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Home My WebLink About188-138CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Lau, Jack J (OGC) To:Oliver Sternicki Cc:Rixse, Melvin G (OGC); Bo York Subject:RE: [EXTERNAL] 20250922 1647 APPROVAL 14-39 (PTD 188138) P&A Rev1 change request Date:Wednesday, October 22, 2025 11:51:32 AM Attachments:image001.png image002.png Oliver, Thanks for the call. As discussed, your plan to perf the OA at ~1000’MD followed by a final injectivity attempt into the OA shoe is approved. If there is no injectivity we will consider the OA sufficiently cemented (minus a top job if needed post surface cut). Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Wednesday, October 22, 2025 11:35 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Bo York <byork@hilcorp.com> Subject: RE: [EXTERNAL] 20250922 1647 APPROVAL 14-39 (PTD 188138) P&A Rev1 change request Jack, I just left you a message about this one. Eline is currently on well 14-39 working on the P&A. Fullbore cemented up the tubing and IA to 1352’ MD on 9/28/25, AOGCC witnessed on 10/1/25. We were successful at jet cutting the tubing at 1090’ on 10/3/25, severing the C&B lines which we then cemented. We are currently at step 5 in the program where eline is attempting to perf into the OA to get injectivity so we can downsqueeze the SC shoe and pump the surface plug in the tubing and IA. So far we have perforated at 300’ and 500’ MD and we are able to hold 2500 psi on the tubing and IA with no injectivity into the OA. This well had 4 OA downsqueezes in 1994, with returns to the cellar in all of them as part of the remediation of the surface casing failure event. The base of TOC in the OA was calculated to be somewhere around 190’ based on when we were getting returns to the cellar on the 1994 cement jobs, but it looks like cement got deeper in the OA based on the lack of injectivity. There is not arctic pack in the OA of this well that would be causing injectivity problems. We currently have one more perf gun available in the appropriate size, wanted to see if you wanted to go down to 1000’ MD to shoot this one as a last attempt to get injectivity into the OA. If we don’t get injectivity than we can assume that there is cement down to at least 1000’ MD in the OA which should be sufficient for the surface plug. Give me a call back, thanks. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, September 22, 2025 4:50 PM To: Oliver Sternicki <oliver.sternicki@hilcorp.com> Subject: [EXTERNAL] 20250922 1647 APPROVAL 14-39 (PTD 188138) P&A Rev1 change request CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Oliver, Approved to continue to Sundry work 325-427 under Revision 1 attached. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Rixse, Melvin G (OGC) Sent: Monday, September 22, 2025 10:52 AM To: 'Oliver Sternicki' <oliver.sternicki@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Subject: RE: [EXTERNAL] RE: 14-39 (PTD 188138) P&A Rev1 change request Oliver, My apologies…….I didn’t read past the schematic (usually at the end). Jack is back in the office today. I will confirm with him that he is good with this. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Monday, September 22, 2025 9:46 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: RE: [EXTERNAL] RE: 14-39 (PTD 188138) P&A Rev1 change request Mel, Here is the Rev 1 program and the original sundry approval, they were in the original email. Thanks, Oliver From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, September 22, 2025 9:41 AM To: Oliver Sternicki <oliver.sternicki@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: RE: [EXTERNAL] RE: 14-39 (PTD 188138) P&A Rev1 change request Oliver, Approved to make the tubing/control lines cut on the contingency a complete revised procedure and expected cement volumes are emailed to me for review. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Monday, September 22, 2025 7:26 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: RE: [EXTERNAL] RE: 14-39 (PTD 188138) P&A Rev1 change request Mel, Yes, but those volumes change a bit in the new procedure as when we down squeeze the OA, we will eventually open up the IA at surface to get cement returns. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, September 19, 2025 4:21 PM To: Oliver Sternicki <oliver.sternicki@hilcorp.com>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: [EXTERNAL] RE: 14-39 (PTD 188138) P&A Rev1 change request Oliver, I presume the rest of the procedure (below) is still relevant? CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell 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 Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Friday, September 19, 2025 10:41 AM To: Lau, Jack J (OGC) <jack.lau@alaska.gov>; Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Bo York <byork@hilcorp.com> Subject: 14-39 (PTD 188138) P&A Rev1 change request unless you recognize the sender and know the content is safe. Jack, Mel, We ran into issue with step #1 of the P&A program on 14-39 (PTD 188138). We were unable to remove the “brain” from the AVA TRSV so we cant get injectivity into the control and balance lines for cementing as initially planned in the approved sundry. Requesting approval of the attached Rev 1 program to jet cut the tubing to sever the control and balance lines at ~1100’ MD. Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com 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 an intendedrecipient 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 received this email inerror, 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 this messageand 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 and other checks as itconsiders 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 an intendedrecipient 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 received this email inerror, 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 this messageand 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 and other checks as itconsiders 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 an intendedrecipient 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 received this email inerror, 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 this messageand 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 and other checks as itconsiders 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 an intendedrecipient 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 received this email inerror, 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 this messageand 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 and other checks as itconsiders appropriate. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:9 Township:10N Range:14E Meridian:Umiat Drilling Rig:Rig Elevation:Total Depth:9850 ft MD Lease No.:ADL0028312 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface:13-5/8"O.D. Shoe@ 3612 Feet Csg Cut@ Feet Intermediate:9-5/8"O.D. Shoe@ 9467 Feet Csg Cut@ Feet Production:O.D. Shoe@ Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 9848 Feet Csg Cut@ Feet Tubing:4-1/2"O.D. Tail@ 9224 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Other 4852 ft 1352 ft 9.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: I traveled to location and met withg Caleb Piaskowski representing Hilcorp. We went over the objective of this job and the slickline BHA assembly. The cement plug is founded on the previous cement plug at a depth of 4852 ft MD. They ran in the hole with a standard assembly consisting of long stroke spangs, oil jars, 8 feet of 2-5/8" weight pipe and a 5-foot long 2-1/2" drive down bailer. They did a pre-tag and recieved a good cement sample ahead of time. They ran in the hole and tagged up in the same spot as the previous run. They tagged it several times and confirmed the top of cement depth. Good tag a little higher then expected. No MIT was required for this cement plug. October 1, 2025 Josh Hunt Well Bore Plug & Abandonment PBU 14-39 Hilcorp North Slope LLC PTD 1881380; Sundry 325-427 none Test Data: Casing Removal: Caleb Piaskowski Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 3-24-2022 2025-1001_Plug_Verification_PBU_14-39_jh              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 thes 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 14-39 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 188-138 50-029-21888-00-00 341J ADL 0028312 9850 Conductor Surface Intermediate Production Liner 9252 80 3579 9436 694 4852 20" 13-5/8" 9-5/8" 7" 4681 34 - 114 33 - 3612 31 - 9467 9154 - 9848 2732 34 - 114 33 - 3538 31 - 8895 8607 - 9250 9149 470 2670 4760 7020 4852, 9150, 9271 1490 5380 6870 8160 9391 - 9640 4-1/2" 12.6# L-80 29 - 92248825 - 9056 Structural 4-1/2" Baker DB Packer 4-1/2" AVA TRSV 9100, 8558 1991, 1991 Date: David Bjork for Bo York Operations Manager Oliver Sternicki oliver.sternicki@hilcorp.com (907) 564 4891 PRUDHOE BAY 8/4/2025 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE 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 By Grace Christianson at 2:56 pm, Jul 18, 2025 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Date: 2025.07.18 14:47:53 - 08'00' David Bjork (3888) 325-427 AOGCC witness tag TOC AOGCC witness casing cuts before any top job commences. AOGCC witness marker cap install before backfilling. Photo evidence of cement tops post-cut X X A.Dewhurst 29JUL25 10-407 JJL 7/21/25 DSR-7/18/25JLC 7/30/2025 Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2025.07.30 08:56:32 -08'00'07/30/25 RBDMS JSB 073125 P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 Well Name:14-39 Permit to Drill Number:188138 Well Type SU API Number:50-029-21888-00-00 Job Scope:P&A Reg.Approval Req’d?Yes Current Status:Not Operable, Offline Date Reg. Approval Rec’vd: Estimated Start Date:8/4/2025 Estimated Duration:20 days Regulatory Contact:Abbie Barker First Call Engineer:Oliver Sternicki Second Call Engineer:Jerry Lau Current Bottom Hole Pressure:3612 psi @ 8800’ TVD Max. Anticipated Surface Pressure:2732 psi Gas Column Gradient (0.1 psi/ft) Last SI WHP:0psi Min ID:3.812” TRSV Nip @ 1991’ MD Max Angle:26 deg @ 6059’ MD Top of Sag:9390’ MD Well History: 14-39 was originally completed as an Ivishak producer in 1988/ 1989. On 6/16/94 the 13.375” surface casing failed resulting a rapid gas release into the wellhouse. A noise/ temp log was executed on 6/19/94 while pumping N2 down the OA to determine the failure depth. Anomalies were found at ~40’ MD (81’ KB) and 400’ MD, though the log results were not conclusive. A plumb bob tagged TOC in the 13.375” x 20” annulus at ~41’ below surface. 4 OA cement down squeezes were executed on 10/24/94, 10/31/94, 11/6/94 and 11/27/94. Based on the volume of cement pumped away on the initial down squeeze when cement was seen at surface, the circulation point could be as deep as 190’ below surface. An MIT-OA on 12/31/94, after the down squeezes, failed with a LLR of ~1-2gpm at 2000 psi. In 2008 the well failed a CMIT-TxIA and a PC leak was found at 5483’ MD in 2009. On 11/20/10, under Sundry # 310- 248, the well was suspended with a reservoir plug placing TOC in the tubing at 4852’ SLM and ~5049’ MD in the IA. On 11/26/10 an MIT-T and CMIT-TxIA passed to 3000 psi, but a MIT-IA failed. The cause of the failed MIT-IA is unknown. Records indicate that the OA shoe is open and had sea water and diesel freeze protect to 2500’ MD pumped on 01/10/89. An OA injectivity test was executed on 9/20/92, establishing stabilized injection of 1.75 bpm at 1280 psi. Current Status: 14-39 is currently not operable and offline. Objectives: The objective of this program is to fully abandon 14-39 as part of the 2025 PBU P&A program. P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 Current Schematic P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. 1. Slickline: 1. Pull DGLV from GLM #1 at 3198’ MD. 2. Lock out AVA TRSV to gain injectivity into control line for cementing. 2. DHD: 1. Cement control line with microfine cement. 3. Fullbore Cement: 1. Verify circulation TxIA through open pocket in GLM #1. 2. Pump the following down the tubing, up the IA. Max pressure while pumping= 2500 psi. A. 5 bbls MeOH. B. 10 bbls fresh water. C. 217 bbls (20 bbls over calculated volume) 14- 16 ppg Class G permafrost (or similar) cement or until uncontaminated cement is seen at surface. D. 5 bbls fresh water. E. Foam ball. F. 10 bbls 9.8 ppg brine. G. 8 bbls 60/40 for freeze protect. Cement Type/weight:Class G permafrost cement 14-16 ppg or similar Bottom Hole Temp:10°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours Cement Volumes: x 4.5” tubing volume= 1500-3198’ MD= 1698’ MD: 1968’ x 0.0152= 26 bbls x 4.5” x 9.625” annulus volume= 0-3198’ MD= 3198’ MD: 3198’ x 0.0535= 171 bbls Total cement: 197 bbls (+ 20 bbls excess) Displacement: x 4.5” tubing from surface to 1500’ MD: 1500’ x 0.0152= 23 bbls Total displacement: 23 bbls 4. Slickline: 1. Drift and tag to TOC in 4.5” tubing @1500’ MD-AOGCC witnessed. 5. Eline: 1. Perforate 4.5” tubing and 9.625” casing at 300-310’ MD. Due to unknown depth of cement donut in OA and specialty gun (3.375” Bighole RDX) needed to get sufficient hole size in 9.625” casing, the plan is to initially shoot with a zero phase 4 spf, 1.56” Millennium DP gun to determine if we are shooting below the cement and once confirmed, follow it up with the specialty big hole charges. P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 A. Perforate 4.5” tubing and 9.625” casing at 300-310’ MD to establish injection point for OA cementing. zero phase 4 spf, 1.56” Millennium DP gun. B. Apply 500 psi to 4.5” prior to perforating, record before/after pressures. Pump into OA to determine if injectivity can be established for cementing. Max pressure= 2500 psi. Monitor OA for increased pressure, conductor annulus and cellar for returns. i. If injectivity is established, perforate same interval with 3.375” Bighole RDX gun. ii. In unable to establish injectivity contact OE, move down 200’ from previous shots and repeat the process with 1.56” gun. Continue to move downhole at 200’ intervals until injectivity is established. 6. Fullbore : ***Have vac truck on location in case returns come to the cellar due to historic SC leak. 1. OA shoe injectivity test. Circulate the following down the tubing and out the 9-5/8” annulus shoe to prep for cement. OA volume from 300-3612’ MD= 198 bbls, tubing volume from 0-300’ MD= 5 bbls. OA inj test on 9/20/92= 1.75 bpm at 1280 psi A. 5 bbls MeOH B. 25 bbls hot diesel (min 120 degF) C. 80 bbls hot (160degF) fresh water + surfactant. D. 95 bbls of 9.8 brine (80-100 degF). E. Max pressure 2500 psi. K-55 burst rating= 3450 psi (only top joint in well, shouldn’t see any pressure during this, but monitor OAP at surface to be sure 7. Fullbore Cement: 1. Circulate the following down the tubing to cement the tubing (from surface to 300’ MD) and 9- 5/8” x 13-3/8” annulus( from 300’ to 3612’ MD). A. 5 bbls MeOH B. 10 bbls fresh water C. 203 bbls 14- 16 ppg Class G permafrost (or similar) cement or until uncontaminated cement is seen at surface. D. Max pressure while pumping 2500 psi. Cement Type/weight:Class G permafrost cement 14-16 ppg or similar Bottom Hole Temp:10°F Fluid Loss:20-200cc/30 min Thickening Time:Minimum 8 hours Cement Volumes: x 4.5” tubing from surface to 300’ MD: 300’ x 0.0152 bpf= 5 bbls x 9.625”x 13.375” annulus from 300 - 3612’ MD: 3612’ x 0.0597 bpf= 198 bbls Total cement: 198 bbls Displacement: x No displacement 8. DHD: 1. Bleed all wellhead pressures to 0 psi. 2. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. 203 bbls (volume correction JJL) P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 9. Well Support: 1. Excavate and cut off all casings and wellhead 3’ below original tundra level. 2.AOGCC witness of cut-off casings before any top job commences. 3.AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld ¼” thick steel marker cap on outermost casing string. Photo document all steps and AOGCC witness of installed cap. Marker cap to read as follows: Hilcorp North Slope, LLC PTD # 188138 Well: PBU 14-39 API # 50-029-21888-00 5. Remove shoring box, backfill excavation. P&A Sundry Well: 14-39 PTD: 188-138 API: 50-029-21888-00 Proposed Schematic Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: July 18, 2025Subject: Changes to Approved Sundry Procedure for Well 14-39Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 7. 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 14-39 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 188-138 50-029-21888-00-00 9850 Conductor Surface Intermediate Production Liner 9252 80 3579 9436 694 ~5000 20" 13-5/8" 9-5/8" 7" 4819 34 - 114 33 - 3612 31 - 9467 9154 - 9848 34 - 114 33 - 3538 31 - 8895 8607 - 9250 9149 470 2670 4760 7020 ~5000 , 9271 1490 5380 6870 8160 9391 - 9640 4-1/2" 12.6# L-80 29 - 9224 8825 - 9056 Structural 4-1/2" Baker DB , 9100 , 8558 No SSSV 9100 8558 Bo York Operations Manager Ryan Holt Ryan.Holt@hilcorp.com (907) 659-5102 PRUDHOE BAY, PRUDHOE 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 0028312 29 - 8671 0 0 0 0 0 0 0 0 0 0 N/A 13b. Pools active after work:PRUDHOE 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 12:11 pm, Aug 06, 2024 Digitally signed by David Bjork (3888) DN: cn=David Bjork (3888) Reason: I am approving this document. Date: 2024.08.06 10:54:53 -08'00' David Bjork (3888) DSR-8/12/24WCB 10-1-2024 RBDMS JSB 080824 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: Prudhoe Bay UNIT 14-39 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 188-138 API Number: Lease Wellbore Traverses: Expiration Date: Operator: Hilcorp Alaska LLC Date Suspended: 11/20/2010 Surface Location: Section: 9 Twsp: 10N Range: 14E Nearest active pad or road: DS-14 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good Surrounding area condition: Good Water/fluids on pad: Good Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 4 Wellhouse Well Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: FMC Cellar description, condition, fluids: Good Rat Hole: None Wellhouse or protective barriers: Wellhouse Well identification sign: Good Tubing Pressure (or casing if no tubing): 0 Annulus pressures: IA - 0 psi OA - 0 psi Wellhead Photos taken (# and description): Work Required: Operator Rep (name and signature): Ryan Holt AOGCC Inspector: Brian Bixby Other Observers: Inspection Date: 7/7/2024 AOGCC Notice Date: 7/6/2024 Time of arrival: 10:15 AM Time of Departure: 10:30 AM Site access method: Drive 50029218880000 5 Year Digitally signed by Ryan Holt (4157) DN: cn=Ryan Holt (4157) Date: 2024.07.07 15:47:51 - 08'00' Ryan Holt (4157) ACTIVITYDATE SUMMARY 7/6/2024 T/I/O = 50/0/10. Temp = SI. WHPs (suspended well inspection). AL disconnected. OA cemented tp surface. Wellhouse, wellhead are clean, cellar has 6" of water in it (raining). There are two wooden boards and a piece of floor grating leaned up in the corner of the wellhouse with AL spool. Surface area around well is clean and clear of debris. Well ID sign on wellhouse. