40 4985.26n 7952.18e 689471.07 6003606.85 0.00 9385.62 K-10:13787'MD 13796.66 58.25 58.06 .8869.00 8915.40 4989.53n 7959.04e 689477.82 6003611.29 0.00 9393.70 HRZ : 13797'MD 13800.00 58.25 58.06 8870.76 8917.16 4991.03n 7961.45e 689480.20 6003612.85 0.00 9396.54 13834.67 58.25 58.06 -8889.00 8935.40 5006.63n 7986.46e 689504.84 6003629.02 0.00 9426.02 KALUBIK : 13835'MD 13851.77 58.25 58.06 .8898.00 8944.40 5014.32n 7998.80e 689517.00 6003637.00 0.00 9440.57 KUPARUK : 13852'MD 13900.00 58.25 58.06 8923.38 8969.78 5036.02n 8033.61 a 689551.28 6003659.50 0.00 9481.58 14000.00 58.25 58.06 8976.00 9022.40 5081.00n 8105.77e 689622.37 6003706.16 0.00 9566.61 14100.00 58.25 58.06 9028.62 9075.02 5125.99n 8177.93e 689693.45 6003752.82 0.00 9651.65 14176.73 58.25 58.06 9069.00 9115.40 5160.50n 8233.30e 689747.99 6003788.62 0.00 9716.89 WOC : 14177'MD 5/19/97 9:53 AM Page 4 of 5 ✓ertical Section 57.92 ;KB 46.40 MD Inc. Azi. TVDss TVDrkb Rect. Coordinates Grid Coordinates US Vertical Northing Easting Easting Northing deg/100ft Section Comment 14200.00 58.25 58.06 9081.25 9127.65 5170.97n 8250.09e 689764.53 6003799.48 0.00 9736.68 14300.00 58.25 58.06 9133.87 9180.27 5215.96n 8322.25e 689835.62 6003846.13 0.00 9821.71 14316.73 58.25 '58.06 9142.67 9189.07 5223.48n 8334.32e 689847.51 6003853.94 0.00 9835.94 TD 7" CASING: 1431TMD 5/19/97 9:53 AM Page 5 of 5 H12388/ DATE I ! 7 CHECK NO. _ 0123882 VENDOR ALASKAST 14 00 DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 061097 CK061097 100.00 100- 0 HANDLING IMST: Sf h Kathy Camp oa Qr x 5122 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. I -^n nfi l I i nn rin H WELL PERMIT CHECKLISTcOMPANY WELL NAME Z PROGRAM: exp❑ devredrl❑ sere❑ wellbore seg❑ ann disp Para req❑ FIELD & POOL .�' �� INIT CLASS �'"GEOL AREA UNIT#� ON/OFF SHORE OAj D nMTMT QrPADTTnM REMARKS 1. Permit fee attached . . . . . . . . . . . . . . . . . Y N 2. Lease number appropriate. . . . . . . . . . . . . . . Y N 3. Unique well name and number . . . . . . . . . . . . . . Y N 4. Well located in a defined pool. . . . . . . . . . . .Y N 5. Well located proper distance from drlg unit boundary. . .Y N 6. Well located proper distance from other wells. Y N 7. Sufficient acreage available in drilling unit. . . . Y N 8. If deviated, is wellbore plat included . . . . . . . . Y N 9. Operator only affected party. . . . . . . . . . . . .Y N 10. Operator has appropriate bond in force. . . . . . . .Y N 11. Permit can be issued without conservation order. . . . Y N 1APPR D TE 12. Permit can be issued without administrative approval. . .Y N C 13. Can permit be approved before 15-day wait. . . . . . . Y N ENGINEERING 1.4. Conductor string provided . . . . . . . . . . . . . . . .Y N 15. Surface casing protects all known USDWs . . . . . . . . Y N _ 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y a 18. CMT will cover all known productive horizons. . . . . . .Y N 19. Casing designs adequate for C, T, B & permafrost. . N 20. Adequate tankage or reserve pit. . . . . . . . . . . . Y N 21. If a re -drill, has a 10-403 for abndmmnt been approved.-.*---* �t1 22. Adequate wellbore separation proposed. . . . . . . . . .� N 23. If diverter required, is it adequate. . . . . . . . . . .Y N 24. Drilling fluid program schematic & equip list adequate . Y N 25. BOPEs adequate . . . . . . . . . . . . . . . . . . Y N APPR DA"E 26. BOPE press rating adequate; test to J o c> a psig. N / 27. Choke manifold complies w/API RP-53 (May 84). . . . . . .Y N 28. Work will occur without operation shutdown. . . . . . . N 29. Is presence of H 2 S gas probable . . . . . . . . . . . . N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures.IN 31. Data presented on potential overpressure zones . . 32. Seismic analysis of shallow gas zones. . . . . . . 33. Seabed condition survey (if off -shore) . . . . . .AP Contact name/phone for weekly progress reports . �34. [exploratory only] GEOLLOOGG �Y:: ENGINEERING: COMMISSION: • Comnents/Instructions . RPxf - BEW DWJ JDH t*:� M z r.r HOW/dlf - 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 information. `�7 _� I a S--- Sperry -Sun Drilling Services LIS Scan Utility Tue Nov 11 15:11:09 1997 Reel Header Service name.............LISTPE Date .....................97/11/11 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Previous Reel Name....... UNKNOWN Comments ... ..............STS LIS Writing Library. Technical Services Tape Header Service name.............LISTPE Date .....................97/11/11 origin...................STS Tape Name................UNKNOWN Continuation Number ....... 