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 12:30 7/7/2024 T/I/O = 0/0/10. Temp = SI. WHP (suspended well inspection). (Witnessed by Brian Bixby). AL disconnected (spool in wellhouse). Surface area around well is clean and clear of debris. Well ID sign on wellhouse. SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 10:00 Daily Report of Well Operations PBU 14-39 Reviewed By: P.I. Suprv Comm ________ :ZϬϴͬϭϲͬϮϬϮϰ /ŶƐƉĞĐƚEŽ͗ƐƵƐϮϰϬϳϬϳϭϮϱϮϯϱ tĞůůWƌĞƐƐƵƌĞƐ;ƉƐŝͿ͗ ĂƚĞ/ŶƐƉĞĐƚĞĚ͗ϳͬϳͬϮϬϮϰ /ŶƐƉĞĐƚŽƌ͗ƌŝĂŶŝǆďǇ /ĨsĞƌŝĨŝĞĚ͕,Žǁ͍KƚŚĞƌ;ƐƉĞĐŝĨǇŝŶĐŽŵŵĞŶƚƐͿ ^ƵƐƉĞŶƐŝŽŶĂƚĞ͗ϭϭͬϮϬͬϮϬϭϬ η ϯϭϬͲϮϰϴ dƵďŝŶŐ͗Ϭ /͗Ϭ K͗Ϭ KƉĞƌĂƚŽƌ͗,ŝůĐŽƌƉEŽƌƚŚ^ůŽƉĞ͕>> KƉĞƌĂƚŽƌZĞƉ͗ZǇĂŶ,Žůƚ ĂƚĞK'EŽƚŝĨŝĞĚ͗ϳͬϲͬϮϬϮϰ dǇƉĞŽĨ/ŶƐƉĞĐƚŝŽŶ͗^ƵďƐĞƋƵĞŶƚ tĞůůEĂŵĞ͗WZh,KzhE/dϭϰͲϯϵ WĞƌŵŝƚEƵŵďĞƌ͗ϭϴϴϭϯϴϬ tĞůůŚĞĂĚŽŶĚŝƚŝŽŶ 'ŽŽĚ ^ƵƌƌŽƵŶĚŝŶŐ^ƵƌĨĂĐĞŽŶĚŝƚŝŽŶ 'ŽŽĚ ŽŶĚŝƚŝŽŶŽĨĞůůĂƌ 'ŽŽĚ ŽŵŵĞŶƚƐ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚtŝƚŚƐͲƵŝůƚDĂƉ͘ ^ƵƉĞƌǀŝƐŽƌŽŵŵĞŶƚƐ WŚŽƚŽƐ;ϰͿ ^ƵƐƉĞŶƐŝŽŶƉƉƌŽǀĂů͗^ƵŶĚƌǇ >ŽĐĂƚŝŽŶsĞƌŝĨŝĞĚ͍ KĨĨƐŚŽƌĞ͍ &ůƵŝĚŝŶĞůůĂƌ͍ tĞůůďŽƌĞŝĂŐƌĂŵǀĂŝů͍ WŚŽƚŽƐdĂŬĞŶ͍ sZWůƵŐ;ƐͿ/ŶƐƚĂůůĞĚ͍ Ws/ŶƐƚĂůůĞĚ͍ &ƌŝĚĂǇ͕ƵŐƵƐƚϭϲ͕ϮϬϮϰ 9 9 9 9 9 9 2024-0707_Suspend_PBU_14-39_photos_bb Page 1 of 2 Suspended Well Inspection – PBU 14-39 PTD 1881380 AOGCC Inspection Rpt # susBDB240707125235 Photos by AOGCC Inspector B. Bixby 7/7/2024 2024-0707_Suspend_PBU_14-39_photos_bb Page 2 of 2 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:188-138 6.API Number:50-029-21888-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028312 Property Designation (Lease Number):10. 8. PBU 14-39 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Renew Suspension Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9850 Effective Depth MD: L-80 11. 9/1/2020 Commission Representative: 15. Suspended 5 Contact Name: Ryan Holt Contact Email: Ryan.Holt@hilcorp.com Authorized Name: Bo York Authorized Title:Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: 4-1/2" AVA TRSV SSSV Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9252 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 9100, 8558 1997, 1997 Date: Liner 694 7"9154 - 9848 8607 - 9250 8160 7020 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 33 - 3612 33 - 3538 14. Estimated Date for Commencing Operations: BOP Sketch 34 - 114 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" Baker DB Packer 9391 - 9640 8825 - 9056 4-1/2" 12.6# L-80 29 - 9224 Production 5000 4819 5000,9150,9271 9149,9642,9643 34 - 114 470 13-3/8" 9-5/8" Contact Phone:(907) 659-5102 Date: 8/21/2020 4760 80 149020"Conductor 1950 / 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 3579 3450 / 5380 Intermediate 9436 31 - 9467 31 - 8895 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 12:13 pm, Aug 21, 2020 320-351 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.21 09:59:35 -08'00' Bo York MGR25AUG2020 10-404 SFD 8/21/2020 DSR-8/21/2020 Yes Required? C 8/25/2020 dts 8/25/2020 JLC 8/25/2020 RBDMS HEW 8/26/2020 Hilcorp North Slope, LLC Bo York, PBE Operations Manager 3800 Centerpoint Dr, Suite 1400 Anchorage, Alaska 99503 August 20, 2020 Mr. Jeremy Price Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Prudhoe Bay Well 14-39 (PTD #188138) Application for Renewal of Existing Suspension (10-403) Dear Mr. Price, An AOGCC witnessed suspended well inspection of Prudhoe Bay well 14-39 was conducted on 07/06/2019 (20 AAC 25.110 (h)). This recently submitted suspended well inspection reflects the current condition of the well (reference 20 AAC 25.110 (f)) and supports the request for renewal of suspension. Recent events from this well indicate that this well is mechanically sound. Specific attachments include: x Wellbore diagram illustrating the current configuration of the well x Suspended Well Site Inspection form documenting the pressures and site condition Prudhoe Bay well 14-39 was suspended on 11/20/2010. It is located on a pad with active wells and/or service wells. The strata through which the well was drilled is neither abnormally geopressured or depleted. The well is mechanically sound and secured with a passing pressure test of the cement top at ~5000’ MD and the 9-5/8” casing. Based on these conditions and the inspection on 07/06/2019 Prudhoe Bay well 14-39 meets the provisions required in 20 AAC 25.110 (a)(1). Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for this well. Attached is an Application for Sundry Approval (10-403) with a technical justification summarizing the information on the current status and condition of the well (reference 20 AAC 25.110 (a), (b), (e), (h)). In summary, Hilcorp believes Prudhoe Bay well 14-39 is mechanically sound and secure and meets the requirements for renewal of suspended status. If you have any questions, please call me at 907-777-8345 or Ryan Holt/ Andy Ogg at 659- 5102. Sincerely, Bo York PBE Operations Manager Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2020.08.21 09:59:54 -08'00' Bo York Attachments Technical Justification 2019 Suspended Well Site Inspection form Wellbore Schematic Prudhoe Bay Well 14-39 (PTD #188138) Technical Justification for Renewal of Suspended Status August 20, 2020 Well History and Status Prudhoe Bay well 14-39 (PTD #188138) was suspended on 11/20/2010 after a lateral cement plug was placed across the tubing and IA to secure the well. Cement was placed in the IA from the packer at 9100’ MD to ~5049’ MD and cement was placed in the tubing from the WRP set at 9150’ MD to 4852’ MD. The well is mechanically sound and secured with a passing pressure test of the cement top and the 9-5/8” casing. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe and not a threat to public health. The strata through which the well was drilled is neither abnormally geo-pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay well 14-39 is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. The well pressure readings are T/I/O = 0/0/0 psi. Request Hilcorp North Slope, LLC requests approval for renewal of the existing suspension status for 14- 39. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to remain as suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS � nsm rt aeC��'9�� ED 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown '0 Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Reenter Susp Well ❑ Other: Suspend Inspection 0 2. Operator Name. BP Exploration (Alaska), Inc 4, Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number 188-138 3. Address: P.O. Box 196612 Anchorage, API Number: 50-029-21888-00-00 AK 99519-6612 St2tigraphic ❑ Service 116. 7. Property Designation (Lease Number): ADL 0028312 S. Well Name and Number: PBU 14-39 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth: measured 9850 feet Plugs measured 5000, 9150, 9271 feet true vertical 9252 feet Junk measured 9149, 9642, 9643 feet Effective Depth: measured 5000 feet Packer measured 9100 feet true vertical 4819 feet Packer true vertical 8558 feet Casing. Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 34-114 34-114 1490 470 Surface 3579 13-3/8" 33-3612 33-3538 3450/5380 1950 / 2670 Intermediate 9436 95/8" 31-9467 31-8895 6870 4760 Production Liner 694 T' 9154-9848 8607-9250 8160 7020 Perforation Depth: Measured depth: None feet True vertical depth'. feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 29-9224 29-8671 Packers and SSSV (type, measured and 4-1/2" Baker DB Packer 9100 8558 true vertical depth) a112" AVA TRSV SSSV 1991 1991 12. Stimulation or cement squeeze summary. Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13, Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 14. Attachments: (req., a per 20 MC 25.070 25 071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development p Service ❑ St2tigraphic ❑ 16. Well Status after v2ork: Oil ❑ Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ® SPLUG ❑ Sundry Number or N/A if C.O. Exempt: 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Authorized Name: Lastufka, Joseph N Contact Name: Montgomery, Travis J Authorized Title: M Special t Contact Email: T2vis.MontgomeryAbp.com Authorized Signature: Date:1I 0II 6i Contact Phone: +1 907 564 4127 Form 10404 ReNsed 04/2017 M6X0 j I *"i RBDMS.r"Wra-"JUL 312019 Submit Original Only TWO = 50/0/0. Temp = SI. Pre AOGCC SU well inspection. AL disconnected. Wellhouse, wellhead and cellar are clean and dry. There are two wooden boards and a piece of floor grating leaned up in the corner of the wellhouse. Surface area around well is clean, dry and clear of debris. Well ID sign on wellhouse. 6/30/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 01:00 T/1/0 = SSV/0/0. Temp = SI. AOGCC SU well inspection (Witnessed by Bob Noble). AL removed. Well id sign on wellhouse. 7/6/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 08:20 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 14-39 Field/Pool: Prudhoe Bay / Prudhoe Oil Permit # (PTD): 1881380 API Number: 50-029-21888-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: -8ti M2f1'IS Surface Location: Section: 9 Twsp: 10N Range: 14E Nearest active pad or road: DS -14 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, Including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: 1 ecfn Pad or location surfaceI O -a A n i' kU i Location cleanup needed: Pits condition: Surrounding area conditio Water/fluids on pad: Discoloration, Sheens on Samples taken: None Access road condition: Photographs taken (# and description): Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: n Cellar description, condition, fluids: Dry Rat Hole: A Wellhouse or protectivebarriers: We I I Hou S Well identification sign: f' Tubing Pressure (or casing if no bing): f 3 Annulus pressures: fi Wellhead Photos taken (# and description): S r - Wt II lie' Work Required: None Operator Rep (name AOGCC Inspector: Inspection Date: _ Time of arrival: Site access method,.- Josh ethod: Josh Prowant AOGCC Notice Date: Time of Departure: ) 1411 B �� C: 12-28 1410 fr 14-30A X-09 _ 1417 1332A IC L 14098 L'. 1405 13-32 :i-33Pfi 1 14-17A53 X-096_- 1440 14-08A7. 1409A,P81 14-09ARD 14-08AL1 P61 _. 14-22A 13-31A '. {I 14-40A'1408AL1 14-44PB1 714-21 - 14-22 X-22 F.. 13-29 [: 1421 1409,9: 1331 14-44APB1 Y 1408A 4A 13.29L1 I 1403A" C. B -26C i 3 X-02 I 'J X -04A 4 MI5 _. X-18 [, /1 1441 14-31 Q 07-20G-, 1423 �X-18 .� 1432 14-34PB2 1423A X14-23APG1 0 14,20 14-1614-18A X -24A 14-19PB1 x5b. 14-234-8 1418 � 1419 ;.N 1443 � i 1418APB1 --- v 14-24A -II.. 1 �l 143APEL6 438— X-15 14-02:.L1�141,3 f, J 14-34A ` X -03A V , 25 ` 3' X-21 14 18 _ -- _ SBPB7 - DS 14 1407 1 1$APB2 [- q , 14-12 � 1418 P81�1418APB3 ` `114188 1418 *- 1418APB4 --� L X-08 C 1437 t 7 14-2b 14288 14 - 10 t' 13-23A 14-02C 8 N X-07 C 428A 7 14-02A L 1423 V X-23 . 1 OS1411A 00.128 14-11APB1 X1439-_ 1 11AL1 '0 1428 - . 1430 _ X -09A - I _ 1409 ) 1411 B �� C: 12-28 1410 fr 14-30A X-09 _ 1417 1332A IC L 14098 L'. 1405 13-32 :i-33Pfi 1 14-17A53 X-096_- 1440 14-08A7. 1409A,P81 14-09ARD 14-08AL1 P61 _. 14-22A 13-31A '. {I 14-40A'1408AL1 14-44PB1 714-21 - 14-22 X-22 F.. 13-29 [: 1421 1409,9: 1331 14-44APB1 Y 1408A 4A 13.29L1 TRFF = FMC GEN 4 SUSPENDED 14-39 WELLHEAD = FMC ACTUATOR= AXELSON KB. ELEV = 74 BF. ELEV = 43.65' KOP = 2400' Max ArMle = 26-@61W Datum MD = RK Datum TVD = 8800' SS 113-3/8' CSG, 6811, K-55 / 72i1, L-80, D = 12.347' I P:I�;Ye-h=Y01: H I 11-69' TUBING PUNCH (11/13110) 1 Minimum ID = 3.725" @ 9213' 4-1/2" OTIS XN NIPPLE TOP OF 7- LNR 9163' SAFETY NOTES: 14-12' AVA TRSV SSSV NP, D=3.812' 1 1 3198 3158 23 MMG DMY RK 0 1027108 2 4742 4579 22 MMG •DMY RK 0 SPF 3 5576 5354 24 MMG •DMY RK 16 1027108 4 6700 6370 26 MMG 'DMY RK 0 1027/08 5 7488 7083 25 MMG •DMY RK 0 4' 6 8022 7566 25 MMG •DMY RK 0 12/05/08 7 8137 7671 24 MMG 'DMY RK 0 1027108 8 8838 8316 22 MMG 'DMY 'NO 0 9 8990 8456 23 MMG 'EQ DMY `NO 0 11/01110 STA 98 - LATCH BROKEN OFF VALVE (1 028108) 91IQD' 9-5/8'X4-12-BKR DB PKK D=? 9�4—W--1FISH: 118' X 1.375' WASHER (10/27/08) 9213' -14-12.OTIS XN NP, ID= 3.725' 8223' 4-12'BKR SHEAROLITSUB .0152 bpf, D = 3.958' 9714' 92M 4-12' WLEG, D = 3.958' 9-5/8' CSG, 47#, L-80, D=8.681' 94ST 17' LINK 29#, L-80, 0.0371 bpf, D=6.184' 8219' ELMD TT LOGGED 12130/91 DATE REV BY COMMENTS PERFORATION SUMMARY REV BYMADDEDBF NTS 12MSM8 REF LOG: BHCS ON 12/12/88 11/14/10 MBM/PJCN ANGLE AT TOP PERF: 23' @ 9391' LAST WORKOVER Hole: Refer to Production DB for tistoriwl perfdata S12E SPF NTERVAL OPrVW DATE 4- 4 9391-9413 C 01/05/89 4' 4 9506-9543 C 01/05/89 4- 4 9545-9566 C 01/05/89 4' 4 9570-9586 C 01/05/89 4' 4 9596-9612 C 01/05/89 4' 4 9624-9640 C 01/05/89 17' LINK 29#, L-80, 0.0371 bpf, D=6.184' 8219' ELMD TT LOGGED 12130/91 DATE REV BY COMMENTS DATE REV BYMADDEDBF NTS 12MSM8 ORIGINAL COMPLETION 11/14/10 MBM/PJCN LATCH (111011 01108189 LAST WORKOVER 11/16/10 RRD/PJC3I70) 10/16108 OOB/PJC GLV CORRECTION 1124/10 DMS/PJB 1120/08 CJN/TLH FISH/GLV C/O (1022 81027108) 0729/19 JNUJMD & SUSPENDED 1122/08 /TLH GLV & SSSV DEPTH CORRECT. 12112MB GJF/SV GLV CIO (12105,M) I(2) HES-N-15RRRK (LOST 0122/94) EIP RUBBER ELEMENTS (08/19/03) PRUDHOE BAYUNIT WELL: 14-39 PERMrT No: 1881380 API No: 50-029-21888-00 IN, R14E, 2759.62' FEL & 5202.77' BP Exploration (Alaska) Suspended Well Inspection Review Report InspectNo: susRCN190708124031 Date Inspected: 7/6/2019 Inspector: Bob Noble Well Name: PRUDHOE BAY UNIT 14-39 " Permit Number: 1881380 Suspension Approval: Sundry # 310-248 ' Suspension Date: 11/20/2010 Location Verified? If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 7/5/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? Photos Taken? Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 0 - BPV Installed? ❑ OA: 0 VR Plug(s) Installed? ❑ Wellhead Condition Wellhead looks to be in good condition. Flowline is still attached. SSV is closed. Wellhead protected with a well house. AL line is removed and blinded. Condition of Cellar Good clean dry gravel. Surrounding Surface Condition Good clean gravel, Comments Location is verified with the used of a pad map. Supervisor Comments Photos (2) attached Monday, August 19, 2019 Suspended Well Inspection — PBU 14-39 PTD 1881380 AOGCC Inspection Rpt # susRCN190708124031 Photo by AOGCC Inspector B. Noble 7/6/2019 2019-0706_Suspend_PBU_14-39 photos_bn.docx Page 1 of 1 • STATE OF ALASKA ',ALASKA OIL AND GAS CONSERVATION COMMI N k REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redrill ElPerforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well m 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 188-138 3. Address: P.O.Box 196612 Anchorage, Development Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21888-00-00 7. Property Designation(Lease Number): ADL 0028312 8. Well Name and Number: PBU 14-39 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Viz, Z--' Total Depth: measured 9850 feet Plugs measured 4852/9120 feet true vertical 9252 feet Junk measured 9149/9642/9643 feet ULT: f) 2 i, Effective Depth: measured 4852 feet Packer measured 9100 feet true vertical 4681 feet Packer true vertical 8558 feetr- a'* t'' i. tL Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"91.5#H-40 36-116 36-116 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate Production 9433 9-5/8"47#L-80 34-9467 34-8895 6870 4760 Liner 695 7"29#L-80 9153-9848 8606-9250 8160 7020 Perforation Depth: Measured depth: 9391 -9413 feet 9506-9543 feet 9545-9566 feet 9570-9586 feet 9596-9612 feet 9624-9640 True vertical depth: 8825-8845 feet 8931-8966 feet 8968-8987 feet 8991-9006 feet 9015-9030 feet 9041-9056 Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#L-80 33-9224 33-8671 Packers and SSSV(type,measured and 4-1/2"BAKER MODEL D PACKER 9100 8558 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: %MORI NOV 1 6 2015 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 358 706 4287 1473 220 Subsequent to operation: 0 0 0 0 0 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.2831 15.Well Class after work: Daily Report of Well Operations p Exploratory 0 Development m Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature 1_ C • Phone +1 907 564 4424 Date 8/6/15 Form 10-404 Revised 5/2015 17"7"L 9/z I f7 !/� SWILMV Original Only RBDMS AUG 1 4 2015 • • m O 0 0 0 0 0 10 N- Cfl N O M O N ti U N 0 0 0 0 0 0 I.. 0) CO Cr) ti CO CO 0) CO CO CO "Cr CO CO CO CO In (.0 10 co 0) CC) N. lO LO CO N CO CO CO CA CO a I I 1 I I I- CO CO CO CO CO CO CO CO C N CO •4 - co N - LO CO 'Cr CO N L M C) O) C7) C) p I 1 1 I I 4-• 0 Q M M Cfl I L co ca M co inM M O L▪ W I-- a 1C) O O • Ln co co = d *k COCN 44 J CO •Cl) N ` CO I� *k CO (A cu � pp N - O C7 M N N c.,;) ) i N t +' N- CO A- M O O IC) co OIC) a) C co N d co co CO 0) J Z c O c H w w U ° ULi - aLt Z a. o O w m ODD OCOU) 0- --I !— I . • c rn 0 c as a) 0 a) m m L U 2 U- C cu O_ } tL a) E 4' < E O Q (I5 W O _ 0 Cr) 5 M o � s_ a o0 CD Qo cs) � - � CU Q - a) Q a.- d U U „- 5 O U lL 0c O Q .� Z W I- < If) } O 5--N- - m I ti U • • Suspended Well Site Inspection Form Initial/5 Year!10 Year inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 14-39 Field/Pool: PRUDHOE BAY/PRUDHOE OIL Permit#(PTD): 188-138 API Number: 50029218880000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/20/2010 Surface Location. Section: 9 Twsp: 10N Range 14E Nearest active pad or road: DRILL SITE 14 Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean, active pad Pad or location surface: graded gravel Location cleanup needed: none Pits condition: good, rain water Surrounding area condition: clean Water/fluids on pad: none Discoloration. Sheens on pad, pits or water: none Samples taken: none Access road condition: good Photographs taken (#and description): (2)flowline and wellhouse Condition of Wellhead AOGCC requires: 1)a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition. FMC gen 4 wellhead, FMC tree, clean and functional Cellar description, condition, fluids: good, steel box Rat Hole: N/A Wellhouse or protective barriers: well house Well identification sign: yes, correct Tubing Pressure(or casing if no tubing): 0 psi Annulus pressures IA/OA= 0/80 psi Wellhead Photos taken (#and description): (3)wellhead and master Work Required none Operator Rep(name and signature): Whitney Pettus AOGCC Inspector: Matt Herrera Other s erv- Ryan Hayes Inspection Date: 7/12/2015 AOGCC Notice Date: 7/8/2015 Time of arrival: 8:30 AM Time of Departure: 8:35 AM Site access method: truck 0 • 4 ctm o a C R n G d = d , N L _ � _ _ J J .. fn fp J a a ( ( a f.a o vi c9 o a o v C w .-1 m o cn r ffJJ qa Pf Xd 03 w O tJ M1 7 t O ,,..^''�.�` `o .=.=-''''''''-*--'''-' c 0 2 f -2' 4 --- <„,.-- - - m T o 'a .O+ y f*T rQp� I ' N co nN pi rn c0 N. 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TREE= s FMC GEN 4 VSIELLHEAD= FMC 14-3 9 S Y NOTES: ACTUATOR= AXELSON KB.ELEV= 74' BF ELEV= KOP= 2400' Max Angle = 26 @ 6100' 1991' H4-1/7'AVA TRSV SSSV NIP, ID=3.812" I Datum MD= ® Datum TVD= 8800'SS GAS LIFT MANDRELS ST MD TVD DEV TYPE V L V LATCH PORT DATE 1 3198 3158 23 MMG DMY RK 0 10/27/08 13-318"CSG,68#,K-55/72f1 L-80, ID=12.34T' — 3612' 2 4742 4579 22 MAG `DMY RK 0 3 5576 5354 24 Mu1G `DMY RK 16 10/27/08 �� 4 6700 6370 26 MMG 'DMY RK 0 10/27/08 TOP OF CEMENT-TBG I —5000 v.'.��1 •.-•-• 57488 7083 25 MMG 'DRY RK 0 TOP OF CEMENT-CSG —1 —5049 ►�•••:'4.:.:.:.►.: 6 8022 7566 25 MC 'DMY RK 0 12/05/08 0•4••••►♦ 7 8137 7671 24 MMG 'DMY RK 0 10/27/08 ►••�►••••••••�• ,• 8 8838 8316 22 MMG `DM' `NO 0 1-69"TUBING PUNCH(11/13/10) I— 9011' -9032' y•to►•�•�•�•4,��• 9 6990 8456 23 MMG 'EO DMY 'NO 0 11/01/10 ►*-i•,•,��,4►•, STA#8-LATCH BROKB1 OFF VALVE(10/26/08) • • ►�•,►�•�•�•�•�0* STA#9-LATCH BROKE OFF VALVE(11/01/10) ••••••4� ►��►� • -#8"GL M S#2 BFUND CEMENTED Minimum ID = 3.725" @ 9213' ►►�•!►.•.•.•.• �• 9100' 9 5/8"X 4 112"BKR DB PKR,ID=? 4-112" OTIS XN NIPPLE -- -.-.-.-.r— �� ►•�•••••• 9149' HFISH:1/8"X 1,375"WASHER(10127/08) I TOP OF 7"LNR —I 9153' 9150' �4 112"WRP PLUG(05/19/08) ' ' 9213' —14-1/2"OTIS XN NIP,ID=3.725" I 9223' —14-1/2"BKR SHEA ROUT SUB 14-1/2"TBG-PC, 12.6#,L-80,.0152 bpf,ID=3.958" -J 9224' I 9224' —14-1/2"WLEG,ID=3.958"I 9271' —ITOP OF SAND(08/19/03) I 19-518"CSG,47#,L-80,ID=8.681" — 9467' I---4 L 9219' H ELMD TT LOGGED 12/30/91 I — PERFORATION SUMMARY REF LOG: BRCS ON 12/12/88 I A NGL E AT TOP PERF: 23 @ 9391' Note:Refer to Production 138 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1 4" 4 9391 -9413 C 01/05/89 4" 4 9506-9543 C 01/05/89 4" 4 9545-9566 C 01/05/89 I 4" 4 9570-9586 C 01/05/89 4" 4 9596-9612 C 01/05/89 _ AL 4" 4 9624-9640 C 01/05/89 9642' —(2)HES-N-15RP-RK(LOST 01/22J94) IBP RUBBER ELEMENTS(08/19/03) Aiv9642' —IHES-02-20RC-RK(LOST 01/21/94) I PBTD —I 9802' 7"LNR,29#,L-80,0.0371 bpf, U=6.184" H 9848' DATE REV BY COMMENTS DATE REV BY COMMENTS I PRUDIIOE BAY UNIT 12/15/88 ORIGINAL COMPLETION 11/14/10 MBM/PJC GLV C/O- BROKEN LATCH(11/01/ 0) WELL' 14-39 01/08/89 LAST WORf(OV B2 11/16/10 RRD/PJC TBG PUNCH(11/13/10) PERMIT No: 1881380 10/16/08 OOB/PJC GLV CORRECTION 11/24/10 DMS/PJB P&A (11/20/10) API No: 50-029-21888-00 11/20/08 CJN/TLH FISH/GLV C/O(10/22 810/27/08) SEC 9,T10N,R14E,2759.62'FEL&5202.7T FNL 11/22/08 /TLH GLV&SSSV DEPTH CORRECT.! 12/12/08 GJF/SV GLV C/O(12/05/08) BP Exploration(Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 07/12/15 Inspector: Matt Herrera Operator: BPXA Well Name: PBU 14-39 Oper.Rep: Ryan Hayes PTD No.: 1881380 Oper.Phone: 907-659-5766 Location Verified? Yes Oper.Email: rvan.havesObp.com If Verified,How? LAT/LONG • Onshore/Offshore: Onshore • Suspension Date: 11/20/10 - Date AOGCC Notified: 07/08/15 - Sundry No.: 310-248 Type of Inspection: Subsequent Wellbore Diagram Avail.? Yes ' Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 OA 80 5CM► EQ AUG 1 9 2015 Condition of Wellhead: Good,Gauges operable Condition of Surrounding Surface Location: Good no standing water or oil sheen discoloration around well house small oil puddle in cellar area Follow Up Actions Needed. Monitor IA and OA pressure and visually inspection by Operator ' Comments: SSV was OPEN Attachments: Photos(3) / REVIEWED BY: Insp.Supry jne bj II'I S Comm PLB 12/2014 2015-0712 Suspend_PBU_14-39_mh.xlsx Suspended Well Inspection—PBU 14-39 PTD 1881380 - Photo by AOGCC Inspector M. Herrera 7/12/2015 BP Exploration (Alaska) Inc. Prudhoe Bay Unit - Well No 14-39 SL:2539S &1599 W of NE CR Sec.9 ,T1ON,R14E, UM BHL: 75 'N &2527 E of SW CR Sec. 9 ,T1ON,R14E, UM State Lease No. ADL 28312 Drilling Permit No.88 - 138 APL 50-029-21888 111111.1111.1.11111.111F- '';7,Pip,r_ -;.. Al A to}f z . �1 .. M1F.M av ril _ - 4! ,41Arie a. -----v•-•.q,",,,,,,,..-74.,,: :.>_ - ,:-. ... 2015-0712 Suspend_PBU_14-39photos_mh.docx Page 1 of 2 • taloa\61,4 mi 44 hah.. ' ifir 1., , , ' to , .. , I 7 ,......... t i ..,. a \ A. i' ,' t / , . ,,, :;:p.,,. ,00. :40041, ',1, It, / c iE, R ,,, 0 ,,,,i0,.4-,,,,..., '144` ''' 4 ' bit w I ' ,,FA.4019 ‘,, if ,i , 2015-0712 Suspend_PBU_14-39_photos_mh.docx Page 2 of 2 • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 January 6, 2012 �. 3� Mr. Tom Maunder Alaska Oil and Gas Conservation Commission West 7 Avenue 411s3! t ffi! Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 14 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 14 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS-14 Date: 11/05/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft gal 14-01A 1931850 50029203170100 14-02C 2071150 50029203180300 14-03A 1961290 50029203190100 1404A 1961640 50029203200100 14-05A 1920010 50029203270100 14.06A 2040360 50029203280100 14-07 1780660 50029203290000 14-08A 2022100 50029203300100 14-09B 1820340 50029205340200 14-10 1801300 50029205280000 14-11A 2051260 50029205290100 1412 1811090 50029206310000 14-13 1811010 50029206240000 14-14 1811020 50029206250000 14-15 1810840 50029206110000 14-16A 1971670 50029206080100 14-17A 2030010 50029205620100 14-18B 2071290 50029205510200 14-19 1810450 50029205780000 14-20 1810700 50029205980000 14-21A 2051070 50029207560100 14-22A 1921230 50029207470100 14-23A 2090200 50029207570100 14-24 1830910 50029209700000 14-25 1831020 50029209810000 14-26 1811100 50029206320000 14-27 1831700 50029210460000 14-28 1820120 50029207080000 14-29 1811680 50029206800000 14-30 2050940 50029206790100 14-31 1831110 50029209890000 0 NA 0 NA 10.20 11/5/2011 14-32 1831220 50029209990000 14-33 1831250 50029210020000 14-34 1831330 50029210100000 14-35 1831420 50029210180000 14-36 1831630 50029210390000 14-37 1880490 50029218100000 14-38 1881030 50029218620000 - "—� 14-39 1881380 50029218880000 Dust Cover NA NA NA 6.80 11/5/2011 14-40A 2011350 50029218750100 Dust Cover NA 0.0 NA 10.20 11/5/2011 14-41 1920960 50029222900000 14-43 1921080 50029222960000 - 14-44A 2021930 50029225730100 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report 07/02/11 Date Inspected: Inspector: Matt Herrera Operator: BPXA Well Name: PBU 14 -39 - Oper. Rep: Jon Arend PTD No.: 1881380 Oper. Phone: 907- 659 -5766 Location Verified? Yes Oper. Email: areni2abp.com If Verified, How? LAT / LONG Onshore / Offshore: Onshore Suspension Date: 11/20/10 - Date AOGCC Notified: 06/29/11 Sundry No.: 310 -248 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 70 Photos Taken? Yes IA 0 - OA 0 , i ` L '+PfiS'FWi. I 1, • Condition of Wellhead: Good; liner in cellar with water determined to be snow melt. All gauges on tree operational. Condition of Surrounding Surface Location: Good. Slight subsidence around cellar but clean. Well sign on well house, Follow Up Actions Needed: Operations get regular annulus readings and perform regular visual inspections. Comments: None BY: Attachments: Photos (2) R EVIEWED � I(�Z Z' Insp. Supry Comm PLB 11/2011 2011- 0702_Suspend_PBU_14- 39_mh.xls Suspended Well Inspection — PBU 14 -39 PTD 1881380 Photo by AOGCC Inspector M. Herrera ,.\ i1 ,\ A 1 tri, ,_ i Eli • I i , - ., ' , ' ,„ :Ai I Inc. ; , A m Y . «, Prudhoe By Unit ,, ► • -3 �, ., ' . :_ . :-. -. — . SL:25 • •� S & 1599 W of NE C . , . , „ , )N R14E, UM ., -. E , r; ., BHL: 75 N &2527 " E 0 `,, .-,,.,` r* ", T1ON,R14E, UM `> �,� '� Sec. 9 >. • iff- illre State Lea No. ADL 28312 r + ' 3 - " ° 411144\. • Drilli it No. 8$ - 138 b..* � h 0 -029 21888 - ' Iti r PBU 14 -39 Suspended Well Inspection 7 -2 -11 mh STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 REPORT OF Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ INSPECTION Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development la Exploratory p • 188 -1380 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 21888 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: r ADLO- 028312 •- PBU 14 -39 10. Field /Pool(s): M PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 9850 feet Plugs (measured) 9271, 9150, 4852 (TOC) feet true vertical 9251.91 feet Junk (measured) 9642, 9643 feet Effective Depth measured 4852 feet Packer (measured) 9100 feet true vertical 4681.47 feet (true vertical) 8558 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 36 - 116 36 - 116 1490 470 Surface 20' 13 -3/8" 68# K -55 35 - 55 35 - 55 3450 1950 Surface 3557' 13 -3/8" 68# L -80 55 - 3612 55 - 3538 4930 2270 Production 9433' 9 -5/8" 47# L -80 34 - 9467 34 - 8895 6870 4760 Liner 695' 7" 29# L -80 9153 - 9848 8606 - 9250 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - - - True Vertical depth: _ - - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 9224 33 - 8672 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker Model D Packer 9100 8558 12. Stimulation or cement squeeze summary: Intervals treated (measured): ] 1 jUL L i 6 2 Treatment descriptions including volumes used and final pressure: ,`il� 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGD GINJ ❑ SUSPQj SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - • = Lastu ' ( Title Petrotechnical Data Technologist Signatur MAII Phone 564 -4091 Date 7/11/2011 II It Form 10 -404 Revised 10/2010 RBDMS JUL 13 2011 _ / Submit Original Only %0- "lam 14 -39 188 -138 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 14 -39 1/5/89 PER 9,391. 9,413. 8,825.13 8,845.42 14 -39 1/5/89 PER 9,506. 9,543. 8,931.44 8,965.78 14 -39 1/5/89 PER 9,545. 9,566. 8,967.63 8,987.13 14 -39 1/5/89 PER 9,570. 9,586. 8,990.85 9,005.71 14 -39 1/5/89 PER 9,596. 9,612. 9,015.01 9,029.89 14 -39 1/5/89 PER 9,624. 9,640. 9,041.05 9,055.94 14 -39 8/20/03 SPS 9,271. 9,640. 8,714.67 9,055.94 14 -39 5/19/08 BPS 9,150. 9,640. 8,603.62 9,055.94 14 -39 11/20/10 SQZ 4,852. 9,150. 4,681.47 8,603.62 AB ABANDONED PER PERF APF ADD PERF RPF REPERF . BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: DS14 -39 Field /Pool: Prudhoe Bay /PBU Permit # (PTD): 188 -138 API Number: 500292188800 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 11/20/10 Surface Location: Section: 9 Twsp: 10N Range: 14E Nearest active pad or road: Drillsite 14 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: Good - Currently Dewatering Surrounding area condition: Good - Clean Water /fluids on pad: None _ Discoloration, Sheens on pad, pits or water: None Samples taken: None _ Access road condition: Good Photographs taken (# and description): (2) Front of Wellhouse and surround, Back of Wellhouse and surround Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good Condition, FMC Wellhead, FMC Tree Cellar description, condition, fluids: Ce,Ilar liner, Good, 3" meltwater- no sheen Rat Hole: None VVellhouse or protective barriers: Wellhouse- Good condition Well identification sign: Yes Tubing Pressure (or casing if no tubing): 70 psi Annulus pressures: IA - 0 psi, OA - 0 psi Wellhead Photos taken (# and description): (2) Wellhead, Tree Work Required: None ' Operator Rep (name and signature): Gerald Murphy AOGCC Inspector: Matt Herrera Other Observers:' Jon Arend Inspection Date: 7/2/2011 AOGCC Notice Date: 6/26/2011 Time of arrival: 8:30 AM Time of Departure: 9:00 AM Site access method: Truck • • Prudhoe Bay Unit Well 14 -39 PTD 188 -138 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU 14 -39on 7/2/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Matt Herrera witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within 1 /a mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • PBU 14 -39 was suspended on 11/20/2010 after several unsuccessful attempts to regain operable status. • PBU 14 -39 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The well is secured with cement in the tubing from a WRP set at 9150' to the TOC which is 4852' SLM. IA is filled with cement from 9100' to TOC at —5049'. • The well is mechanically sound as proven by a CMIT TxIA tested to 3000# after the cement was pumped. AWO 7/8/2011 TREE = FMC GEM 4 • WELLHEAD = FMC • 14-39 SAFETY hilk: ACTUATOR = AXELSON KB, ELEV = 74' BF. ELEV = KOP = 2400' Max 'An' ngle = @ 6100' ( 1991' 1-1±-E. AVA TRSV SSSV NIP, ID = 3.812" 1 Datum MD = Datum TVD= 8800' SS GAS LIFT MANDRELS STI MD TVD DEV TYPE VLV LATCH PORT DATE 1 3198 3158 23 MMG DMY RK 0 10/27/08 113 -3/8" CSG, 68 #, K -55 / 72#, L -80, ID = 12.347" H 3612' 1 2 4742 4579 22 MMG 'DM' RK 0 3 5576 5354 24 14/MG *DMY RK 16 10/27/08 4 700 6370 26 !WOG *DMY RK 0 '. -4 I TOP OF CEMENT -TBG H — 5000 r--4; : � MM •� ►-v 5 7488 7083 25 G *DMY RK 0 10/27/08 'TOP OF CEMENT -CSG I - 1 " -5049 j ' � '4 ", 6 8022 7566 25 WOG *DAY RK 0 12/05/08 ► ♦ ♦ 4 � ♦ ♦ ♦ ♦ ♦ ♦ ♦ a ♦ 7 8137 7671 24 P 1G "DMY RK 0 10/27/08 ♦ ♦ , ► ♦ ♦ ♦ ♦ ♦ ♦ ♦ ♦ti ♦ ♦ 8 8838 8316 22 AtIvIG *DMY *NO 0 11'69" TUBING PUNCH (11/13/10) H 9011' - 9032' it j ♦ ♦ ♦Q1►♦♦ 9 8990 8456 23 MG *ED DMY NO 0 11/01/10 ►♦ ♦• ♦ ♦ ♦♦ ♦ ♦ ♦4♦♦ STA #8 - LATCH BROKEN OFF VALVE (10126/08) I. ► ., 4t. STA # 9 - LATCH BROKE OFF VALVE (11/01110) ♦� ♦ ♦ ♦ ♦ *GLMS #2 -#8 B�H1NDCEMENTED Minimum ID = 3.725" @ 9213' ► ♦; ►♦ i ♦i ♦i ♦ ♦ ♦ ♦ ♦ I 9100' H9- 5 /8 " X4- 1 /2 "BKRDBPKR, =? I 4 -1l2" OTIS XN NIPPLE = F.- — ♦ ♦ � ♦ ♦ ♦ ♦♦ I 9149' I_I FISH: 1/8" X 1.375" WASHER (10/27/08) 1 ' ♦- -, - 9150' 4-1/2" WRP PLUG (05 /19/08) ITOPOF7" LNR H 9153' I h 1 1 1 1 9213' 1 /2" OTIS XN NIP, ID = 3.725" I 9223' H4-1/2" BKR SHEA ROUT SUB I 14-1/2" TBG -PC, 12.6#, L -80, .0152 bpf, ID = 3.958" H 9224' I-- / \ I 9224' 1 /2" WLEG, ID = 3.958" I I 9271' I OF SAND (08/19/03) I 19-5/8" CSG, 47 #, L -80, ID = 8.681" H 9467" I , & 1 9219' H ELMD TT LOGGED 12/30/91 I PERFORATION SUMMARY REF LOG: BHCS ON 12/12/88 I ANGLE AT TOP PERF: 23 @ 9391' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn /Sqz DATE 4" 4 9391 - 9413 C 01/05/89 4" 4 9506 - 9543 C 01/05/89 4" 4 9545 - 9566 C 01/05/89 I 4" 4 9570 - 9586 C 01/05/89 4" 4 9596 - 9612 C 01/05/89 4" 4 9624 - 9640 C 01/05/89 = r - I 9642' I— (2) HES- N- 15RP -RK (LOST 01/22/94) IBP RUBBER ELEMENTS (08/19/03) mir- = 9642' —I HES- 02- 2ORC -RK (LOST 01/21/94) I I PBTD I- 9802' SIM 17" LNR, 29#, 1-80, 0.0371 bpf, ID = 6.184" H 9848' Y. • • •v. A A v DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 12115/88 ORIGINAL COMPLETION 11/14/10 MBIWPJC GLV C/O- BROKEN LATCH (11/01/ 0) WELL: 14-39 01/08189 LAST WORKOVER 11/16/10 RRD/PJC TBG PUNCH (11/13/10) PERMIT No :1881380 10/16/08 OOB /PJC GLV CORRECTION 11/24/10 DM1S /PJB P&A {11/20/10) API No: 50 -029- 21888 -00 11/20/08 CJN/Tt,H FISH/GLV C/0 (10/22 &10/27/08) SEC 9, T1014, R14E, 2759.62' FEL & 5202.77 FNL 11/22/08 /TLH GLV & SSSV DEPTH CORRECT_ 12/12/08 GJF /SV GLV CIO (12/05/08) BP Exploration (Alaska) I 1 \ Enter /Exit 2 }• 2 45' ►I \ / - - - -- I • 41 I I ,31 I / / I I I I II I I I 1 , 32 1 I I 43 ( I l I'/ I J •33 I // If I ■34 / Q I I A 3 1 410 . \,.... } -) I / E / 4' ,4., /�'a ° I (V __J ( ) 0 0� I I 1 l 1 I 1 rr "- .../ ( I I 18■ i �_ =1 I r -- 290' I I A1 1 I is • I I i 1 • 23 1 • 2 0 20 • 14 24 ' , 3 19 • I I 13 A I A 25 1 ( • 4 f I 18 • I I 12 • 1 I � 4 1 1 • I 1 26 • ___1 ■6 /� �. 1i I .7 � /r- I I �! 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Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Lau, John, Jack [mailto:Jack.Lau @bp.com] Sent: Tuesday, January 04, 2011 4:26 PM To: Schwartz, Guy L (DOA) Subject: RE: DS 14 -39 Suspend work (PTD 188 -138) MANNED Guy JAN ] 2 2011 On 11/26/10 Slickline tagged TOC at 4852'SLM with 2.50" S- Bailer. Let me know if you need anything else. Jack From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 04, 2011 3:51 PM To: Lau, John, Jack Subject: DS 14 -39 Suspend work (PTD 188 -138) Jack, In reviewing the 407 report I didn't see where it mentioned SL tagging the TOC? 1 assume they did as they were rigged up on the well doing a pressure test on the cement. Can you verify it was tagged and at what depth ?? Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/4/2011 • STATE OF ALASKA ALASKA OILLD GAS CONSERVATION COMMISS WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 -4 Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/20/2010 188 - 138 310 - 248 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 11/25/1988 50 - 029 - 21888 - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/13/1988 PBU 14 -39 2539' FNL, 1599' FEL, SEC. 09, T1ON, R14E, UM KB above MSL): 15. Field / Pool(s): To of Productive Horizon: 8. (fta o e 74 Top 171' FSL, 2606' FWL, SEC. 09, T1ON, R14E, UM GL (ft above MSL): 42.3' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 74' FSL, 2520' FWL, SEC. 09, T1ON, R14E, UM 5000' 4820' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 674907 y- 5937793 Zone ASP4 9850 9252' ADL028312 TPI: x - 673898 y- 5935200 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 673814 y- 5935101 Zone- ASP4 1991' 1991' 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIL / GR / CAL, GR / RFT, DIL / BHCS / GR / SP, CNL / Z -DEN / GR / CAL, CCT, CET / CBT 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP I BOTTOM ToP ` BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 110' Surface 110' _ 30" 2150# Poleset 13 -3/8" 72# / 68# L - 80 / K - 55 Surface 3612' Surface 3538' 17-1/2" 2000 sx CS III. 600 sx Class 'G' Too iob w / 250 sx CS I 9 -5/8" 47# L -80 Surface 9467' Surface 8895' 12 -1/4" 600 sx Class 'G' 7" 29# L -80 9155' 9848' 8608' . 9250' , 8 -1/2" 325 sx Class 'G' 24. Open to production or injection? El Yes ❑ No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): None 4 -1/2 ", 12.6#, L80 9224' 9100' MD TVD MD TVD 26. ACID, FRACTURE, SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9011' - 9032' Tubing Punch 5000' P &A 279.5 Bbls Class 'G' ✓ _ /.y.lt 7- r3 'f SZ'SLM 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes C No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. RECEIVED None DEC 2 1 2010 RBD S DEC 2 2 0 7 Alaska nil RI gal C Copv s ion Form 10-407 Revised 12/2009 CONTINQON REVERSE A n chora ge Submit Original Only . (44, r /" G 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well Tested? ❑ Y No Permafrost Top If yes, list intervals and fo n s tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 9495' 8921' None HOT 9640' 9056' OWC 9692' 9104' Formation at Total Depth (Name): Sadlerochit 9850' 9252' 31. List of Attachments: Summary of Well work and a Well Schematic Diagram. 