01 Previous Tape Name ...... *.UNKNOWN Comments ... ..............STS LIS Writing Library. Technical Services Physical EOF Comment Record TAPE HEADER POINT MCINTYRE MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION 4__ - I � ( I C?- Scientific Scientific Date P2-27 500292278500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 11-NOV-97 MWD RUN 3 MWD RUN 4 AK-MM-70226 AK-MM-70226 RANDY KRELL M GABEL KEN MELDER KEN MELDER SECTION: 14 TOWNSHIP: 12N RANGE: 14E FNL: 148 FSL: FEL: FWL: 1399 ELEVATION (FT FROM MSL 0) KELLY-BUSHING: 47.90 DERRICK FLOOR: 46.40 GROUND LEVEL: 11.90 NOV WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING 12.250 9.625 6248.0 PRODUCTION STRING 8.500 14330.0 REMARKS: 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), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO DENSITY (SLD). 4. A MEASUREMENT AFTER DRILLING (MAD) PASS WAS PERFORMED WHILE TRIPPING INTO THE HOLE FOR MWD RUN 3 FROM 6248'MD, 4899'SSTVD TO 8532'MD, 6087'SSTVD. ONLY ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) AND DUAL GAMMA RAY (DGR) LOGGED DURING THIS INTERVAL. 5. THE ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4) TOOLS' MEMORY FILLED AT 13228'MD, 8579'SSTVD DURING MWD RUN 3. 6. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). THIS RUN WAS MEASURED AFTER DRILLING (MAD) TO OBTAIN MISSING DATA FROM MWD RUN 3. THIS RUN WAS LOGGED AT APPROXIMATELY 400 FT/HR. 7. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND TOM WALKER OF ARCO ALASKA, INC. ON 30 OCTOBER, 1997. 8. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14331'MD, 9178'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT -DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SRAT = SMOOTHED TOOL SPEED WHEN NOT DRILLING. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE OF NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBDC = SMOOTHED BULK DENSITY - COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. CURVES WITH THE EXTENTION "M" ARE MEASURED AFTER DRILLING (MAD). ENVIRONMENTAL PARAMETERS USED IN PROCESSING NUCLEAR/NEUTRON LOG DATA: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 750 - 30000 PPM. MUD WEIGHT = 8.5 - 9.8 PPG. FORMATION WATER SALINITY = 14545 PPM. File Header Service name.............STSLIB.001 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation ....... 97/11/11 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 6210.0 14238.5 FET 6248.0 14316.0 RPD 6248.0 14316.0 RPM 6248.0 14316.0 RPS 6248.0 14316.0 RPX 6248.0 14316.0 ROP 6257.5 14331.0 FCNT 11784.0 14238.0 NCNT 11784.0 14238.0 NPHI 11784.0 14238.0 PEF 11817.5 14272.5 DRHO 11817.5 14272.5 RHOB 11817.5 14272.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 8532.0 14331.0 MWD 4 13185.0 14331.0 REMARKS: 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 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub -type ... 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD AAPI 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 NPHI MWD P.U. 4 1 68 12 4 RHOB MWD G/CC 4 1 68 16 5 ROP MWD FT/H 4 1 68 20 6 PEF MWD BARN 4 1 68 24 7 DRHO MWD G/CC 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 RPS MWD OHMM 4 1 68 36 10 RPD MWD OHMM 4 1 68 40 11 FET MWD HOUR 4 1 68 44 12 NCNT MWD CNTS 4 1 68 48 13 FONT MWD CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 6210 14331 10270.5 16243 6210 14331 GR 21.6919 373.238 80.5975 16148 6210 14283.5 RPM 0.1977 100.017 4.07919 16137 6248 14316 NPHI 21.6156 81.7622 33.9288 4909 11784 14238 RHOB 2.1662 2.7946 2.4593 4911 11817.5 14272.5 ROP 7.1429 6465.23 398.645 16148 6257.5 14331 PEF 1.5748 7.1771 2.48747 4911 11817.5 14272.5 DRHO -0.089 0.3388 0.0451644 4911 11817.5 14272.5 RPX 0.5798 43.6677 3.42058 16137 6248 14316 RPS 0.404 56.8853 3.7936 16137 6248 14316 RPD 0.1897 115.402 4.31461 16137 6248 14316 FET 0.574 59.0746 14.6129 16137 6248 14316 NCNT 2344 3448 2873.62 4909 11784 14238 FCNT 543 1043 707.197 4909 11784 14238 First Reading For Entire File .......... 6210 Last Reading For Entire File ........... 14331 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number. ..........1.0.0 Date of Generation ....... 97/11/11 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 ....... 