32. I hereby certify hat the f eg ing is true and correct to the best of my knowledge. n Signed: Title: Wells Engineer Date: ') /2 r /AD P 1 - 188 -138 310 -248 Prepared By Name/Number Joesph Latstufka Well Number Permit No. / Approval No. Drilling Engineer: Jack Lau, Wells Engineer, 564 -5102 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. 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 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • 'TREE= FMC GEN 4 VVELLHEAD = FMC • SAFETY OS: ACTUATOR = AXELSON 1 439 - 1 KB. ELEV = 74' BF. ELEV = - Max Angle = 26 rir 6100' - Datum MD = 1 1991' H4-1/2 A VA TRSV SSSV NIP, ID = 3.812" I ril GAS LIFT MANDRELS Datum WO = ago SS1 STI MD WO DB/ TYPE VLV ILATCH PORT DATE 1 3198 3158 23 MV1G DWI RK 0 10/27/08 113-3/8 CSG, 68#, K-55 / 72#, L-80, ID = 12.347“ H 3612' IA ilk 2 4742 4579 22 FitTAG *DMY RK 0 3 5576 5354 24 WAG *DMY RK 16 10127108 4 6700 6370 26 MVIG *DIVIY RK 0 10/27/08 I TOP OF CEMENT -TBG H - 5000 ----•■■■ 4 • • • • kw* ••••,•,•,•,•„,„ "41. 5 7488 7083 25 1VIVIG *DMY RK 0 I TOP OF CEMENT -CSG 1-1 - 5049 v......4.0 6 8022 7566 25 IVAAG • DIVIY RK 0 12/05108 • 7 8137 7671 24 WAG *DIVIY RI( 0 10/27/08 " sssvi e.• 8 8838 8316 22 liAvIG *DMY *NO 0 .t v******4•.• 9 I'VliA * * I69 TUBING PUNCH (11/13/10) I 9011' - 9032' •• 8990 8456 23 G ED MTV NO 0 11/01/10 ••••-•• • 1 I k. •,•,w ,,, • • •••• g '■ STA #8 - LATCH BROKEN OFF VALVE (10128/08) ,•,•,•,•,•,•4• - • 7 • - • - • - • - •^0 • STA # 9 - LATCH BROKE OFF VALVE (11/01/10) •,• ,•,•,•,•,4 ,•, • G * 9100' J L M S #2 - #8 BHIND CEMENTED Minimum ID = 3.725" @ 9213' ••••••••••••••• ,......... 4-1/2" OTIS XN NIPPLE ''''.#•••••••••■1: • • • • - X 4-1/2" BKR DB PKR, ID = 7 1 •••• .•,, ,,,••••te• 1 9149' H FISH: 1/8 X 1,375" WASHER (10/27/08) 1 ■ TOP OF 7" LNR 9150' -14-112' WRP PLUG (05/19/08) I 1-1_2113 -.IN- • • I 9213' H 4-1/2" 0116 XN NIP, ID = 3.725 1 9223' H4-1/2" BKR SHEA ROUT SUB 1 14-1/7 TBG-PC, 12.6#, L-80..0152 bpf, ID = 3.958" H 9224' I / \ 1 9224 .. H4-112 WLEG ' = ID 3.958 " - 3.958" I 1 9271' H TOP OF SAND (08/19/03) 1 19-5/8" CSG, 47#, L-80, ID = 8.681" H 0467' I A ■ 1 9219' H ELMO rr LOGGED 12/30/91 1 11■11.. PERFORATION SUMMARY REF LOG: BHCS ON 12/12/88 I ANGLEAT TOP PERE: 23 @ 9391' Note. Refer to Production DB for historical perf data SEE SPF INTERVAL OpnISqz DATE .1 4" 4 9391 - 9413 C 01/05/89 4" 4 9506 - 9543 C 01/05/89 4" 4 9545 - 9566 C 01/05/89 1 4" 4 9570 - 9586 C 01/05/89 4" 4 9596 - 9612 C 01/05/89 4" 4 9624 - 9640 C 01/05/89 .- 1 9642' I (2) HES-N-1 5RP-RK (LOST 01/22/94) -, — - --- -. 113P RUBBER ELEMENTS (08/19/03) ; = --------; 9642' HES-02-20 RC-RK (LOST 01/21/94) PBTD - 9802' I INNI 444..441 0.0.0.0 17" LNR, 29#, L-80, 0.0371 IV, ID = 6.184" I - I 9848' DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 12/15/88 ORIGINAL COMPLETION 11/14/10 MBM/PJC GLV C/0- BROKEN LATCH (11/01/ 0) WELL: 14-39 01/00109 LAST WORKOVER 11/16/10 RRD/R1C . TBG PUNCH (11/13/10) PERMIT No: ri 881380 10/16/08 0013/RIC GLV CORRECTION 11/24/10 DMS/PJB P&A (11/20/10) API No: 50-029-21888-00 11/20/08 C.INTILH FISI-t/GLV C/0 (10/22 &10/27/08) SEC 9, T1ON, RI4E, 2759.62 FEL & 5202.77 FNL 11/22/08 /11H GLV & SSSV DEPTH CORRECT , 12/12/08 GJF/SV 1GLV C/O (12/05/08) RP Exploration (Alaska) I . 1 • • 14 -39, Well History Date Summary 07/13/10 T /I /0= 20/500/350. Temp= SI. T, IA, OA FL's (pre -P &A- requested by WDE). AL spool piece dropped. TBG FL near surface, IA & OA FL's @ surface. SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. 07/28/10 T /I /O = SSV/480/390. Temp = SI. Eval for sombrero (pre P &A). AL spool dropped. Integral installed on OA companion. Cellar has metal grating. 20" conductor is either sealed or cemented (there is a metal ring but some cement on top @ 6:00 and 9:00). Gravel is level with top of conductor except where it appears to have subsided around well 12 -18" out and 18" deep. One circ port is visible @ 9:00, it has a 1502 cap on it. Will need to excavate to install containment. SV, WV, SSV = C. MV = 0. IA, OA = OTG. NOVP. 08/08/10 T /I /0= SSV /400/300. Temp= SI. Remove gravel from cellar, install containment (pre P &A). AL spool piece dropped. Integral installed on OA. Removed floor kit from wellhouse. Removed 3 yds of contaminated gravel from cellar to expose circ -ports w/ 4" bull plugs installed.. Installed 20" secondary containment in cellar. Installed floor kit in wellhouse. FWHPs= SSV /400/300. ** *Job complete * ** SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 09/07/10 T /I /O =SSV /300/440. Temp =SI. WHPs (remove yellow spill liner.). Removed Liner from around conductor. SV,WV,SSV =C MV =0 IA,OA =OTG NOVP. 10/23/10 T /I /O= SSV/380/120. Temp= SI. WHPs (Eval spray in liner). AL spool piece dropped. Integral flange installed on OA. Cellar has new spray in liner installed, w /no holes or tears. Cellar is clean and dry. SV, WV, SSV= C. MV= 0. IA, OA= OTG. NOVP. 10/31/10 ** *WELL SHUT IN ON ARRIVAL * ** (pre p &a) RAN 3.85" CENT, FLAPPER CHECKER TO CHECK AVA TRSV SSSV @ 1,966' SLM (1,991' MD) (good function test) TAGGED TOP OF WRP @ 9,181' SLM WITH 2.5" LIB. (lib shows impression of the wrp shear stud) SET 4 1/2" WHIDDON CATCHER SUB @ 9,181' SLM. * ** *JOB STILL IN PROGRESS, WSR CONTINUED ON 11/1/2010 * * ** 11/01/10 ** *WSR CONTINUED FROM 10/31/2010 * ** (pre p &a) MADE AN ATTEMPT TO PULL RKP VAVLE FROM STA 9 @ 8,968' SLM (8,990' MD), LATCH BROKE OFF OF VALVE PULLED 4 1/2" WHIDDON CATCHER SUB FROM 9,181' SLM. (recovered a wobble ring from broken latch - spring from latch still in hole) * ** *LEFT WELL SHUT -IN, SSV LEFT DUMPED AND NORMALED UP TO THE PANEL - NOTIFIED PAD OP * * ** 11/13/10 ** *WELL SHUT -IN ON ARRIVAL * * *(E -LINE TUBING - PUNCH) INITIAL T /I /0= 1100/400/250 PERFORATED TUBING WITH 4 SPF 0 DEG PHASING 20 DM 1.56" TUBING PUNCHER OVER 9011' TO 9032'. CCL TO TOP SHOT = 5.7', CCL STOP DEPTH = 9005.7'. LRS PUMPED 3.7 BBLS DIESEL ON TUBING, BROUGHT TUBING PRESSURE UP FROM 500 TO 1400 PSI. IA TRACKED FROM 400 TO 1300 PSI IMMEDIATLEY, INDICATING CLEAR COMMUNICATION. FINAL VALVES: WING CLOSED, SSV CLOSED, SWAB CLOSED, MASTER OPEN. RDMO AND HANDOVER TO DSO. ** *JOB COMPLETED * ** 11/13/10 T /I /0= 500/400/235 Temp =SI Assist E -line, Injectivity test ( P &A wellbore) Pumped 3.7 bbls of 30* diesel down TBG to confirm communication with IA T /I /0= 1400/1300/370 Bleed well head psi down bleed back aprox 2 bbls Perform injectivity test- Pumped 5 bbls diesel to pressure up tubing. Pumped 12 bbls crude in 66 minutes, approx .18 bpm, down tubing to verify injectivity Monitor WHP's while pressures fall off. * *Swab, Wing, SSV= closed, Master, IA, OA = open on departure ** FWHP's= 550/500/50 Page 1 of 3 1 • 14 -39, Well History Date Summary 11/13/10 T /I /O = 500/450/260. Temp = SI. Assist E -line. (Cellar watch). Flow line is blinded. AL spool dropped. Conductor is sealed w/ circ ports CO 3 & 9 O'clock positions. Circ port @ 3 O'clock position has a bull plug & Circ port @ 9 O'clock has a 1502 connection and cap. Monitored OAP, conductor pressure & cellar during / after Tubing punch for returns / pressure changes. * *Night shift * *. Change out with days. Monitored conductor and cellar while LRS performed injectivity test. No leak activity observed. ***See log for details. FWHPs = 550/500/50. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 11/15/10 Injectivity test. Job Postponed due to weather. 11/19/10 T /I /O = 1240/120/0 psi. Temp =SI Injectivity test to prove 5 BPM circulation TBG x IA. Pump 5 bbls 60/40 Methanol followed by 40 bbls Crude down TBG and return from IA to open top tank. Pump 5 bbls 60/40 Methanol followed by 40 bbls Crude down IA and return from TBG to open top tank. FWHP's = 0/0/0 psi. SV,WV,SSV =C MV,SSSV =O IA,OA =OTG 11/19/10 T /I /O = 5/470/5. Temp = SI. Assist FB during Circ out (Cellar watch). AL is disconnected. 2" hardline rigged up to TBG, IA & OA. Sealed conductor @ 0 psi. Assist LRS, monitored OA & sealed conductor during Circ out. No fluid returns to surface. OAP & sealed conductor pressure where unchanged during Circ out. FWHP's = Vac/Vac /5. Job Complete. LRS in control of well on departure. 11/20/10 T /I /O = 400/400/0. Temp =SI. Assist FB during Circ out (Cellar Watch). AL spool is dropped. Assisted FB & SLB during Circ out and Cement P &A on cellar watch. Final WHPs = 0/120/0. SLB has control of valves. 11/20/10 T /I /O = 500/360/0 Assist Schlumberger Cement. (P &A Wellbore) Pumped into the Tbg with a 5 bbl neat methanol spear. Shut down, standby for SLB to pump 9.8 ppg NaCI Brine. Pumped 20 bbls of 80* F Diesel. Shut down, standby for SLB to pump. Pumped and additional 7.3 bbls of 80* F diesel. Final W H P's = 1000/1000/0 Schlumberger pump truck on well at the time of departure 11/20/10 ** *SLB Fullbore Cement Crew * ** Job Scope: P & A w/ 15.8 ppg Class G Cement. MIRU, Pump circ schedule: 5 bbls Meth spear, 15 bbls 9.8 Brine, 20 bbls Diesel, 200 bbls of inhibited 9.8 brine CO 6.6 bpm sweep down TBG up IA. Confirm returns 1/1 during circulation with return MM and visual on return tanks. Pump cement schedule: 59 bbls of inhibited 9.8 brine, 5 bbls of fresh water, 279.5 bbls of 15.8 ppg class G cement, 2 bbls of fresh water, launched foam wiper, 5 bbls of fresh water, 61.7 bbls of inhibited 9.8 brine, 7.3 bbls of diesel. Secure well. 4 1/2" Tubing 4 1/2" x 9 5/8" IA Surface 7.3 bbls of diesel Surface 12 bbls of diesel 460' 61.7 bbls of inhibited brine 223' 254 bbls of inhibited brine 4540' 7 bbls of fresh water, 4967' 5 bbls of fresh water 5000' -9050' 63.2 bbls of cement 5060' -9100' 216.3 bbls of cement, ** *Job Complete * ** 11/25/10 ** *WELL SHUT IN ON ARRIVAL ** *(post p &a) RIG UP SWCP 4518, CURRENTLY STANDING BY FOR TRI -PLEX. * * *CONT WSR ON 11/26/10 * ** 11/26/10 T/I/0 = 300/0/0. MIT -T to 3000 psi, PASSED. MIT -IA to 3000 psi, FAILED. CMIT -T x IA to 3000 psi, PASSED. (P & A). Pressured up TBG to 3000 psi with 1.7 bbls Crude. TBG lost 200 psi in the 1st 15 min and 60 psi in the 2nd 15 min. Bled tubing pressure to 580 psi. RU to IA. Pressured up IA to 3000 psi with 5.5 bbls Crude. IA lost 400 psi in 15 min. Re- pressured IA to 3000 psi with 0.5 bbls of crude. IA lost 180 psi in the 1st 15 min and 160 psi in the 2nd 15 min. (Tubing pressure increasing each time IA pressure is increased). Pressured up TBG x IA to 3000 psi with .3 bbl Crude. TBG /IA lost 20/60 psi in the 1st 15 min and 10/20 psi in the 2nd 15 min. Bled back tubing and IA pressures. SLB in control of well at departure. FWHP's = 140/100/0 psi. Page 2 of 3 • 14 -39, Well History Date Summary * 11/26/10 CONT WSR FROM 11/25/10 * ** (post p &a) RAN 2.50" S- BAILER TO TOC AT 4,852'SLM. LRS PERFORM PASSING MIT -T TO 3000 PSI. LRS PERFORM MIT -IA TO 3000 #(failed tbg tracked with ia) LRS PERFORM CMIT -T x IA TO 3000 #(passed) ** *WELL LEFT SHUT IN, DSO WALK THROUGH UPON DEPARTURE * ** Page 3 of 3 • • Jack Lau ~ J, ~ ~g Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 14-39 Sundry Number: 310-248 ,~,;, Dear Mr. Lau: ~~ ?' ~ ~=~'`~4 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. -~ Sincerely, ~~~ Daniel T. Seamount, Jr. Chair DATED this ? day of August, 2010. Encl. STATE OF ALASKA ALAS AND GAS CONSERVATION COMMISSI~ ~,~3~}~-PPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ~ ,~.~~ ~~i gti 8~ $' 1. Type of Request: Abandon ~_ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend [/~ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operation Shutdown ^ Re-enter Susp. Well ^ Stimulate^ Alter Casing ^ Other' - ~ ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ~_~7`-~v BP Exploration (Alaska), Inc. Development ^_ Exploratory ^ 188-1380 3. Address: P.O. Box 196612 Stratigraphic ^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21888-00-00- 7. If pertorating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^ PBU 14-39 - 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO-028312 _ PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 9850 - 9251.91 - 9271 8715 9150 9149 9642 Casing Length Size MD ND Burst Collapse Structural Conductor 80 20"91.5# H-40 36 116 36 116 1490 470 Surtace 20 13-3/8"68# K-55 35 55 35 55 3450 1950 Intermediate 3557 13-3/8" 72# L-80 55 3612 55 3538 4930 2670 Production 9433 9-5/8" 47# L-80 34 9467 34 8895 6870 4760 Liner 595 7"29# L-80 9153 9748 8606 9157 8160 7020 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# L-80 33 9224 Packers and SSSV Tvoe: 4-1/2" AVA TRSV SSSV Packers and SSSV MD and ND fftl: 1997 1997 4-1/2" Baker Model D Packer 9100 8558 12. Attachments: Description Summary of Proposal ^/ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q - Service ^ 8: 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/25!2010 Oil ^ Gas ^ WDSPL ^ Suspended 16. Verbal Approval: Date: WINJ ^ GINJ ^ WAG ^ Abandoned _~ Commission Representative: GSTOR ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact JACK LAU Printed Name JACK LAU Title WELLS ENGINEER Signat re Phone / Date 564-5102 c/ 8/11/2010 Prepared by Gary Preble 564-4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~, ~ '"~ Plug Integrity ~ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ -°°~ A-'a n ~~~ L~ Other: j,''I ~'n ~t- C~.s~s._2 ti~i`' ~ /,,,~ /~ (4-c~'~•~ ~~rbc~~y V , .. ,.~ :~ ~~ ~3 ~~-~. c~nnoss~ Subsequent Form Require: lD-YD -,,a~;a~~f1~8 APPROVED BY ' ~ Approved by , j COMMISSIONER THE COMMISSION Date: ~ ~--! RBDMS AUG ~~ ~1 ~.. O R I G I N A L ~- X77 ~° Form 10-403 Revised 1/2010 ~ ~~ ~/O Submit in Duplicate i3,1~ 14-39 188-138 PERF ATT~4CHMENT u Sw Name Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base Operation Date 14-39 PER 9,391. 9,413. 8,825.13 8,845.42 1/5/89 14-39 PER 9,506. 9,543. 8,931.44 8,965.78 1/5/89 14-39 PER 9,545. 9,566. 8,967.63 8,987.13 1/5/89 14-39 PER 9,570. 9,586. 8,990.85 9,005.71 1/5/89 14-39 PER 9,596. 9,612. 9,015.01 9,029.89 115/89 14-39 PER 9,624. 9,640. 9,041.05 9,055.94 1/5/89 14-39 SPS 9,271. 9,640. 8,714.67 9,055.94 8/20/03 14-39 BPS 9,120. 9,391. 8,576.08 8,825.13 5/19/08 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~~ 14-39 Secure ~~~~~ ~- ~r August 11, 2010 To: J. Bixby / R. Liddelow - Wireline Operations Team Lead C. Olsen / T. Norene -Well Services Operations Team Lead From:Jack Lau, Wells Engineer Dan Kara, Wells ETL Subject: 1439 P&A Est. Cost: $200M AFE: APBD14WL39 Please perform the attached P&A procedure on Not Operable well 1439: 1 D Install Cellar Liner 2 S D&T. Pull GLV#9. 3 F P&A 4 F MITT to 3000 psi. 5 S D&T (obtain sample) Current Status: Shut In Not-Operable Gas Lifted Producer -Secured-with WRP at 9150'. Ann Comm Status: TxIA, PC leak, IAxOA, SC leak Integrity: Not Operable due to TxIA, PC leak, SC leak .Deviation: 26° at 6100 MD Minimum ID: 3.725" thru XN Nip at 9213'. 3.813" thru SSSV nip at 1991' Last Downhole Op: 06/11/09: LDL found PC leak at 5483' Latest H2S value: 14 ppm 12/11/92 BHP/BHT: 12/04/93: 3612 psi/ 228°F at 8800' TVDss 10-403 Required OBJECTIVE: The objective of this well intervention is to P&A this wellbore .with 1000' of .cement above all permeable hydrocarbon containing zones, in this case 1500' of cement will be placed above the production packer in both the tubing and inner annulus. This will be Page 1 of 16 /~~d~Rf- ~:.ts Tl~i C.~ro(~'~:/9 v~ 7~~ . 14-39 Secure accomplished by pulling GLV from Sta#9 and circulating cement down the tubing and up the IA. SUMMARY OF COMMUNICATION: TxIA: The source of TxIA communication is unknown, but all indications point to a one way leak, IA ~ T. First indication of TxIA Comm was observed by coil during a hydrate cleanout/sand plug in Aug-03. The Tubing pressure did not track the IA while being brought up to test pressure during aCMIT-TxIA on 12/28/07. On 12/25/08 a MITT passed to 2500 psi indicating no communication from tubing to IA. Subsequently the tubing very slowly tracked the IA while pressuring up the IA for a CMIT. While establishing a LLR down the IA on 02/28/09 again the tubing slowly tracked the IA. The TecWel LDL ran in June-09 failed to identify TxIA comm while pressuring up the IA. PC Leak: The source of IA repressurization is a PC leak at 5483'. A TecWel LDL ran on E-Line in June-09 identified a 9-5/8" PC leak at 5483'. The LLR into the PC leak is relatively small being ~7.7 gpm at 2500 psi. SC Leak: Shallow surface casing resulted in fluid leak in cellar on 06/17/94. Subsequent LDL Temp/noise log suggests SC leak is at 81' (not 100% conclusive). Surface casing leak verified by circulating N2 freely down 13-3/8" and up 20" seeing immediate returns. Attempted to repair SC leak with four OA cement down squeezes on 10/24/94, 10/31/94, 11/6/94, and 11/27/94. MITOA post OA sown squeezes failed to 1000 psi on 12/04/94. Noted that cellar was bubbling on 2/22/97. Need DHD & vac on location during pumping operations. IAxOA: TIO plot history indicates a trend of very slow IAxOA in this well. No pressure communication from IA to OA has been observed using pressure testing of the inner annulus; reference CMIT-TxIA's on 02/28/09 and 12/25/08. It is likely that the IAxOA communication is to gas only. SUMMARY OF PRIMARY CEMENT: The 14-39 Cement Bond Log (CBT) and Cement Evaluation Log (CET) have been reviewed by both BP and Schlumberger engineers. The resultant interpretation indicates there is more than 1000' of cement behind the 9-5/8"above the production packer. Detailed CBT & CET Interpretation Page 2 of 16 14-39 Secure • Cement quality in the 7" section is very good from the bottom of the liner lap to TD. • Cement quality in the 7" liner lap is not definable due to tool limitations as sonic cement bond log tools are not reliable when ran in concentric pipe strings. • Cement quality in the 9-5/8" section is also very good, with cement bonded to the pipe and formation from 7996' to the top of the 7" casing at 9165'. • Estimated TOC behind 9-5/8" casing is 7895'. • There is a micro annulus present in the 9-5/8" to cement interface which is gradually removed by applying increasing surface pressures. • The cement density track of the CET tool seems to be indicating a channeling effect on the low side of the hole throughout the 9-5/8" section. This does not agree with the CBT tool measurement which shows virtually no casing arrivals. A probable cause for this CET channeling response is tool eccentralization. o The 9-5/8" section was logged during the same pass as the 7" section.. The tool string was configured to be ideally centralized in the 7" section and was only well centralized in the 7" section. o A wandering transit time baseline in the 9-5/8" pipe is another indication of tool eccentralization. WELLWORK HISTORY • 06/11/09 - TecWel LDL identified PC leak @5483'. No tubing leak. • 04/12/09 - SL tagged WRP at 9183'SLM with 2" LIB, 2.5" Cent. Clean picture of WRP fishing neck. This SL tag is deeper than expected seeing the WRP was set at 9150'MD. • 02/28/09 -CMIT-TxIA Failed. LLR 7.7 gpm @ 2500 psi, tubing pressure response when pumping on IA. Could be thermal & compression of tubing. No pressure communication observed between IA and OA. • 12/25/08 -MITT Passed to 2500 psi. CMIT-TxIA failed. Tubing pressure response when pumping into IA. • 12/05/08 - DGLV's. Pulled flow sleeve and set DGLV. All DGLV's with 1 equalizing valve. • 11/26/08 - Circ'd well to 1 %KCI • 10/27/08 -Fish left in hole: Round overshot washer (Dimensions= 1/8" Thick x 1.375" OD). • 05/30/08: CMIT-TxIA Failed. LLR 0.10 bpm ~ 1000 psi. Page 3 of 16 14-39 Secure • 05/19/08: Pulled XX Plug, Set WRP at 9150'MD • 01/03/08: Failed CMIT-TxIA. No OA response to IA pressure. • 12/26/07: Caliper indicated tubing in good condition. 223 jts < 20%; 11 jts 20- 26% • 08/19/07: CT secured with sand plug. SL bailed latex on top of sand at 9217' SLM. • 02/22/97: Cellar bubbling & has 10" water. • 12/04/94: MITOA failed 1000 psi. • 06/17/94: Surface casing failed, IBP set ~ 9360'. BASIC PROGRAM PHASES • DHD to install cellar liner. • SL to pull GLV from Sta#9 at 8990'. • FB to circulate cement down the tubing and into the IA, securing the well with 1500' of cement in each. • FP IA by bull heading 5 bbls of diesel. Communication path is out the PC leak. • Perform MITT. • SL to D&T TOC. RISK DISCUSSION: • Well control plans and a task hazard assessment should be in place in the event of a well control problem. Review well control basics and ensure sufficient kill fluids are available on location at all times during all pumping phases of this work. Review well control plan at each shift change. In the unlikely event of a well control situation the most probable scenario is that a barrier is lost and the surface casing can't contain reservoir pressure. Rig up equipment so that in the event of a well control situation the following general steps, at a minimum, can be executed: o Pump down the production tubing, taking returns up the IA until the IA is liquid packed and dead. o Continue pumping down the tubing while taking returns from the OA until the OA is liquid packed and dead, if conditions warrant. Page 4 of 16 . 14-39 Secure • Note: 13 3/8" 68# K-55 3450 psi burst -Arrange for DHD to be on location during all pumping operations to monitor and bleed pressure from the 13-3/8" surface casing. • To mitigate the severity of spills from the active SC leak, DHD and a vac truck are to be on location during all pumping operations. To control over pressuring the OA, mitigate IAxOA flow, and to enable pumping down the OA, an open top return tank and inline choke will be rigged up to the OA. DHD will monitor OA pressure and maintain open bleed. • 26-Dec-07 caliper indicates minimal corrosion in the tubing tail between the packer and WRP. This section of the tubing is the only section not reinforced by the pressure on the IA, but considering the reservoir pressure and mechanical condition of the tubing it is within operating limits for this job. • Subsidence reported on the DHD WSR from 7/28/2010. • Gamma Ray log interpretation indicates there are no permeable zones within the proposed cement depths of 8990'MD to 7632'MD. All Ivashak permeable sands are below the target cement depths. WELL INTEGRITY HISTORY: ^ 6/17/94: Surface casing failed (cellar blowout). IBP set at 9360'. ^ 6/19/94: LDL w/ N2 suggests SC leak is shallow (likely above 80'). Circulated N2 freely down 13-3/8" and up 20" w/ immediate returns. ^ 10-11/94: Pumped 4 OA down squeezes ^ 12/4/94: MIT-OA failed to 1000 psi ^ 12/29/94: Packoff sealant treatment ^ 12/31/94: MIT-OA failed ^ 1/23/95: CMIT passed to 2500 psi ^ 2/21 /95: A/L circ test showed gas on OA ^ 2/28/95: After add'I sealant, well still communicates AL to OA. MIT-OA failed indicating flow from OA to formation or atmosphere. ^ 2/22/97: Cellar bubbling & has 10" water ^ 5/27/97: OA stable at 580 psi ^ 6/20/98: OA stable at 0 psi ^ 12/12/00: TIFL failed; check IBP integrity ^ . 12/28/00: CMIT-TxIA failed; LLR (T-CIA) 2.2 BPM ~ 850 psi ^ 7/5/03: DSO called in high OAP ^ 8/18/03: Ice cleanout, pull IBP, TxIA noted ^ 8/19/03: CT sandback to 9271' CTMD w/ latex cap ^ 5/1 /06: DSO reports OA pressure is not stable Page 5 of 16 14-39 Secure ^ 5/2/06: OA FL at surface ^ 12/26/07: Caliper 4-1/2": 223 jts<20%, 11 jts 20-26% ^ 12/27/07: Set TTP at 9213' MD; attempted CMIT-TxIA, but blind between wing valve and S-riser started leaking gas ^ 1/3/08: CMIT-TxIA failed to 3000 psi; LLR too small to determine w/ LRS ^ 5/19/08: Pulled TTP, set WRP at 9150' MD. WRP setting tool and firing head didn't shear. ^ 5/24/08: Fished e-fire and setting tool. Attempted CMIT-TxIA, but TIO all tracking. Bled IAP/OAP and RDMO. ^ 5/30/08: CMIT-TxIA failed (held open bleed on OA during test); LLR (T~IA) 0.10 bpm at 3000 psi ^ 10/21/08: Several days of GLV work pre-circ out for secure diagnostics; set flow sleeve in GLM #6 for deepest circ out possible. ^ 11/30/08: Circ out to 1 % KCI; bleed WHPs to 0 psi ^ 12/5/08: Reset GLV #6 post-circ out ^ 12/25/08: MIT-T passed to 2500 psi. CMIT-TxIA failed to 2500 psi; LLR too small to determine w/ LRS. Bled OAP to o psi. ^ 2/28/09: CMIT-TxIA failed; LLR (IA->PC leak) ~7.7 gpm Contact Jack Lau at 564-5102 (W), 227-2760 (C), or Josh Allely at 350-7362(C), or Danny Kara at 564-5667 (W ), 240-8047 (C), with any questions or comments. CC: Well File Page 6 of 16 14-39 Secure Page7of16 14-39 Secure Cement Systems.... Volume. ®f Cement is Pumpable 102 bbfs _ ~ he [ ~ L~ ~ __ ..-,_., ~~~~ b era Sty a itaEd `f a Vol ~ 9.$ inhibited Naci 50 M 2 15.8 Class G Cement 100 ~ 3 Fresh Water S aces 7- MAX 4 9.8 `Inhibited NaCI 106 MAX 5 Diesel 3 1 9. MIFiU SLB Cementing Services. 10. Order out necessary fluids including a contingent upright of 1 % KCI for kill fluid 11. Fullbore cement downtubing and into IA following the pump schedule above. Max pump pressure of 2500 psi. 12.Come online with 50 bbls of 9.8 ppg NaCI pumping down tubing through tho side outlet piping at max rate at 2500 psi, which ever is camas first. 13. Immediately follow with 100 b'bls of 15.8 ppg class G cement at max rate. Request Schlum'berger to minimize "tail-off" and get a clean break between cement and water. • Two 55 bbl cement batch mixers.: will be required to mix 100 bbls of pumpable cement. ; 14. Clear the lines with 2 bbls of fresh water-to ensure,no cement ends up above the ball. Stop pumping, and close the pump-in sub side outlet to-torq valve. 15.Open the workover valve, followed then by the Lo-torq valve for upper Chiksan loop in that order (so if ball get sucked, it travels down). 16. Resume pumping and displace ball into tubing with 5 bbis fresh-water through the` upper loop, 17.O:pen side outlet. Lo-torq valves but still leave top chiksan loop open. Switch to 9.S ppg NaCi and continue pumping the required displacement of 106 bbls at max rate. Note: Total displacement of cement should not exceed'116 bbls :.(displacement is 7 bbls FW + 106 bbts 9, NeCI +`3 bbls ~eisei). This shouid ` ,'lace TC?C 7.632'. Page8of16 • 14-39 Secure 18 Cap. tubing vvith 3=bbls of diesel. 19. Cap IA vvith 8 bbls of diesel, Do NOT exceed rnax dump pressu wrhile dumping into IA. The` IA is expected t® have infectivity th at 5483': Expected rates are ~0.1 bpm at 1000;psi. • 02/28/09: CMIT~TxIA failed, IA ~ PC LLR M 7;7 gpn 20. Cycle.. swab,. master, secondary swab, and, if possible from cavities.. 21. Request grease crew to ..inject 1/3 va ve cavity volume: swabs, and wing within 5 hours to prevent any_cemen crossfrom setting up. 22. Request DHD to check WHP i six hours to ensure cep expansion problems, 23. Pressure test cement by performing a MITT to 3000 P three thickening times. mastE ass into 24. M`IRU SL. D&T TIC with centralizer & sample bailer (ensure s RDMO. is obtained). Page9of16 • 14-39 Secure TFtfE fYa1C GEJV 4 Vtl~tNEAD _Fi~ ~ ~-~ SAFEfY fif7tES; A~Ti1ATdR ~m% AJ{f~S+[NJ iG@. El£V A. m- .. 74' 8F. F1E'J s KUP ~ '~~ ~4ax~Angfe x 26 Bit76" ~~y' a-i!2 AVA Tf~.s"'V SSSV t+d~'. ~I~ 3 911" Datum b~7 =. 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U~ 1 ~ "' ~ ~' €~. ~`{ 5 r~~a l/ ~ ~~ `~~ ~ " . ~ ~.~ ~, a A ~~~_ ~ ~~ ~ ~~~ ' c ~as~.__ . ~` ~~ ~t.~.-.._._ ~. ~ ,t3 tJt~,~ _ ~, S 7 `~ t' Vii' `~~ -~ ~.,aQn....-L..~f- F~ ~-[~~~.L~I~~_G4 _.,,, ,('y~ .L FkA ~. .1=..C./ .~ 1 f+ / 1! /~~~ _ t _. . _f.~.~~,~~__....r~t~ ~ c ~ -- .~ ~. -- ~ a_~ ,r ~t rte ~ ~.~~.C 4 .fl./. ~~'1~'.. ~1~~ ~ '~ 7 ~ 5_,.,t~_~.~~.31.~.,.c~ ~ 0, ~I, 7~~ .z° C], ~ b S~ a; Y ~' `% d `I_ ~ `! 1 ~/1.31r c -, ' ~ Caw ~ ~ 7~c'~~'~ ~. ~~~~..C_~.-. _------ _ __ € ~ ~D _. _ 111.E ~'r~ _ _ / ~/ / ~ _~e A£d ~ f , / I !_, ~CC~Ir~__ _~'1P~~1~~. ~r~r~~~ ~ C~1 ~~s~ y. teS b ~ ~G~' !i~ ~ ~~~~ft~~~ ..._.._.- _ ~ . __..~_ . .r.., - _. ~C)TTC11~f QF TU8IP1Ci TAIL, Rentk~fk9 Page 12 of 16 . 14-39 Secure . WELL. ER1/ICE RE RT d'( GATE Q ! D U 4-~~ ~.~~~,~~~a'g ANN-C~.dh~ tflPEEt} SPILLER COST Ct}DEPE DAILY WORK NIGtfT ~t1PY PED144YL39-I GIN,~B~IATI{3NMECHANICALfNTEGf~ITYTE~T SAU'JAC~AL! Nf1N IQ DEPTt~ T'rL~IZE KEY PERSO!~i UNIT' 4" 0 Ft 4~ LRS-VARNER LRS 46 T14'C~~30''0 T~r~_ SI Ctt4lTTxlA FAILED t~ 25~p~i. Eytsbl~l32d a 11R of ~-,~,7 ~m (Ex~al? Pump 0.7 ~L~ d_>BSaI dcr~t t~ a~ pressor~l to ifir00 psi. Purnpfi.3 bats dlasAl dow~~n IA to rea;,h 25~ p5a. Tb~ ;ncreased to 1600 psi. 4~P }ost 128'0 psi in 15 mine to 1220 ~. TP Lost 100 psi. EMai~kshed LLR by prestiur~ IA to 2506 ~~ arxl slicwin0 pressure to decrease 304 ~i to 2200 psi over a 30 min span. F'tamp~d 5.5 ~~ in that 30 rains. Bled T & IAP toy psi. h+kanittx Par 30 min. IAP in~r~~s~d to 3D3 es. Tb+u ;~ :~A rem€toed ~nchanaed. F4L'HP ~=Q'3~'0 SV. SSV. '4'1V=5~'l t~.'['~ t7 IA, t~~~Tra. SLUG ENTRIES .-.- ~ ~.~~ _ I n it-~ fi TIME FPM _ ~BLs . FLUID TEMP ~ TBC 1:;3:30 _ __ ~ ~Y_15 .._ 1030 _ -- ~ ~ _ IA` fl i~,A ~C'~EUIMENTS _ ... _Stttrt t~: ~ t. F, U procedure ~ F'Bl~. _ Check on 4o;,ateon far aPOes~-snow drifts, etc. LoayJd~ese(. 11:43 Ml ~'JS #,A~ R U 12:40 ~ __ PT F~wline bliivJad~~O~si. 55 1 ' ' .6 0 t ~~esel i ti. ~ 34G q_ 9tartd~.vnt`t~. _ _ __ 12 :50 .8 -., - -- s __ *'-"'.' 1100 _ _ ~ 340 _ 0 S D. - ~ 13:02 ~~ 110(J .__ 3 ~.~.~_ #i _ ~ FAD. R~ 4~ 1~4. 13:15. PT. 13:25 5 iTst cisesei 15` 1100 950 0 Start dc~°n {A. 13 :27 ' .5 1 11$0 544 0 13:29 .5 2 120f) 14D0' 0 13:32. .3 3.3 1260 1500 0 13:37 .3 4 ~ ~ 1360 20~ 0 13:.39 2 5 ~ 1400 2104 0 13:40 .3 5.4 1440 2200 0 13:42 .3 5.7 1500 23011 0 13 :43 _ 13:45 14:01 .3 .3 __ 5.9 5.3 _ 154+7 ~ iS00 ~ 15D4 2400 2500 122'(} 0 ~0 20 SD h~tinitorpr2ssares. 15 m9n. 1403 14:(}6 ._e.m-.. 14:11 ..14:12 14:13 14:151 11 ~;1 ~ j 14:1; .5 .4 -..__- .; .3 .25 - .3 . _. .3 I .2 _ 6 3 ~t 7.6 - 9.1 9.6 _ 9.8 10.3 _ 1.1 ] ~ 11,1 _ _ ~~~._ ~ ~ 150J ~ `~~1500 ~~ -.,T ~_.W.u _ ~ 1600 1630 ififi0 ', 170Ct _ ~.__. • _t 147 -'1 1?90 1200 1500 a..~, ~.. _ 2000 2100 _ 2.200 ,~. 2900 ._ 2#00 2500 2'0 20 ~~__ _, 40 4;1 40 40. ~ ~.. 6~ ~ atart~ur~ 1& ~ a:n___~_._~ ° _~ _ . SD h+kcnitar. _ _ 14 ; - _ _. ~ - ;, 15 man. call PE ~ ___: _ 1 ! 1 ~ : ~ SCSrt a~ n 4-l' 14:52 } 3 .. .1 3.4 . • ~ _ 16fi 1500. .....,,.._ 2:1 j 14:57 _~ .3 _ -- 14.i _ ~ . ~ 1750. _.- 2000 ~40 - 14:5 .4 _...15.4 -._ _... _. _ .- °- 18 00 ._.. 2200 40 15:02 _ .4 16.3 _ 1~0 25{x} SO SD. 15:05 5 16.3-~t 18fi0 2200 40 Burr. 15_U~ .4 17.5 '~ 1~0 2500 40 SD. t.2 i~ls in~3 min 15:11 .4 17.5,~st "" 1£60 22011 44 B 15:14 .4 18.E 2040 2500 &0 SD. 1.2 bills i n --3 min 15:.11 4 18.7Jst ~ ~{~20 ° 2'200 __ DO Burn. _. 15:.213 .4 19.8 _ ~ 2100 2500 60 S[3. 1.1 bbls in ~3 min 15:24 .4 14.8'st , . ; 2070 - 220f} - 60 Bitn'~. - 15:27 15:30 16:33 - .3 .5 4 -- 2~J.A 20.9'st 222 ' ____. ' 2140 _ "~ _ 2100 2160 250E} 2160 ~ 2500 60 &U_ 50 SD. 1,1 blslsin ~3 min Bump _ .SD. 1.3 bills in ~3 min. Page 13 of 16 14-39 Secure • 15:38 .5 222~st "~ ~ 2140 2200 S0~ ~ Bad. _ 15:30 _ 5 X32 210 ._ 25'v0 6~ SD 1 to r~ 3 mm 15:2 15:4£ - 15.4P 4 .3 .3 ~3 2st •'~~24 4 2~.~J~t _ _ 2120 „. " 224 - ~ • ~ • 2150 2200 ~ 2~00~ ~2D0 fi0 8~ - 6t1 Bun~~ • _ SD. 1.1 ~[s in --3~mir~ ~ __,.-_- . _. Barn . _ 15:54 '~ .2 _.25,3 _- .. mm 22ffOs _ - 2500 - - fi0 ~ ~D .8 tpt~~ 3n ~~ min, 1557 16_GCl .ii .8 2531st _26.4 "` `~ „" 214f1~ 224117 2200 25410 {r4 '~00 B:~rn~s __ SD. 1.1 bo(~ in ••3 rrcin, m~in:tar preys~r~e~ 10:30 1?$t~JJ TUL~ 40 30 m#n r~ssur~s, start bid TP 1S;4s 0 4'JO 40 SI [' bfe~ed, start b63e•3 IAP 1:52 0 ~ 0 SI 1,4 ok3ed, RDt~'~. 1~~ :3~ 0 ~ 300 ~ 44 min static rgssures 17:50 Er~t;~,kat. ~-nel-s 0 300 ~E 271ac1s diesel _ ~ _ Page 14 of 16 . 14-39 Secure • WELL SERVICE REP'aRT DATE JOB SCdPE DAY SUPV 1'' ~-~~ ~ GI ~J~I2QOS PRESSURE TEST I~tVTEGRITY} SPIELER OST CQDE PLU A WQ NIGHT SUP PBD1aWL39-1 MCT-T• MIT-fA SAUVAGEAU ~ifN lD i7EPTti TR SIZE F4EY PEFtC~+! l!N'IT {3" ' 9 FT 4 "" IAS-ZIMMERP,7AN LR5 42 {; tlU = 3UCW:i~1i3,~3t3U temp = SL h9ETT PASSED t4 2~3~ paa~ GMtT TxtA PA~E[J Kk psi (`.r`eCUfe hell} E~gd t?A to zeta. Pumped 1.8 bbls diesel into Tf~ ~ reach test pressure toT MITT. Tb~ lost 9 psi in 1st 15 mins and 20 psi in 2nd 15 rains for a total pressure loss of 20 psi in 0 mins. Loaded Ea with a fatal at 18 bbls dieset, +~ CMIT. iA pressure fell aft too fast to reaoh 2»160 p~ In Tbg (saw ~,od c~nmunicatianj. Figged up ~mper one, and pumped additianal 7.2 bbls into Tbg and to simultaneaush~. T,+tA last 18611 149 ~~!! in 1st 15 mdns and 126/640 psf in 2rxi 15 mins far a fatal pressure loss of 3041780 in 30 mins. Bled IA to 4~ psi. Re-N11T T PRS,SED to 2599 psf. Pressured up Tbg with 6~2 bbls diesel (tram 2646 psi}. T!~ lost 30 psi in 1st 15 mins and 10 psi 2r~ ~ 5 mitts a t+~t~ pre~ure c~ +t(3 psi in Sit mins. Bled Tbg to 509 psi. 'LOG ENTRIES IniY_, 300 300 300 TIME 09:OQ 6Pt~i B8'Ls FLUED TElAP TBG _ IA OA COMMEh1T8 Start Ticl~t. Load Diesel. ~ __ . 11:42 _.... ~ 11 :58 ~,,.,. _ _ _ 30ti 306 300 3 0 On lacation. Permitted. PJShA. Rig up test gauges. Start bleeding 4A ~_ ___ _ QA at Qtrs. Rid up to tubing. PT to 3009. 12.19 0.5 St Q~s 340 Start down tut~n '~ 12x26 1.8 2500 } 9 Shut drnrn. Start MITT. (Saw sNght bev~tdie ressuri up tubing, pessib~ ice r;! 12:dt 2480 326' D t5min pressures. 12'56 13.18 ~ 2480 0 ~ 320 320 ~ 6 0 ~ 30rnln pressures. Bleed dovrn. _ R~~io-wn. Rig up to lA. ~__. 13 43 . _ ~ ' PT to r 3t)OOps~, _ _._~. ..13:45 , 0.5 St ....,._ ,..,,.~,..~._. ....,,..._. t3 300 0 _ Startdawn IA. 13 55 _ _ 5.9 380 _ 2~0 0 - Shut dov, n. h4onrtar ressures. P._ 14 C ~ 6Q0 1200 0 15min presures Bump up. 14.19 ~ 10.2 146D 2300 0 Shut dtnvn. rv4anitar rass~es. 14.34 14.42 14:57 -- ~- t3 8 ~~~ 1060 _M 1320 1300 1224 2500 1304 0 -_ -_____0 0 15min pressures. Burt3p up. Shurt.dawn Mcindcrpressures 15ntin ressures. Bump up. __ 1511 1526 15:41 16.02 .5 18.0 _ St; 1600 i5_QO 13ty 0 650 25110 1~0 70fl 650 0 0 0 ______0 Shut dawn. bic~nitarprn~ssures, 15mrnpteasures. :~3min pressures. Fail. Rig upluml' ~ k~eNreen T and IA. Call PE. Jumper apen__c3nhne down tubrrij anti iA. 1b 29 0.1 ~.2i 2400 2500 ~ 0_ StartC.MIT. _ 1b ~_ 16:59 _. __ _ --~ ~ 2220 2100 1364 720 0 0 15min pressures. 34min pressures. FAIL. i;all PE. Bleed fA to . 440 si. 17:24 ...17.26. 0.5 .. St 0.2 ~" 2040 2540 406 406 0 0 Start down tubing.. __ Shut cla~rn. h~onitar ressure. 17:a1 2470 380 0 15min ressures. 17_56 _.. ,..2460,. ___380 0 34min.pressures PASS Cail PE. 18:1}0 24170 380 0 Bleed tub#n to ~. Monitor pressures. 18`x4 ~ 5{30 350 ___. _ 0 Monitorptessures. _ _ _ 1$:44 520 380 1? ~ .,..:19-36.... . 520 ~_ ..3f30 C _. ,.~ ' 21 ~01 21:49 520 380 4 Start riggin~g_down Han t s, varl all vatdes in ca~rect i~an 21:59. End t~ket Final-> 520 3t39' 0 Page 15 of 16 . 14-39 Secure • WELL PAJMBE R GAS LIFT VALVE PULLINGPRUNPIIPJG REF~(7RT 1439 VALVE 3lZE 1.5 .~ VALVES TO PCFLL FIPkIL DEStQW ao DATEP'UI.LED 1'~/& DATESE7 12 PORT V/U_VE PORT ~~ t~AD NQ VALVE TYPE $12E TR© LATGFI QiA1# MD Np TYPE SCZE TRO LATG#i 1 3 I X78 I 5354 I (3~AY I I I RK 1 WL GOCIRLANVATOR: BRACKETI7FORE VALVE i~ANUFAGTURER: Gamut Page 16 of 16 DS 14-39 P &A (PTD 188-138) r Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, August 17, 2010 2:19 PM To: 'Lau, John, Jack' Cc: Aubert, Winton G (DOA) Subject: RE: DS 14-39 P &A (PTD 188-138} Page 1 of 2 Jack, Thanks for the explanation. I agree with your assessment that a FCO entails more risk than moving ahead with the abandonment as planned. Your intermediate cement plug will prevent migration of hydrocarbons to other strata and will satisfy regulations under 20 AAC 25.112 (C)(1)(c). The sundry will likely not get approved till just after August 25 (your planned start date) ... if you need this expedited let me know. Our reservoir engineer is on vacation and will not be able to look at this procedure until August 24tH Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Lau, John, Jack [mailto:Jack.Lau@bp.com] Sent: Tuesday, August 17, 2010 10:32 AM To: Schwartz, Guy L (DOA) Cc: Kara, Danny T Subject: DS 14-39 P 8cA (PTD 188-138) Guy, Per our conversation, the proposal to P&A well 14-39 for reservoir isolation is due to well integrity concerns. 