97/11/11 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 6210.0 14283.5 RPS 6228.0 13228.5 FET 6248.0 13228.5 RPD 6248.0 13228.5 RPM 6248.0 13228.5 RPX 6248.0 13228.5 ROP 6257.5 14331.0 FCNT 11784.0 14238.0 NCNT 11784.0 14238.0 NPHI 11784.0 14238.0 PEF 11817.5 14272.5 DRHO 11817.5 14272.5 RHOB 11817.5 14272.5 LOG HEADER DATA DATE LOGGED: 18-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 14331.0 TOP LOG INTERVAL (FT): 8532.0 BOTTOM LOG INTERVAL (FT): 14331.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 55.9 MAXIMUM ANGLE: 59.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0805CRDGP6 EWR4 ELECTROMAG. RESIS. 4 P0805CRDGP6 CNP COMPENSATED NEUTRON P0805CRDGP6 SLD STABILIZED LITHO DEN P0805CRDGP6 .19 um BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: . MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type..................0 Data Specification Block Type ..... 0 Logging Direction.................Down Optical log depth units ........... Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT GR MWD 3 RPX MWD 3 RPS MWD 3 RPM MWD 3 RPD MWD 3 NPHI MWD 3 RHOB MWD 3 PEP MWD 3 DRHO MWD 3 PET MWD 3 ROP MWD 3 FCNT MWD 3 NCNT MWD 3 8.500 8.5 KCL-POLYMER 10.30 48.0 8.5 30000 4.6 .130 .060 66.1 .100 .160 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 AAPI 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 P.U. 4 1 68 24 7 G/CC 4 1 68 28 8 BARN 4 1 68 32 9 G/CC 4 1 68 36 10 HOUR 4 1 68 40 11 FT/H 4 1 68 44 12 CNTS 4 1 68 48 13 CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 6210 14331 10270.5 16243 6210 14331 GR 21.6919 373.238 80.5975 16148 6210 14283.5 RPX 0.5798 20.0917 3.20149 13962 6248 13228.5 RPS 0.404 19.7003 3.2945 13962 6248 13228.5 RPM 0.1977 16.8084 3.35574 13962 6248 13228.5 RPD 0.1897 30.3359 3.42986 13962 6248 13228.5 NPHI 21.6156 81.7622 33.9288 4909 11784 14238 RHOB 2.1662 2.7946 2.4593 4911 11817.5 14272.5 PEF 1.5748 7.1771 2.48747 4911 11817.5 14272.5 DRHO -0.089 0.3388 0.0451644 4911 11817.5 14272.5 FET 0.574 41.3047 9.78412 13962 6248 13228.5 ROP 7.1429 6465.23 398.645 16148 6257.5 14331 FCNT 543 1043 707.197 4909 11784 14238 NCNT 2344 3448 2873.62 4909 11784 14238 First Reading For Entire File .......... 6210 Last Reading For Entire File ........... 14331 File Trailer Service name...........:.STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation ....... 97/11/11 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 ....... 97/11/11 Maximum Physical Record..65535 File Type................LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 13170.0 14316.0 RPD 13170.0 14316.0 RPM 13170.0 14316.0 RPS 13170.0 14316.0 RPX 13170.0 14316.0 GR 13178.0 14323.5 LOG HEADER DATA DATE LOGGED: 19-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWNHOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 14331.0 TOP LOG INTERVAL (FT): 13185.0 BOTTOM LOG INTERVAL (FT): 14331.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0802CRG6 EWR4 ELECTROMAG. RESIS. 4 P0802CRG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8.5 BOREHOLE CONDITIONS MUD TYPE: 6% KCL MUD DENSITY (LB/G): 10.40 MUD VISCOSITY (S): 50.0 MUD PH: 8.5 MUD CHLORIDES (PPM): 31000 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .130 MUD AT MAX CIRCULATING TERMPERATURE: .060 76.1 MUD FILTRATE AT MT: .100 MUD CAKE AT MT: .140 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 .1IN Max frames per record.............Undefined Absent value ......................-999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT GR MWD 4 RPX MWD 4 RPS M1r]D 4 RPM MWD 4 RPD MWD 4 FET MWD 4 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 AAPI 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 First Last Name Min Max Mean Nsam Reading Reading DEPT 13170 14323.5 13746.8 2308 13170 14323.5 GR 28.6655 368.897 83.3078 2292 13178 14323.5 RPX 0.9797 43.6677 4.72439 2293 13170 14316 RPS 0.772 56.8853 6.80222 2293 13170 14316 RPM 0.6216 100.017 8.44192 2293 13170 14316 RPD 0.4978 115.402 9.64761 2293 13170 14316 FET 36.8408 60.0065 46.3174 2293 13170 14316 First Reading For Entire File .......... 13170 Last Reading For Entire File ........... 14323.5 File Trailer Service name.............STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/11/11 Maximum Physical Record..65535 File Type................LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name.............LISTPE Date .....................97/11/11 origin...................STS Tape Name................UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date .....................97/11/11 origin...................STS Reel Name................UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services 6TT3 SIZ 3O pua JOE TPDTSAud JOE TPOTSAud