14-39 has been established as a high risk well due to TxIA communication, IAxOA communication, a PC Leak, and a SC Leak. This well is currently secured with a sand plug in the 7" liner at 9271' and a WRP set in the 4.5" tubing at 9150'. The 14-39 Cement Bond Log (CBT) and Cement Evaluation Log (CET) have been reviewed by both BP and Schlumberger engineers. The resultant interpretation indicates there is more than 1000' of cement behind the 9-5/8"above the production packer. The objective of this P&A is to isolate this wellbore from the reservoir with 1500' of cement placed above the production packer and WRP in both the tubing and inner annulus. This will be accomplished by pulling GLV from Sta#9 and circulating cement down the tubing and up the IA. Another option evaluated was to pull the WRP, FCO, and P&A using coil, however this option was deemed too high of risk due to the well's integrity status. Please let me know if you have any questions or concerns. Thanks, Jack Jack Lau Wells Engineer 8/17/2010 DS 14-39 P &A (PTD 188-138) Page 2 of 2 BP Exploration (Alaska) Inc. Office: 907.564.5102 Cell: 907.227.2760 8/17/2010 .' '\ STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 SuspendD Operation ShutdownD Perforate 0 WaiverD OtherD Alter CasingD Repair wellD Plug Perforations]] Stimulate 0 Time Extension 0 Change Approved ProgramD Pull TubingD Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 188-1380 Development ]] Exploratory 0 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 Stratigraphic 0 ServiceD 50-029-21888-00-00 7. KB Elevation (ft): 9. Well Name and Number: 74.00 14-39 8. Property Designation: 10. Field/Pool(s): ADL-028312 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 9850 feet true vertical 9251.9 feet Plugs (measured) None Effective Depth measured 9271 feet Junk (measured) 9642, 9643 true vertical 8714.7 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# H-40 36 - 116 36.0 - 116.0 1490 470 Liner 595 7" 29# L-80 9153 - 9748 8606.4 - 9156.6 8160 7020 Production 9433 9-5/8" 47# L-80 34 - 9467 34.0 - 8895.3 6870 4760 Surface 20 13-3/8" 68# K-55 35 - 55 35.0 - 55.0 3450 1950 Surface 3557 13-3/8" 72# L-80 55 - 3612 55.0 - 3538.0 4930 2670 Perforation depth: Measured depth: 9391 - 9413, ,9506 - 9543,9545 - 9566,9570 - 9586,9596 - 9612,9624 - 9640 True vertical depth: 8825.13 - 8845.42,8931.44 - 8965.78,8967.63 - 8987.13,8990.85 - 9005.71, 9015.01 - 9029.89,9041.05 - 9055.94 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 33 - 9224 Packers & SSSV (type & measured depth): 4-1/2" AVA TRSV SSSV @ 1997 RECE IVED 4-1/2" Baker Model D Packer @ 9100 12. Stimulation or cement squeeze summary: JAN 1 6 2004 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission 13 Representative Dailv Averaae Production or In¡ection Data Anchoraoe Oil-Bbl I Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 376 I 0.75 4617 1580 202 Subsequent to operation: Currently Shut-In 1389 3 14. Attachments: 15. Well Class after proposed work: Exploratory 0 DevelopmentŒ] ServiceD Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 OilŒ) GasD WAG 0 GINJD WINJD WDSPLD Daily Report of Well Operations. ! Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Garry Catron NI A Printed Name Garry Catron Title Production Technical Assistant Signature Phone 564-4657 Date 1/14/04 0 R , G \ . ~. JAM 2\1 100~ Form 10-404 Revised 12/2003 R£l)MS Sf L ' ( ( 14-39 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/18/03 T/I/O=SI/1580/840. IA FL at 2800' (150 bbls). For CT. 08/18/03 RU Baker MHA w/Sure Catch pulling tool w/1-3/4" grapple for 3-3/8" Baker IBP. RIH to 96821 ctmd and soft tag IBP, latch PUH and re-tag at 9705'. Pump 30 bbls 25 KCL to knock down WHP and POOH w/Baker 3-3/8" IBP. IBP rubber left in the hole. Rig up WL unit to fish rubber. WL tagged TO at 9640' wlm, did not recover the rubber. 08/18/03 Thaw Hydrate plug/Fish IBP/Sand plug. RIH with 2.5in down jet nozzle. Tag ice at 1945' ctmd. RIH jetting w/50/50 and neat methanol. Cleared two hard plugs at 19451 and 31311 ctmd. Last plug at 32801. 08/19/03 NOT ABLE TO RECOVER MISSING IBP ELEMENTS RDMO AS PER. CTU CO. REP. 08/19/03 Lay in 27 bbls of 8 ppg 20/40 sand slurry (6400#) from 96901 ctmd, wait 1 hr. RIH and tag at 9425' ctmd. Lay in 14 bbls of 8 ppg 20/40 sand slurry (3300#) from 94251 ctmd. waith 30 min and washed tbg to tail. RIH and dry tag sand top at 92711 ctmd. POOH. Rig down. 08/19/03 IA FL at 28001. Bullhead 6 bbl's meth and 280 bbl1s crude down IA while RIH wih 2.25in ball drop nozzle. Swapped to KCL water down the tbg and pump 220 bblls down tbg x coillA. Start pumping down the coil and check for 1:1 returns. Did not get all the gas out, re-start kill. Pump 290 inhibited 1 % KCL followed by 160 bbls curde down IA. Kill tubing w/195 bbls 2% KCL & 50 bbls crude. RIH and tagged at 9434' and again at 95781 ctmd while pumping intermittently. Made check run from 9695' to 9150' and back to 9695' without problems. IBP rubbers appear to be on bottom, started injectivity test and CT Nzl plugged. POOH. Clean out nzl, flush coil and RIH to plug lay depth. 08/20/03 Sand plug set @ 92711-96401 08/21/03 DUMP BAIL 5 GALLONS OF LATEX ON TOP OF SAND @ 92171 SLM. RDMO. WELL LEFT SHUT IN. FLUIDS PUMPED BBLS 329 50/50 Methanol 70 Ex SLK 1 % KCL 523 Crude 437 20/0 KCL 296 Inhibited 1 % KCL 50 HEC gel 9700 Lbs 20/40 River Sand 36 Neat Methanol 11441 TOTAL Page 1 '¡. ( ( TREE = FWC GEN 4 WH.LHEAD = FWC 14-39 SAFErY NOTES: WAIVEREDWB.L.IA x A CTl..LA. TOR = AXB...SON OA x FORM SlRFACECASING FAILUÆ. KB. B...EV = 74' LEAKAT 41'. BF. B...EV = KOP= 2400' Max Ange = 26 @ 6100' 4-112" A V A TRSV SSSV t\lP. ID = 3.812" DatumMD= 8 DatumTVD = 8800' SS 13-3/8" CSG, n#. L-80. ID = 12.347' GAS LIFT Mð.NrRH.S ST rvo lVD ŒV lYFE VLV LATa-f PORr DATE 1 3198 3158 23 CA-Mtv'G ErvPTY POCKET Minimum ID = 3.725" @ 92131 2 4742 4579 22 CA-Mtv'G DMY RK 0 3 5576 5354 24 CA- Mtv'G DOME RK 16 01 /21 /94 4-112" OTIS XN NIP PLE 4 6700 6370 26 CA-Mtv'G DOME RK 20 01 /21 /94 5 7488 7083 25 CA-Mtv'G DMY RK 0 6 8022 7566 25 CA-Mtv'G SO RK 28 01 /21 /94 7 8137 7671 25 CA-Mtv'G DMY RK 0 8 8847 8325 22 CA-Mtv'G DMY RK 0 9 8890 8364 23 CA-Mtv'G DMY RKP 0 9100' 9-5/8" x 4-1/2" BAKER DB PKR TOP OF 7" LNR 9153' 4-1/2" OTIS XN NIp, ID = 3.725" 4-1/2" TBG-PC, 12.6#, L-80, 0.0152 bpf, ID = 3.958" 4-1/2" TUBING TAIL -i TOPOF SAND (08/19/03) I 9-5/8" CSG, 47#, L-80, ID = 8.681" I 9219' H H.MD IT LOGGED 12ßO/91 I FERFORA llON SIJ\I1Mð.RY REF LOG: BI-CS ON 12/12/88 ANGLE AT TOP PERF: 23 @ 9391' Note: Refer to Produetion œ for hstorieal perf data SIZE SFF NTERV A L Opn/Sqz DATE 4" 4 9391 - 9413 C 01/05/89 4" 4 9506 - 9543 C 01/05/89 4" 4 9545 - 9566 C 01/05/89 4" 4 9570 - 9586 C 01/05/89 4" 4 9596- 9612 C 01/05/89 4" 4 9624 - 9640 C 01/05/89 (2) I-ES-N-15RFtRK (LOST 01/22/94) IBP RUBBER ELEMENTS (08/19/03) I-ES-02-20RC-RK (LOST 01/21/94) DATE REVBY COMfvENTS DATE REV BY COfvTv1ENTS PRUŒiOE BAY UNIT 12/15188 ORIGINAL COMPLETION WELL: 14-39 01/08189 LAST WORKOVER FERMT No: 1881380 08/15/01 RN/KA K CORREcrlONS APII\b: 50-029-21888-00 08/19/03 KSB/KK PLlL IBP; SAND DIJ\I1P SE"C 9, T10N, R14E, 2759.62' FEL & 5202.77' FI'l. BP Exploration (Alaska) /-.,, STATE OF ALASKA ALASK OILAND GAS CONSERVATION ~IMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.©. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2539' FNL, 1599' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 171' FSL, 2612' FWL, Sec. 9, T10N, R14E, UM At effective depth 86' FSL, 2538' FWL, Sec. 9, T10N, R14E, UM At total depth 75' FSL, 2527' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 74 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-39 9. Permit number/approval number 88-138 10. APl number 50 - 029-21888 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 9850 feet Plugs(measured) Bridge Plug @ 9337' MD (set 6/17/94) true vertical 9252 feet Effective depth: measured 9802 feet true vertical 9207 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 2150# Poleset 110' 110' 2000 sx CS III & 600 sx CIG Top job w/250 3612' 3538' Sudace 3579' 13-3/8" sx cs ~ Production 9436' 9-5/8" 600 sx CIG 9467' 8895' Liner 695' 7" 325 sx CIG 9848' 9250' Perforation depth: measured Isolated below Bridge Plug: 9391-9413'; 9506-9543'; 9545-9566'; 9570-9586'; 9596-9612'; 9624-9640'; true Vedical Isolated below Bridge Plug: 8825-8845'; 8931-8966'; 8968-8987'; 8991-9006'; 9015-9030'; 9041-9O56' Tubing (size, grade, and measured depth) 4-1/2', 12.6#, L-80, PCT @ 9224' MD Packers and SSSV (type and measured depth) Baker DB packer @ 9100' MD; 4-1/2", AVA SSV @ 1997' MD 13. Stimulation or cement squeeze summary 14. RECEIVED Intervals treated(measured) See Attached Treatment description including volumes used and final pressure MAR - 7 1995 Representative Daily Average Production or Injection Data h,!~k~ 0JJ & G,~$ Cul~. CumliJJ~siu[~ OiI-Bbl Gas-Md Water-Bbl Casing Pressure AllC~'l~in'g Pressure Prior to well operation Shut In Subsequent to operation Shut In 15. Attachments 16. Status of well classification as: Copies of Logs and SUrveys run __ Daily Report of Well Operations . Oil X~ Gas ~ Suspended ....-- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~ ~ Title Engineering Supervisor Form 10-40~Rev 06/15/88 cc: KZ, JWP. Date SUBMIT IN DUPLICATE, 9-5/8" 14-39 DESCRIPTION OF WORK COMPLETED x 13-3/8" ANNULUS CEMENT SQUEEZES 6/17/94: RIH & set an Inflatable Bridge Plug in the 9-5/8" casing at 9337' MD (plug top), above the six open perforations intervals located between 9391 - 9640' MD. POOH. Rigged down. 6/19/94 - 6/21/94: Performed a leak detection log indicating a leak was present in 13-3/8" casing at about 81' RKB. Pumped N2 down the 13-3/8" & got immediate returns up the 20" casing. 10/24/94: Performed a 9-5/8 x 13-3/8" Cement Squeeze as follows: MIRU & PT equipment. Tied hardline to 13-3/8" & pumped 3 bbls Diesel down the 9 x 13" annulus. Took immediate returns up the 20" casing. Pumped 63 bbls of Arctic Set cement down the 9 x 13" before getting returns up the 20". Diverted cement returns to tank, then resumed pumping an additional 104 bbls of cement down the 13-3/8". Returns entered the cellar outside the 20". Shutdown pumping & took returns to Vac truck from the 20". Left an estimated 115 bbls of cement downhole & never attained any squeeze pressure during the job. RD. 10/29/94: MITOA failed. 10/31/94' Performed a 9-5/8 x 13-3/8" Cement Resqueeze as follows: MIRU & PT equipment. Tied hardline to the 13-3/8", then pumped 20 bbls Diesel down the 9 x 13" annulus & took returns up the 20" casing. Pumped 60 bbls of Arctic Set cement w/cellophane flakes, down the 9 x 13" annulus & took returns up the 13 x 20". Rigged down. 11/5/94: MITOA failed. I I 1619 4: Performed 9-5/8 x 13-3/8" Cement Resqueeze as follows: MIRU & PT equipment. Tied in hardline to the 13-3/8", then pumped 54 bbls of Arctic Set cement w/cellophane flakes, down the 9 x 13" annulus & took returns up the 13 x 20". Got cement up through gravel in cellar w/20" returns shut-in; had a 500 psi max squeeze pressure. Opened 20" for returns & got 32 bbls cement back to Vac truck, leaving 22 bbls cement downhole. Rigged down. I I/8/9 4 · MITOA failed; returns still flowed up 20" casing. I I/1 5/94: RECEIVED MAR - 7 1995 Performed 9-5/8 x 13-3/8" Cement Resqueeze as follows' Ai~ska. Oil & Gas Cons. ColflrllJssiori MIRU & PT equipment. Tied hardline to the 13-3/8", and pumped Arctic Set ceme~Itc~etlophane flakes, down the 9 x 13" annulus. Took returns up the 13 x 20" & attained a 500 psi max squeeze pressure. Placed an additional 11 bbls of cement in the OA & 20". RD. 11/24/94: MITOA failed. I 1/27/94: Performed 9-5/8 x 13-3/8" Cement Resqueeze as follows: MIRU & PT equipment. Tied in hardline & pumped 2 bbls Arctic Set cement into the 9 x 13" annulus. Took no returns up the 13 x 20" & Shutdown for 30 minutes. Resumed pumping an additional 0.2 bbls of cement & attained a 2000 psi squeeze pressure. Held pressure for bleed off from 2000 to 1300 psi in 18 minutes. Placed an estimated I bbl of cement in the 9 x 13" annulus; well held a 1000 psi final pressure. Rigged down. 12/2/94: MITOA failed. 12/28/94' Pumped sealant job down the 9-5/8", w/3000 psi max treating pressure. 12/31/94- MITOA failed. The well is currently shut in & secured with all surface pressures at zero. IA x OA communication still exists & is suspected to be through the tree. Future work options to repair the well are currently being evaluated. ARCO Alaska Inc, Post Office Box 10-0360 Anchorage, Alaska 99510-0360 Telephone (907) 276-1215 October 29, 1994 Mr. David W. Johnston Commissioner Alaska Oil & Gas Conservation Commission 3301 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Update, Prudhoe Wells 14-39 and 16-26 Dear Commissioner Johnston: Attached per your request is a summary of recent activity and plans for wells 14-39 and 16-26 in the Eastern Operating Area of the Prudhoe Bay Field. If you require additional information or clarification, please feel free to contact either Richard Ortiz or Jim Styler at (907) 659-5102. R. A. Ortiz Annular Communication Engineer Attachments cc: Blair Wondzell, AOGCC RECEIVED t 0V - 7 1994 A~aska 0il & Gas Cons. Commission Anchor~e DS 14--39 CHRONOLOGICAL SUMMARY June 17, 1994: At 1:00 AM the drill site operator found the wellhouse askew and gravel blown out of the cellar around the conductor to a depth of about four feet. Well was still producing with gas lift and was then manually shut in. No further gas discharge was noted. An inflatable bridge plug was set below the tubing tail in the liner above perforations @ 9360' to secure the well. June 18, 1994: Loaded inner annulus (Tbg x 9-5/8) w/crude oil and performed combination Tubing x 9-5/8 MIT to 2000 psi - PASSED. Confirms 9-5/8 casing and IBP integrity. AOGCC witnessed by John Spalding. June 19, 1994: Ran plumb bob down 13-3/8 x 20 annulus - tagged @ 41' below ground level or ~81' KB. Noise/temperature logging while circulating nitrogen down 13-3/8 with returns up 20" conductor confirmed the 13-3/8" failure depth @ ~81' KB. NOTE: Well remained secure and was observed daily while a reservoir/wellbore utilization study was conducted for this area of the reservoir to determine optimum drainage of the remaining reserves. This study concluded that the existing wellbore should be returned to production after repair. June 21 & October 10-11, 1994: Performed 9-5/8 x 13-3/8 casing hanger packoff pressure testing: Routine positive pressure test to liquid failed. Further, more detailed testing indicated that the upper and middle seals are leaking but lower seals have integrity. October 24, 1994: Performed downsqueeze of the 9-5/8 x 13-3/8 annulus with Arctic Set I cement. Pumped 167 bbls total, with returns noted both inside the 20" and outside the 20" in the well cellar. Estimated volume placed in the wellbore was 115 bbrs. October 25, 1994: Tagged cement top of the 13-3/8 x 20 annulus at 34' with a plumb bob. Was unable to tag 9-5/8 x 13-3/8 annulus. October 29, 1994: Post downsqueeze 9-5/8 x13-3/8 MIT Failed. DISCUSSION REEEIVEO NOV - 7 1994 Alaska 0il & Gas Cons. Commission Anchora~ The apparent cause of the incident was a failure of the 13-3/8 casing 41' below ground level, which allowed 950 psi of trapped gas pressure to escape to the surface both inside and outside the 20" conductor. (The escaped'gas volume was 15.2 MSCF; no isq~_.d hydrocarbon escaped.) The b~urce of this pressure is believed to have been either a downhole 9-5/8 casing thread leak or surface wellhead packoff leak that allowed lift gas pressure from the 9-5/8 casing to pressure up the 13-3/8 at a very low rate over time. Our normal operating practice is to bleed the 13-3/8 pressure off whenever it reaches 1000 psi. It is suspected that drilling wear inside the 13-3/8 and/or corrosion contributed to the failure. PLANS The current plan for 14-39 is to perform a second downsqueeze down the 9-5/8 x 13-3/8 annulus. After the cement sets a MIT of the 13-3/8 will be performed. A sealant treatment of the 9-5/8 x 13-3/8 packoff is also planned as an added protection against gas seepage past the packoff. Following a successful 13-3/8 pressure test and the packoff sealant treatment, the well will be returned to production. R. A. Ortiz / J. W. Styler RE¢£ VED NOV ....7 1994 Oil & Gas Cons. Commission Anchors~ ~:~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johns~[c~. DATE: Chairma~ THRU: Blair Wondzell. ~ FILE NO: ~I¢~ / ~ ,~ P. I. Supervisor FROM: John Spaulding. c,,~])' .,~ SUBJECT: Petroleum Inspect-~'rt~ September 29, 1994 GF9LI3BD.doc Surface Casing Incidents Arco PBU DS 16-26&1~-39 .September 29, !994: I traveled to Arco's PBU wells 16-26 and 1.~-39 to inquire as to what steps have been taken to insure the integrity of the surface casings on these two wells. 14-39: As noted in a previous report dated June 16, 1994 (file gg91ufbd) well 1~-39 suffered a suspected surface casing failure resulting in rapid gas release. I spoke with Arco DS 1~ operator and he told me that some video logging had been attempted down the tubing with no results. I then spoke with Mike Shoemake Arco wireline supervisor and he informed me that Arco would be cutting a hole in the 20" conductor pipe so that a video log could be run down the outside of the 13 3/8" casing to the top of cement. Well 14-39 is secured with a mechanical bridge plug located in the tubing tail with kill weight brine on top of the mechanical bridge plug. 16-26: Early this summer (date unknown) well 16-26 incurred a subsidence problem in the cellar area around the conductor pipe. In speaking with the Arco DS 16 operator he informed my that at one time approximately 50' of the conductor pipe was exposed. Also during the summer approximately 100 yards of gravel was added to the cellar area. The wellhead appears to have subsided and is now leaning to the south approximately 10 degrees. There does not appear to be any damage to the wellhead or the flowline at this time, although both are probably under some lateral stress. The well was recently returned to production, co Mike Shoemake Arco wireline supervisor informed me that when the well was drilled ~ problems were encountered in cemerlting the surface casing and a" top job" was 4 required to get cement to surface. At this time there are no records indicating how/~ much cement is behind the surface casing. Summary: In my opinion that Arco has not placed a very high priority on the diagnosis and repair of a potentially very serious problem with wells 1~-39 & 16-26. ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location: P.O. Box 100360, July 6, 1994 ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution Transmittal #: 94054 chorage, AK 99510~ ~, '4~ka Oil & ~as Cons Anchorage' i W ell iL°g Date .. Number (M-D-Y) i 1-05ST ! 6-21-94 ! 1-17 ! 6-20-94 2-20 i 6-18-94 2-28 i 6-28-94 3-2 I 6-22-94 4-2 i 4-30ST 4-40 i 6-25-94 Tool Type i RUn,scale Prod Prof ! 1,1"&5" / Prod Prof IBP Setting Rec Leak Detection Leak Detection 1 5" 1 5" Contractori i SCH i SCH SCH 1,2"& 5" SCH 1,1 "&5" SCH 1 5" SCH f 6-17-94 / Patch SetRec I ~ 6-25-94 / Pen` Rec SCH ./ Pen' Rec SCH Comp Rec { 1 5" 1 5" 1 5" SCH SCH SCH SOH !O ! 4-44 ~.tj. l 4-45 (,d~ ,/i 5-03A 5-03A 5-03A 5-13 5-33 6-8 6-12A 7-6 i 6-20-94 i 6-25-94 6-9-94 Pen' Rec Pert Rec i I 5" i I 5" CDN i 1,2" &5" Slim 1 GR ! 1, 2"& 5" ! 6-9-94 SCH l 6-9-94 ~/ CDR l 1, 2" &5" SCH / Leak Detection i 6-17-94 i 6-29-94 i 6-15-94 I 6-24-94 --' Pen' Record ~ 1,1" & 5" I 1, 5" ~' TDTP i 1, 5" SCH SCH SCH .-- Perf Rec i 1, 5" SCH i 6-28-94 Pen` Rec i 1,5" SCH 7-26 i 6-19-94 i.- Pen' Rec I 1, 5" SCH 9-05A { 6-21-94 1~' PerfRec I 1, 5" SOH 9-05A ! 6-22-94 I/' Pen` Rec I 1, 5" SCH 9-30ST I 6-29-94 ,~ Duai Burst i 1, 5" SCH 11-6 i 6-22-94 /'ProdProf 1, 1"&5" SCH 11-29i 6-27-94 .-" Perf Rec 1, 5" SCH 12-02 I 6'28'94 1 12-7A 6-27-94 -"Leak Detection 12-19 6-27-94 '~' Inj Prof 12-23 6-28-94 /'~ Inj Pmf 12-28 ! 6-27-94 I ~ Prod Prof 13-08 I 6'30'94 I f Pen'Prof 14-24 i 6-15-94 I '~' CNL 14-39 I 6-19-94 I ~"~.eak Detection 14-39 i 6-19-94 ~" Leak Detection 16-28 l 6-20-94 ] / PerfRec 1, 5" SCH 1, 5" SCH 1,5" SCH 1, 5" SCH 1~ 5II 1, 5" SCH SCH 1~ 5II 1, 5" SCH 1, 1" &5" SCH 1, 2" SCH SCH * DS# 04-02 The APl# is $0-029-20088-00 Number of Records: 35 ARCO Alasl(a, Inc. is a Subsidiary of AtJantlcRIchfleldCompany ' ~qco Ahmka, Post Office Box 100360 Anchoragu, Alaska 99510-0360 Telephone 907 276 1215 , June 19, 1994 Mr. Blair Wondzell Chairman Alaska Oil & Gas Conservation Conunission 1001 Porcupine Drive Anchorage, AK 99501 Re: Reportable Gas Release Dear Mr. Wondzell: Following is a report fora gas release which recently occurred at our Prudhoe Bay Facility. If you or you staff need additional information on this event, please call Chris Brown or mc at 659-5609. Sincerely, Sheliie Jones Associam Coordinator Field Environmental Compliance [inclosure RECEIVED dUN 21 1994 Alaska 0it & C4as ~ons. ~;ommtssto~ Anchorage ARCO Alaska, lnc, Prudhoe Bay, Eastern Operating Area Reportable Substance SpiH Report .............. , Illl . . ,,' *' . _.~ '1 .... , l,ocation' Drillsite 14, Well. 39 Date: June 17, 1994 Time Observed- 01:00 hrs. Material: Natural Gas Quantity: 15 MSCF RECEIV£b Oil & GaS VUlIS. bU/lll'l'llSSlu'~ Anchorage Cause and Source: Gas was rvleased fi'om a failure in 13-3/8" casing; however the exact cause of this failure is currently being investigated. Preventative Action Preventative action will be reported to AOGCC once the exact cause is identified. MEMORANDUM TO: THRU: Blair Wondzell, P. i. Supervisor FROM: John Spaulding, Petroleum Inspec~(~r State or Alaska Alaska Oil and Gas Conservation Commission DATE: June 21, 1994 FILE NO: SUBJECT: GG9LFUBD.doc \. Incident at PBU 14-39 ARCO / PBU / Well 14-39 Prudhoe Oil Pool Thursday June 16, 1994: ! was notified by James Fausett, Arco FS 3 drill site supervisor, of a suspected 13 3/8 casing failure resulting in a rapid gas release outside the 20" conductor; I traveled to drill site 14 well 39 to investigate, arriving at about 7am. At 11pm on the night of June 15, the operator checked the well house and noted the 9 5/8 pressure was 1450 psi and the 13 3/8 pressure was 980 psi. He didn't bleed either casing down. At about lam the grease crew noted the wellhouse lifted off the pad and then settle back down on the pad. There was a crater under and around the well house. One of the crew went to the back side of the wellhouse and hit the ESD. Then they called the operator. The well house was sitting at an angle with the front down in a crater, it suffered severe damage. The flowline did not appear to have any physical damage. The well head appeared to be twisted. The control panel was in the cellar, missing its top, and was full of gravel. There were no personel injuries. The SVSystem was in operation and when operated from the external ESD, worked as designed. Arco started securing the well by pumping seawater to kill the well; after killing the well,the well house was removed and work mats were installed. An inflatable bridge plug was set in the 7" liner to secure the well and the tubing was bled to 0. An MIT was performed on the 9 5/8" annulus, the pressure bled 30 psi (from 2000psi) in 45 minutes. A boroscope camera was used to check inside the 20" condUctor and the outside of the 13 3/8" casing down to a depth of abput 18'. Temperature and noise logs were perfomed on June 17 and an anomaly was discovered at 40' and at 400' in the 13 3/8" casing. At this time Arco is letting the well temperatures stabilize and will be.tng doing more temperature and noise logs for confirmation. Estimated in about a week. Summary.: I investigated the rapid gas release at Arco drill site 14 well 39, cause not known yet, Safety Valve System in operatiom, cu,~ o~ Attachment: well bore schematic Sheet1 I Type of Problem ¡ I Well Name Csg Cmt WH Observation I Comments : Action/Result i PBU Wells I : ¡ : I : - A-18 Y Y cond leaking Press'd annulus & cond started leaking WH seals B-33A y broached Broached while disposing in nearby well E-18 sc Y I gas to sfc Also press on sc I H-16 sc Y Y fluids to sfc Shallow leak in SC- welded speed head H-25 y Y gas in cellar Packed casing hanger seals J-01 sc Y fluids to sfc SC leak at 60'- down squeezed J-23 ' Y broached Fluid surfaced while disposing down annulus K-11 pc press on sc OA press tracked IA pressure/Prod csg leak - K-13 sc Y oil in cellar Oil in cellar- sc leak at 30' bleed OA --- K-19 pc press on sc Press would not bleed down N-20 sc Y Y gas in cellar Prob 60 - 80' below sfc- to be RD'd to be RO'd P-18 sc ? Y o&g to sfc Leak in the sc at - 80'- down sqz'd OA sqz'd OA R-34 sc pc Y Y g&m in cellar Leak @ 420'- seals leaked- pc also leaked RWO W-08 pc gas in OA Leak in pc- sqz'd OA- ok press test sqz'd OA 4-19. Y broached Disposal fluids surfaced 9-23. sc pc Y g&w in cellar Hydrate gas/downsqz'd/g&w in cellar RWO 9-47. Y broached Disposal fluids surfaced 11-27. Y wtr outside 3bpm wtr outside well/source not determined Cbs 14-39. sc Y gas release Sudden /sc parted 81'(41'bgl)/downsqz not good wellSI 15-45. y broached Disposal fluids surfaced down sqz sc 16-26 ? subsidence Conductor slipped down hole gravel fill 16-27 ? subsidence Conductor & tree leaning gravel fill PWDW Y broached MPU Wells K-25 y gas in cellar Hydrate gas/no cmt to sfc wac E-4 sc Y broached Disp'l fluids broachedlleak @1200'/csg wear arctic pak -- ~-- ..-- .--.--- DIU Wells 4-38/K-34 y broached Disposal f/4-48/K-43 broached in 4-38 SI displ 1--. broached Disposal f/1-51 broached in 1-41 SI displ 1-41/0-23 y 1-53/0-20 Y gas to sfc Formation gas to sfc out side conductor P&A well 1-61/0-20 y pc prss on OA Reservoir press on OA due to pc poor cmt sqz'd pc 1-33/M-23 y broached Disposal f/1-33/M-23 broached in M-23 sqz'd OA Exp Wells Sourdoug 3 y broached Disposal down #3 broached around #3 SI displ Badami 4 ? subsidence During disposal, WH subsided SI displ Badami 5 ? subsidence During disposal, Wh subsided SI displ KRU Wells 2T-21 ? sc cmtg Lost circ early while cmtg/no action taken Notes: 1. Surface casing leaks 10 2. Prod casing leaks 5 3. Problems w/sfc casing cementing 24 4. Problems w/prod csg cementing 1 5. Well Head leaks 5 6. Subsidence around the conductor 4 7. Disposal fluid to surface 11 - 8. Other gas/fluid to surface 14 sc-probs.xls 10/4/96 Page 1 Well: 1A-39 Spud Date:Il/26/88 Original RKBE:74' Top of Formation: 9495' Annular Fluid:9.0 Brine Reference Log:BHCS .%RCO Alaska, Inc. - Prudhoe .... y AP1 #: 50-029-21888-00 Completion: 01/08/89 Hanger ~fpe: FMC Gen IV Max Hole Angle: 25° ~ MD: 6100' Date:12/12/88 Tie In: Type:PRODUCER Status:New Hanger:33' Angle @ TS:22° Angle @ TD:21° Date: 00/00/00 ALL DEPTHS ARE RKB DRILLINO MD TO TOP OF EQUIPMENT EXCEPT WHERE NOTED. J-1 IkC'l Jewelry (J) Depth Description I 1997 4-1/2" AVA TRSV SSSV Nipple ID=-3.812" 2 9100 9-5/8" x 4-1/2" Baker DB Packer 3 9213 4-t/2' Otis XN Nipple ID=3.725" 4 9223 4-1/2' Baker Shearout Sub 5 9224 4-I/2' Tubing Tail 9219 ELM Tubing Tail (Logged 12/30/91) 7 FISH: (2) HES-N-15RP-RK (Lost 01/22/94) 8 FISH: HES-02-20RC-RK (Lost 01/21/94) Min ID: 4-1/2" Otis XN Nipple ID=3.725" G-1 Casing and Tubing (C) Size Weight Grade ! 13-3/8" 729 L-80 2 9-5/8" 47# L-80 3 7" 29# L-80 4-1/2' 12.6% L-80 Top Bottom Description 0' 3612' Casing 0' 9467' Casing 9153' 9848' Liner 0' 9224' Tubing-PC Gas Lift Information (G) W/L had difficulty installing/pulling glvs due to scale MD TVD Stn Mandrel Valve Type Latch Port TRO Date 3198' (3158') 1 CA-MMG HES J-3 4742' (4579') 2 CA-MMG TE 5576' (5354') 3 CA-MMG HES J-4,~ Stn 3: High Scaling Tendency 0-2 6700' (6370') 4 CA-MMG HES Stn 4: High Scaling Tendency 7488' (7083') 5 CA-M/dG HES Stn 5: High Scaling Tendency 8022' (7566') 6 CA-MMG HES Sin 6: High Scaling Tendency 8137' (7671') 7 CA-MMG CA 8847' (8325') 8 CA-MMG CA 8890' (8364') 9 CA-MMG CA N-15RP RK D-14R RK N-15RP RK N-15RP RK D-14RP RK O2=20RC RK 1/4" 1715 01/21/94 1/4' 1707 01/22/94 5/16' 1739 01/22/94 01/22/94 7/16' ORIF 01/22/94 Perforation Data (ELM DEPTHS) (P) Interval Zone FT SPF P-1 1 9391- 9413 SAG 22 4 9506- 9543 4 37 4 9545- 9566 4 21 4 9570- 9586 4 16 4 d-7 9596- 9612 4 16 4 J-8 9624- 9640 4 16 4 Date Comments 01/05/89 IPERF 01/05/89 IPERF 01/05/89 IPERF 01/05/89 IPERF 01/05/89 IPERF 01/05/89 IPERF 0-3 FRAC 11/13/89 Not Arctic Packed Datum 8700' SS= 9335' MD 8800' SS= 9444' MD PBTD= 9716' TD= 9850' Revision Date~ 01/23/94 by ENH Reason: GLV C/O Sta#1,3,4,5,6; Fish Previous Reason: 10/16/93 Well 14-39 ARCO Alaska, Inc. P.O. Box 100360, ,, orage, AK Date: Subject: From/Location: Telephone: To/Location: el'5- Feb 25, 1994 Transmittal #: 94024 ARCO Static Pressure Surveys John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well iLog Date i Tool Type Number (M-D-Y) 2-3 6-5-93 Static Press Sun/. I 7-21-93 Static I 11-22-93 ~ Static f 1-3-94I Static 2-5 3-8 3-19 3-35 3-36 4-12 4-31 4-32 4-41 5-12 6-19 _ 7-7A 7-8 9-49 11- 16ST1 c~.--i t 18-29A Press Sun/. Run, 11-22-93 Static 12-7-93 Static I 7-24-93 Static 11-17-93 Static 1-3-94 Static 9-8-93 Static 11-21-93 Static 7-21-93 Static 1_1-28-93 Static 7-21-93 Static 9-2-93 Static 9-14-93 Static 9-5-93 Static Press SUrv. Press Surv. Press Sun/. Press Surv. Press Sun/. Press Sun/. Press Sun/. Press Sun/. Static Press Sun/. ! 5II Contractor Sch Sch Press Sun/. " Sch Press Sun/. " Sch Press Sun/. " Sch Press Sun/. " Sch Press Surv. " Sch Press Surv. " Sch PreSs Surv.. " Sch II II II II II II II II II II II II II # II II II II II II II II II Sch Sch Sch Sch __ Sch Sch Sch Sch p_~oo 11-17 11-26-93 12-16A 11-8-93 Static Press Surv. 13-14 i 7-2-93 Static Press Sun/. 13-14 7-2-93 Static Press Surv. 14-01 11-25-93 Static Press Surv. 14-6 11-25-93 Static Press Sun/. 14-18 11-26-93 Static Press Surv. 14-38 12-4-93 Static Press Sun/. 14-39 12-4-93 Static Press Surv. 15-6 5-28-92 Static Press Sun/. 15-15 7-5-93 Static Press Sun/. 15-16 8-26-93 Static Press Surv. 15-18 10-26-93 Static Press Sun/. 15-23 9-23-93 Static Press Sun/. 16-12 7-21-93 Static Press Surv. 16-17 12-29-93 Static Press Surv. 16-18 7-18-93 Static Press Surv. 16-22 I 7-18-93 I Static Press Surv. 17-1 11-23-93 Static Press Surv. 17-13 8-27-93 Static Press Sun/. 5-19-93 Static Press Surv. I! Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch t Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch 99510.~ ~. ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRIr. hflMdCompeny ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-18-92 1-10 fY"- ~,~ 11-154~ t4-s 11-16-92 Lll-168'r 11-18-92 16-14, 10026~ f16-21 L~-- i~.10027'92 16-21 ~ '~' 10027-92 17-10 ~/"~? 11-6-92 17-13 o%9/--? ~'~ 10024-92 Jewelry ~ L ~' Camco Prod Profile l~m L ~' Camco Jewelry la,m 1, ~' Camco Prod Profile ]~m L ~ Camco Inj Profile ~ L ~" Camco Please sign and return the attached copy ,as receipt of data. RECEIVED BY___.~_~_~~_~L~ Have ANice Day[ DEC30 1992 ..~_~~ Sonya Wallace Alaska 0il & Gas Cons. Commission APPROVED_ ATO- 1529 Anchorage Trans# 92266 # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # pm~.T.Ip8 PB WELL FH2~ R&D #BPX # STATE OF ALASKA TEXACO WALTER J. HICKEL, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION April 14, 1992 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 John Trautwein Core Store BP Exploration(Alaska), Inc. 1310 West 56th Avenue Anchorage, Alaska 99501-1433 Re: Inadequate or missing samples Well Name: PBU DS 14-39 Permit Number: 88-138 Dear Mr. Trautwein: The Alaska Oil and Gas Conservation Commission requests, the operator of the above referenced well to resubmit the dry ditch / core sample intervals listed on the attached transmittal(S). Sample sets have been received by the Commission, however during the verification process, some intervals have been deemed either inadequate or were not submitted. The ~ intervals are listed on the attachment, please submit.these listed intervals as soon as possible. The following is an excerpt from the Alaska Oil and Gas Commission Regulations: 20 AAC 25.071. Geological Data and Logs. Stipulates that operator shall:. (b) within 30 days after completion, suspension, or abandonment of a drilling well the operator shall file with the commission (2) a complete set of washed and dried, legibly- identified samples of all drill cuttinqs, as caught by the operator in accordance with good geological practices, consisting of a minimum of one-quarter cud in volume or three ounces in weight of cuttings for each sample interval; (3) a lithologic description of all cores and a chip or chips from each foot of recovered core; the chips must be representative of the one-foot interval, and must be approximately either one cubic inch in volume or three ounces in weiqht; If you have any questions in reference to this matter, please contact Larry Grant at (907) 279-1433. Robert Crandall Senior Petroleum Geologist Alaska Oii Gas Conservation Commission 3001 Porcupine Drive Anchor=ge, Alask= 99501-3192 901-279-! 433 To: ARCO Re: Well name: PEIU DS 14-39 Permit: 88-0138 SubjectF: Samples Receipt of the following core samples. These samples are~ hereby acknowledged as being received. Et OX # I NTE RVALS 1 9513' thru 9542' 2 9542 thru 9571' 3 9571' thru 9600' 4 960!' thru 9§46' 5 9647' thru 9658' I ~lpl~., IUIIUWlII~i_ []lTblY(JiO (Jib IIIQtJb~ltltb. 9515' 9516' 95~' 9587' 9599' Copy sent to sender:. Yes ~ No _____ ARCO Alaska. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 1-24-92 REFERENCE: ARCO CASED HOLE FINALS ~~_~ ~- ~'"~ 12-29-91 ~//.---z Il 12-29-91 ? ~ .,-~/ 12-29-91 ~'~9_ ~ ~ 12-28-91 .~~~ #/ 12-~-91 ~.~ .. 1-5-92 ~ ~~II~ 1-6-9212-31-91 ~-~/ z~ 12-31-91 ~ 12-26-91 Prod Profile Run 1.5" Temp Survey & Tag Run Run. 1.2" InJ Profile Run 1.5" Perf Breakdown/Temp/Spinner Run 1, 5" Perf Breakdown Run 1, 5" Leak Detect Run 1.5" Prod Profile Run 1.5" Leak Detect Run 1.5" InJ Profile Run 1.5" InJ Profile Run 1.5" PITS Run 1, 5" Prod Profile/Gas Lift Run 1.2"&5" Prod Profile Run 1, 2"&5" Leak Detect ~ 1.2'&5" Leak Detect Run 1, 2'&5" Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Camco Please sign and return the attached cop~ as receipt of data. RECEIVED BY _ff~~_ _~~__A/ ~ Have A Nice Day! ~ _~,~~ Sonya Wallace APPROVED ATO- 1529 Trans# 92016 J # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF ~KA TEXACO RECEIVED FEB 0 3 7992 Alaska Oil & Gas C~n$. Comrnissk)n Decembe~ 19~ 1991 Iii P Ii:.' X F" l... 0 R A '1" I 0 N ( A I.. A S K A ) , iii N C , 1~i.~10 I,,;est ~:;6th Avenue Attn: CORE: $1'ORE THE: F:'OI..I...OHING I'~A[I::.R.I:AI.. :I:S BI":.ING ,SUI:~M]:TTli::I:] ,"II::EEI, JJ:-I['H. I...EAolii: AE:KNC][dL.E:DGE' R iii: CIE :[ P T 13 Y ~] :[ G N :1: N G A C 0 P Y 0 F' T I"1 :[ ,"~ I_ [C T TIE F,' A N. 13 I;,' I.:: '1[' LJ R N :1: N G Z T '1" 0 T H :[ ,".~ 0 F' F: :1: C E ~ t, H ,:': :1: n t. y r e :I1: J. :-]: 8 b o x e s, o v e ~ .1:. h e :i. n t e r v a 1 .1. 2 7 D 9.-- :L B 0 7 :L , ( C 0 N F' I ILl Ii': N'F I A I.. ) 13 tJ .1. 4 --- ~ 9: -.-17: 13 a t e 13 a t e RECEIVED Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALA:i'~-'"i~, OIL AND GAS CONSERVATIO',' ~OMMISSION REPOR i' OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2539' FNL, 1599' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 171' FSL, 2612' FWL, Sec. 9, T10N, R14E, UM At effective depth 88' FSL, 2538' FWL, Sec. 9, T10N, R14E, UM At total depth 75' FSL, 2527' FWL, Sec. 9, T10N, R14E, UM 5. Type of Well Development X Exploratory Stratigraphic ...... Service 6. Datum of elevation(DF or KB) 74 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 14-39 9. Permit number/approval number 88-138/9-863 10. APl number 50 - 029-21888 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9850 feet true vertical 9252 feet Effective depth: measured 9802 feet true vertical 9207 feet Casing Length Size Conductor 80' 20" Su dace 3579' 13-3/8" Production 9436' 9-5/8" Liner 695' 7" Plugs(measured) Junk(measured) Cemented Measured depth True vertical depth 2150# Poleset 110' 110' 2000 sx CS III & 600 sx CS I 3612' 3538' Top job w/250 sx CS I 600 sx CIG 9467' 8895' 325 sx CIG 9848' 9250' Perforation depth: measured 9391-9413'; 9506-9543'; 9545-9566'; 9570-9586'; 9596-9612'; 9624-9640' true vertical 8825-8845'; 8931-8966'; 8968-8987'; 8991-9006'; 9015-9030'; 9041-9056' Tubing (size, grade, and measured depth) 4-1/2', 12.6fl, L-80, PCT @ 9224' MD Packers and SSSV (type and measured depth) Baker DB packer @ 9100' MD; 4-1/2", AVA SSSV @ 1997' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached Treatment description including volumes used and final pressure DEC - 4 i990 Alaska 0ii & Gas 0OHS. Commission 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Obi Casing Pressure 1084 1210 588 -- 4991 6361 3788 Anchorage Tubing Pressure 222 3O4 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X. Gas .. Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Date Form 10-404 Rev 06/15/88 572 DRR c: J. Gruber, ATO-1478 SH SUBMIT IN DUPLICATE DS 14-39 DESCRIPTION OF WORK COMPLETED FRACTURE TREATMENT OF SAG RIVER & ZONE 4 I I/8/89' RIH & replaced OGLV w/DGLV. I I/1 3/89: MIRU, & PT to 7000 psi. Pumped a propped fracture treatment using cross linked water and intermediate strength proppant through perforations at: 9391 - 9413' MD (Sag) Ref. Log: 12/12/88. 9506 - 9543' MD (Z4) 9545 - 9566' MD (Z4) 9570- 9586' MD (Z4) 9596- 9612' MD (Z4) 9624 - 9640' MD (Z4) Pumped the treatment as follows: a) 152 bbls Uncrosslinked Pre Pad Gel w/OSR, @ 30 - 40 bpm, followed by b) Shutdown. ISIP @ 1226. Resumed pumping: c) 1848 bbls Cross Linked Water Pad w/OSR, @ 45 bpm, followed by d) 631 bbls Slurry w/proppant concentrations of 1 to 10 ppg, followed by e) 40 bbls Diesel Flush. Shutdown. Placed a total of 118,000 lbs of proppant into the formation. Rigged down. I I/25/89 · Performed a proppant fill cleanout to 9787' MD. I I/28/89 · Replaced DGLV's w/LGLV's. Returned well to production and obtained a valid production test. RECEIVED DEC - 4 ~99~ Alaska 0it & Gas Oons. Coi~miss~O~'~ Anchorage ARCO Alaska, Inc. ! Prudhoe Bay _.~gineering Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 263 4248 Donald F. Scheve Operations Engineering Manager September 25, 1989 C. V. "Chat" Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: DS 14-39, Permit No. 88-138 Dear Mr. Chatterton: Attached is the Application for Sundry Approval detailing work to be performed on the above-referenced well. Sincerely, D. F. Scheve DFS/DRR/jp Attachment cc: J. Gruber, AT©-1478 PI(DS 14-39)W1-3 I £C iVED $£P 2 6 1989 Alaska Oil & ~as Cons. Cor~r~;$$io~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B--6132-C STATE OF ALASKA ALASKA'" '~'~'L AND GAS CONSERVATION CC~AISSION 0 R I C-IN A L APPLICA, ION FOR SUNDRY AF,--ROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well AItercasing Repairwell Plugging Time extension Stimulate X Change approved program Pull tubing Variance Perforate __ Other ,,, 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) RKB 74' 7. Unit or Property Prudhoe Bay Unit 4. Location of well at surface 2539' FNL, 1599' FEL, Sec. 9, T10N, R14E, UM At top of productive interval 171' FSL, 2612' FWL, Se¢.9, T10N, R14E, UM At effective depth 88' FSL, 2538' FWL, Sec.9, T10N, R14E, UM At total depth 75' FSL, 2527' FWL, Sec.9, T10N, R14E, UM 8. Well number 14-39 9. Permit number 88-138 10. APl number 50 - 029 - 21888 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured 9850' feet Plugs(measured)RECEIVED true vertical 9252' feet Effective depth: measured 9802' feet SEP 2 1989 true vertical 9207' feet Junk(measuredAJaska 0il & Gas Cons, C0mmissi0r~ Casing Length Size Cemented Arll~§g~led depth Conductor 80' 20" 2150# Poleset 110' 20o0 sx cs ,~ & soo sx 3612' Sudace 3579' 13 3/8" class G-Top job w/25o sx cs I Production 9436' 9 5/8" 600 SX Class G 9467' Liner 695' 7" 325 SX Class G 9848' True verticaldepth 110' 3538' 8895' 9250' Perforation depth: measured 9391-9413'; 9506-9543'; 9545-9566'; 9570-9586'; 9596-9612'; 9624-9640' true vertical 8825-8845'; 8931-8966'; 8968-8987'; 8991-9006'; 9015-9030'; 9041-9056' Tubing (size, grade, and measured depth) 4 1/2", L-80, 12.6~, PCT @ 9224' MD. Packers and SSSV (type and measured depth) Baker 'DB' pkr @ 9100' & AVA SSSV @ 1997 MD. 13. Attachments Description summary of proposal x. Detailed operations program BOP sketch x 14. Estimated date for commencing operation September, 1989 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby c/e~tify that the,,foreg~ing is true and correct to the best of my knowledge. Signed .,~_. i~~/~/~~__...~' Title Operations Engineering Manager 15. Status of well classification as: Oil x Gas J.. Suspended__ Date FOR COMMIR~ION U~E ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance ,~/'~ Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commissioner ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner I Approval No. ¢_. ~)~/~ Approved Copy Returned Date C~.. ~,)¥..~c~ Form 10-403 Rev 06/15/88 Dennis Reimers SUBMIT IN TRIPLICATE Drill Site 14-39 Ivishak and Sag River Formations Hydraulic Fracture Treatment PRELIMINARY PROCEDURE ARCO Alaska intends to pump a hydraulic fracture treatment on well 14-39 as outlined below: . . . . . . Pull gas lift valves and replace with dummy valves. Pressure test tubing / casing annulus. Rig up fracturing service company. Pump propped fracture treatment at 40-45 BPM using a dual cross linked water system with approximately 63,000 lbs of 16-20 proppant. The maximum injection rate possible will be obtained following pressure limitations. The interval to be fracture stimulated is the Sag River interval from 9391' to 9413' and the Ivishak interval from 9506' to 9640'. The pump schedule is outlined as follows: A. B. C. D. E. F. 1000 Bbl cross linked water pad 50 Bbl 2 PPG in cross linked water 50 Bbl 4 PPG in cross linked water 50 Bbl 6 PPG in cross linked water 50 Bbl 8 PPG in cross linked water 50 Bbl 10 PPG in cross linked water Rig up CTU and cleanout to PBTD if necessary. Open well to flow gradually increasing the drawdown to allow proper fracture healing. Install gas lift valves. RECEIVED 5 4 3 2 COILED TUBI. Nt3 UNIT BC~ EGU ! PMENT 1. 5000 PSI ?" W£LLN-~ CONNECTOR FLANGE 2. 5000 PSI 4 1/16" PiPE RAMS 3, 5000 PSI 4 1/6" HYD~LK~ SLIPS 4. 5000 PSI 4 1/6" SHEAR RAMS 5. 5000 PSI 4 1/~," BLIND RAMS 6. 5000 PSI 4 1/16" STUFFING BOX 3 2 H]REL]NE BOP EOUIPHENT i i i 1. 5,000 PSI ?" WELLHEAD CONN£CIOR FLANGE 2. 5000 PSI WlRELIN[ RAMS (VARIABLE SIZE) 3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF ARC(] ALASKA, INC, F'.O. BOX ~00360 ANCHORAGE, ALASKA DATE' 8-29-89 REFERENCE' ARCO F'RESSURE DATA 5--t .5 7-'27-89 BHP--~'TAI'IC GRADIENT CAMCO J-33 7-t4-89 BHF'--,~TATIC GRADIENT CAMCO 4-2 7-8-89 BHF'--~'TATIC GRADIENT (W/ATTACH.) CAMCO 7-5 7-~9-89 BHP--3'TATIC GRADIENT CAMCO 7-7A 7-~ t -89 BHF'--F'BU HR~¢' 7-8 7-29-89 BHF'--S'I'AT I C GRADIENT CAMCO 7-J O, 8-5'-89 BHP--S'TATIC GRADIENT CAMCO 7-~ 4 '?-29-89 BHF'--PBU HR$ 7-27 7-2~-89 BHF'--$TAT I'C GRADIENT CAMCO 7-33 7-23-89 BHF ....£TAT.[ .... GRADIENT CAMCO 9-24 7/~4-~5/89 BHF'--~'TATIC GRADIENT CAMCO 9-~8 8-~ '2-89 BHF'--~"I'AT I C GRADIENT CAMCO J~-2 7-7-89 BHP--~'TATIC GRADIENT HR~' ~ ~-7 '?-9-89 BHF'--~'TATIC GRADIENT HR~? ~-~6 7-~8-89 BHP--~'TATIC GRADIENT HR~~ tJ-~7 8-JJ-89 BHP--FI_OWING GRADIENT CAMCO ~ 2-~£* 7-23-89 BHP--$TATIC GRADIENT CAMCO ~4.-~9 8-J0-89 BHF'--$TATIC GRADIENT CAMCO ~4-22 8-~7-89 BHP--$TATIC GRADIENT CAMCO ~ 4-~6 7-29-89 BHF'--FLOWING GRADIENT CAMCO ~ 4-39 8-~ ~--89 BHP--S'TATIC GRAD]lENT CAMCO ~5-~5 7-2J-89 BHP--$TATIC GRADIENT CAMCO ~ 6.-~ 2~ 7-26-89 BHP--~'TATIC GRADIENT CAHCO ~6-2o 7--~3-89 BHP--£TATIC GRADIENT CAMCO J 8-25: 7-.~ ~-89 BHP--J;TATIC GRADIENT CAMCO PLEA£E £IGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA~ DISTRIBUTION AF'F'ROVED"~~ TRAN$:D 89363 CENTRAL FILES CHEVRON · ,,-D & M EXTENSION EXPLORATION ~ EXXON MARAI'HON ~ . .~ MOBIL -- ~ · ,-'"' F'HILLIF'~' F'B WELL F'ILE£' ..ti. · ,- R & D ~ BPX · * ~"FATE OF ALASKA ~~ TEXACO Ai~.:CO A! AS'KA, INC,. F' ~ 0 ~ I.:~ 0 X ~ (:.:, ~'i:, :5 6 6, ANCHORAGE, ALA~;KA 995 i ,3 DATE · 7-i 9-89 U~-.~ ED F "' REFERENCE' ARCO "'"" .... ' HOLE - i 7 2-9 S- 28 i4-4 4-5: 4-23 4 -.}:3 4-35 4--.39 i5--i ~'5-i 3 '=..' -- ".':'. i8-i8 8-21 6--.27-89 '7 - i '5 ..- ~-~ 9 7..-2.-89 6 - 29 - 89 6-..'5,::.:,- 89 7'-i -89 ":' 8':.;' A - '~ :q - 6: ':."-:' 7'--i -89 6-29-89 6-28-89 6._,~ ~' -,:':,- ~ 9 7-S-89 Mi INJECTION F'I:;..'OF'IL.E: SURVEY RUN C:OI..LAR/F'EF.:F RUN F'F.'.Oi)UCT I ON PROF'ii_E SUt:,:VFY i:;,'L.iN F'F;.'.ODUCTiON F'I':.:OFi!..E SURVEY I:;.'.UN P I TS RLIN F' ;[ 'i- ;':," R U N i::' P i:) D U C T ]: 0 N P R 0 F I i_ E F;..' U N t:' z;, . . ;,ODUCTION F'I;:OFtLE SUI'?¥1EY RUN F'F,:ODLIC'i"I (:iN F:'ROFI i_E RUN t._F£Ai<DETECTION RUN LEAK I)ETECTION RUN LEAK DETECTION RUN G R / C C L_ R U N 6R/CCL. I';.'. U N i, i, i, i, i.. i... i, i, i, i, " -' i~'; RETURN I:'LEAS~'',_ SIGN RECEIVED BY HAVE: A NICE DAY! SALLY FtO FF ["'C 14 EF.'. ATO- t 529 THE ATTACHED COPY AS REC:EIF'T OF DATA CA:tCO ai'l_A,S' C A i'q,...:O C A M ("j 0 C A M C 0 C A M C: CAHCU C A d C 0 C A f'i C 0 C A M C 0 CAMCO CAMCO DISTRIBUTION ~ CENTRAL FILES ¢- PHILLIPS · ,- CHEVRON PB WELL FIL. E,S' D & M .~. ~ EXTENSION: EXPLORATION ~ BPX ~ EXXON ~-'~'STAI'E OF ALASKA MARATHON. -.--"- TEXACO -,-~' MOBIL . ARCO Alaska, Inc. Post Office Box 400360 Anchorage, Alaska 99510~0360 Te~ephor~e 907 278 1215 SAMPLE TRANSMITTAL TO: STATE OF ALASKA OIL & GAS CONSERVATION COMM. 3001 PORCUPINE DR. ATTN:JOHN BOYLE DATE'2- 17-89 HAND-CARRIED OPERATOR: ARCO NAME' PBU 14-39 SAMPLE TYPE: CORE CHIPS NUMBER OF BOXES:5 SAMPLES SENT: 9513 9515 9517 9577 9578 9587 9588 9598 9599 -9514' -9516'(missing) -9576' (missing) -9586' (missing) -9597' (missing) -9658' SENT BY' J. L. COLLINS UPON RECEIPT OF THESE SAMPLES, PLEASE NOTE ANY DISCREPANCIES AND MAIL A SIGNED COPY OF THIS FORM TO' ARCO ALASKA, INC. P. O. BOX 100360 ANCHORAGE, AK. 99510 ATTN: BAYVlEW GEOLOGIC FACILITY RE C _J~~_~_ DATE' ARCO Alaska, inc. is a Subsidiary of A!,~,r~.tic~'~,ici'~fieb3~D~'~ .; ~ i'~F ARCO ALASKA, INC. P.O. BOX t00368 ANCHORAGE, ALASKA DATE: ~-~9-89 REFERENCE: ARCO DIRECTIONAL DATA ~2-3(-) t2 3t-88 HWD DIRECTI~N~L ZURVEY t4-J7 9-25-88 MWD DIRECTIONAL SURYEY JOB~54 ~4-:58 ~0-2~-88 MWD DIRECTIONAL SURVEY JOB-~65~ 4-39 ~2-8-88 MWD DIRECTIONAL SURVEY .JOB~6~9 ~4-4~ ~t-2~-88 HWD DIRECTIONAL SURVEY JOB~4 PLEASE $I~N AND RETURN THE ATTACHED COF'Y A~.!~"ECEIP'i' OF' DATA. RECEIVED ~Y ....... HAVE A NICE DAY! SALLY HOFFE~.KER AT0-~529 Naska Oil & Gas Con=. Commission Anchorage AF'F'ROV -' . ..... DISTRIBUTION TELECO TELECO TELECO TELECO TELECO CENTRAL FILES CHEVRON D & M '"' EXTENSION EXF'LOI:;,'A'F I ON ..- EXXON MARATHON MOBIL F'HII_I_IF'S F'B WELL F'ILES (2 COI:'IES) R & D SAF'C STATE OF ALASKA TEXACO ~ STATE OF ALASKA 0 ~ I 6 I , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED ~ ABANDONED ~ SERVICE 2. Name of Operator 7. Permit Number ~-138 ARCO Alaska~ Inc. 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50-029-21888 4. Location of well at surface 9. Unit or Lease Name 2539' FNL, 1599' FEL, Sec. 9, T10N, R14E, UM Prudh°e Bay Unit At Top Producing Interval 10. Well Number 171' FSL, 2612' FWL, Sec. 9, T10N, R14E, UM 14-39 At Total Depth 11. Field and Pool 75' FSL, 2527' FWL, 5ec. 9, T10N, R14E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i l Pool 74' RKB ADL 28312 12. Date Spudded11/25/88 13. Date T.D. Reached12/13/88 14. Date Comp., Susp. or Aband.01/09/89* I15' water Depth' if °ffsh°reN/A feet MSL 116' N°' °f c°mpleti°nsl 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth whereSSSV set 21. Thickness of Permafrost 9850'MD/9252'TVD 9802'MD/9207'TVD YES ~ NO []I 1997' feet MD 1900' (approx) 22. Type Electric or Other Logs Run DIL/GR/Cal~ GR/RFT~ DIL/BHCS/GR/SP, CNL/Z-Den/GR/Cal, GCT, CET/CBT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASINGSlZE!WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91,5# H-40 Surf 110' ." t3" 7150~ pol_eset 13-3/8" ?2.0/68.0# L-80/K-55 Surf ~612' 17-1/?" ~nnn ~, cS !!! & 600 s× ¢~.~_ss ¢ r~p ~eb w/250 s× CS ! 9-5/8" 47.0# L_-80 Surf 9467' 1 2-1/4" 6or) ~ (:1 ~ c 7" 29.0# L-80 91~' 9848' ~-1/2" ~?~ ~× Cla~ ~. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) Perforated w/4 spf, 90° Phasing 4-1/2" 9224' 9100' 9391 ' -9413 'MD/8825 ' -8845 'TVD ,,. 9506 '-9543 'MD/8932 ' -8966 'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETc. 9545'-9566'MD/8968'-8987'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9570 ' -9586 'MD/8991 ' -9006 'TVD N/A 9596 '-9612 ' MD/9015 ' -9030 'TVD 9624 ' -9640'MD/9041 '-9056 ' TVD ~,17/.A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE i GAS-OIL RATIO I TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED,~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of l ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. To be submitted when received. / ~:'!i"'~ ~"~IV[D Note: Drilled RR 12/15/88, Perforated well 1/5/89. Tubing ran 1/9/89. ~?,las '_1~ ~Oil & 6as Cons, ''~ ~ohorage Form 10-407 Submit in duplicate Rev. 7-1-80 WC5/078 CONTINUED ON REVERSE SIDE NAME Top Sadlerochit HOT OWC GEOLOGIC MARKERS TRUE VERT. DEPTH MEAS. DEPTH 9495' 9640' 9692' 8921' 9056' 9104~ 30. 31. LIST OF ATTACHMENTS 6188 None 5480 FORMATION TESTS Include interval tested, pressure data, all fluids r~overed and gravity, GOR, and time of each phase. ~epth ~ydro. Press. (ft) (psi) (psi) Shut-In Press. 4675 2281.00 2129.00 4675 2279.27 2133.72 4713 2295.39 2003.85 4760 231 6.36 2107.64 4844 2358.23 2055.70 5135 2502.50 2177.88 5480 2671 . 63 2344.97 5540 2698.87 2369.16 5580 2716. O0 2383. O0 5638 2744.32 2410.51 5720 2788 ~21 2445.46 5781 2811 ,33 2465.56 5850 2846,40 2482.64 5930 2885,52 2523.72 5990 2913 61 2546.80 6070 2951 , O0 2570. 90 4946 2407 29 2095.73 3008,96 2674,00 2599.1 0 2347.00 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Regional Drilling Engineer / Signed_ . Title Date ... 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 welt 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 cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 SUB-SURFACE DIRECTIONAL ~URVEY r-~ UIDANCE F~ONTINUOUS [-~OOL RECEIVED ~]as~ J3il & Gas Cons. Commissio~ "1~ ~chorage Company ARCO ALASKAi INC. Well Name D.S. 14-39 (2539' FNL,I~9~)I FEJ~,S~ 9.TION.R14E.UM) Field/Location PRUDHOE BAY, NORTH ~LOPE. ALA~I<A Job Reference No. Date. 73088 19-DEC-88 Lo_ggg.~L~.; Computed By:. WEST KRUWELL SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA9 INC. D.S. 1~-39 PRUDHOE BAY NORTH SLOPE9 ALASKA SURVEY DATE: 19-0EC-88 ENGINEER: T. WEST METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF SOUTH 23 DEG 3 MIN WEST ARCO ALASKA, INC. D.S. 14-39 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 11-JAN-89 PAGE 1- D~TE OF SURVEY: 19-DEC-88 KELLY BUSHING ELEVATION: 74.00 ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL :D'I 'Z!A:TION AZIMUTH DEPTH DEPTH DEPTH ~D.,?'~#ZN OEG MIN 0.00 0.00 100.00 10.0.00 200.00 ZO0.O0 300.00 300.00 400.00 400.00 500.00 500.00 600.00 600.00 700.00 700.00 800.00 800.00 900.00 900.00 -74. O0 0 0 N 0 0 E 26.00 0 12 S 75 39 W 126.00 0 4 S 75 0 E 226.00 0 0~ N 17 36 E 326.00 0 ~2 S 59 50 E 426.00 0 10 S 9 11 W 526.00 0 8 S 45 15 W 626.00 0 7 S 61 56 E 726.00 0 7 S 12 43 E 826.00 0 10 S 77 31 E 0 4 S 55 39 E 015 N 86 19 E 0 5 S 72 56 E 0 22 S 88 45 E 0 18 S 86 19 E 0 37 S 85 41 E 0 36 S 91 32 E 0 51 S 77 54 E 0 53 S 71 14 E 0 57 S 60 41 E 1000,,00 1000.00 926.00 1100.00 1100.00 1026.00 1200.00 1199.99 1125.99 1300.00 1299.99 1225.99 1400.00 1399.99 1325.99 1500.00 1499.99 1425.99 1600.00 1599.98 1525.98 1700.00 1699.97 1625.97 1800.00 1799.96 1725.96 1900.00 1899.95 1825.95 ZO00.O0 1999.94 1925.94 I 10 2100.00 2099.81 2025.81 4 35 2200.00 2199.24 2125.24 7 2 2300.00 2298.30 2224.30 8 46 2400.00 2396.94 2322.94 10 5 2500.00 2495.20 2421.20 11 11 Z600.00 2593.17 2519.17 12 8 2700.00 2690.63 2616.53 13 47 2800.00 2787o19 2713.19 16 25 2900.00 2882.29 2808.29 19 38 3000000 2975.43 2901.43 22 28 3100.00 3067.43 2993.43 23 18 3200.00 3159.28 3085.28 23 15 3300.00 3251.15 3177.15 23 14 3400.00 3343.06 3269.06 23 13 3500.00 3434.93 3360.93 23 17 3600.00 3526.79 3452.79 23 12 3700.00 3618.74 3544.74 23 12 3800.00 3710.67 3636.67 23 6 3900.00 3802.51 3728.51 23 24 S 20 8 E S 15 45 W S 19 28 W S 21 9 W S 2318 W S 25 35 W S 23 43 W S 20 10 W S 15 25 W S 13 52 W VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEO MIN 0.'00 0.00 0.00 N 0.00 E 0.30 0.81 0.23 S 0.23 W 0.48 0.12 0.36 S 0.36 W 0.44 0.00 0.34 S 0.31 W 0.42 0.09 0.34 S 0.29 W 0.54 0.07 0.48 S 0.25 W 0.88 0.44 0.79 S 0.40 W 0.90 0.51 0.82 S 0.38 W 1.15 0.26 1.14 S 0.26 W 1.14 0.45 1.17 S 0.15 W 1.20 0.00 1.37 S 0.16 E 1.10 0.00 1.33 S 0.31 E 1.03 0.00 1.41 S 0.68 E 0.82 0.02 1.36 S 1.09 E 0.67 0.32 1.44 S 1.66 E 0.33 0.00 1.44 S 2.55 E 0.05 0.00 1.60 S 3.64 E -0.26 0.04 1.81. S 4.94 E -0.46 0.05 2.23 S 6.39 E -0.43 0.41 2.87 S 7.85 E 0.00 N 0 0 E 0.33 S 44 1I W 0.51 S 44 44 W 0.46 S 41 45 W 0.44 S 40 21 W 0.54 S 27 9 W 0.88 S 26 37 W 0.90 S 25 3 W 1.17 S IZ 43 W 1.18 S 7 18 W 0.20 1.93 4.02 S 4.67 3.79 8.66 S 15.18 1.64 18.65 S 28.83 1.44 31.48 S 45.22 1.40 46.65 S 63.82 0.17 63.56 S 83.84 1.54 81.71 S 106.19 2.20 102.43 S 132.03 3.13 127.18 S 162.55 3.54 157.08 S 1.38 S 6 30 E 1.36 S 12 59 E 1.56 S 25 41 E 1.74 S 38 41 E 2.20 S 49 6 E 2.93 S 60 32 E 3.97 S 66 15 E 5.26 S 69 49 E 6.77 S 70 48 E 8.36 S 69 54 E S 13 31 W 198.41 1.69 S 13 36 W 237.08 0.12 S 14 15 W 276.11 0.19 S 14 23 W 315.14 0.11 S 14 18 W 354.10 0.14 S 14 29 W 393.16 0.16 S 14 38 W 432.24 0.45 S 14 53 W 471.15 0.34' S 15 25 W 510.12 0.57~ S 15 41 W 549.34 0.52 8.92 E 9.79 S 65 45 E 8.43 E 12.08 S 46 12 E 5.06 E 19.33 S 15 11 E 0.34 E 31.48 S 0 36 E 5.87 W 47.01 S 7 10 W ) 13.62 W 65.01 S 12 5 W 22.10 W 84.65 S 15 7 W 30.49 W 106.88 S 16 34 W 38.30 W 132.83 S 16 45 W 46.01 W 163.68 S 16 19 W 192.40 S 54.59 W 199.99 S 15 50 W 230.51 S 63.77 W 239.17 S 15 27 W 268.88 S 73.29 W 278.69 S 15 14 W 307.13 S 83.09 W 318.17 S 15 8 W 345.32 S 92.85 W 357.58 S 15 3 W 383.58 S 102.66 W 397.08 S 14 59 W 421.82 S 112.62 W 436.59 S 14 56 W 459.83 S 122.66 W 475.91 S 14 56 W 497.81 S 132.93 W 515.25 S 14 57 W 535.94 S 143.51 W 554.82 S 14 59 W ARCO ALASKA~p INC. D.S. 14-39 PRUDHOE BAY NORTH SLOPE~ ALASKA COMPUTATION DATE: 11-JAN-B9 PAGE 2 - DATE OF SURVEY: 19-DEC-88 KELLY BUSHING ELEVATION: 74.00 FT ' ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUe. SUB-SEA ; , COURSE MEASURED VERTICAL VERTICAL DE¥IATION AZIMUTH DEPTH DEPTH DEPTH 'O"EG",.HIN , DEG MIN 4000.00 3894.32 3920.32 ~ 23' 19 4100.00 3986.17 3912.17 ~i23 15 4Z00.00 4078.08 4004.08 23 6 4300.00 4170.12 4096.12 22 58 4400°00 4262.23 4188.23 22 48: 4500.00 4354.52 4280.52 22 27 4600.00 4447.13 4373.13 21 5Z 4700.00 4540.00 4466.00 21 41 4800.00 4632.92 4558.92 21 35 4900.00 4726.03 4652.03 21 12 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET OEG MIN S 16 17 W 588.67 0.15 S 16 40 W 627.97 0.38 $ 16 45 W 667.12 0.22 S 17 11 W 706.01 0.21 S 17 34 W 744.75 0.45 S 18 10 W 783.11 0.69 S 18 16 W 820.70 0.14 S 19 29 W 857.67 0.73 S 20 30 W 894.56 0.37 S 20 57 W 931.01 0.38 574.02 S 154.45 W 594.44 S 15 3 W 611.95 S 165.70 W 633.98 S 15 9 W 649.66 S 177.04 W 673.36 S 15 14 W 687.08 S 188.44 W 712.45 S 15 20 W 724.23 S 200.09 W 751.36 S 15 26 W 760.88 S 211.92 W 789.84 S 15 33 W 796.71 S 223.73 W 827.53 S 15 41 W 831.83 S 235.61 W 864.55 S 15 48 W 866.54 S 248.27 W 901.40 S 15 59 W 900.66 S 261.19 W 937.76 S 16 10 W 5000.00 4819.48 4745.48 20 34 5100.00 4913.13 4839.13 20 37 5200.00 5006.35 4932.35 21 50 5300.00 5099.09 5025.09 21 56 5400.00 5191.79 5117.79 22 17 5500.00 5283.94 5209.94 23 26 5600.00 5375.38 5301.38 24 9 5700.00 5466.48 5392.48 24 31 5800.00 5557.41 5483.41 24 40 5900.00 5648.14 5574.14 25 7 S 21 23 W 966.61 S 22 2 W 1001.65 S 20 28 W 1037.83 S 20 6 W 1075.18 S 21 13 W 1112.66 S 21 0 W 1151.45 S 20 55 W 1191.91 S 21 34 W 1233.14 S 21 8 W 1274.73 S 20 20 W 1316.75 0.23 0.85 0.99 0.67 0.92 1 0.53 0.27 0.53 0.85 933.87 S 274.04 W 973.25 S 16 21 W 966.43 S 287.02 W 1008.15 S 16 32 W 1000.11 S 300.26 W 1044.Z1 S 16 42 W 1035.24. S 313.11 W 1081.55 S 16 49 W 1070.34 S 326.34 W 1118.98 S 16 57 W 1106.50 S 340.43 W 1157.69 S 17 6 W 1144.35 S 354.81 W 1198.09 S 17 13 W 1182.79. S 369.77 W 1239.24 S 17 21 W 1221.52 S 384.99 W 1280.75 S 17 29 W 1260.84 S 399.89 W 1312.74 S 17 35 W 6000.00 5738.46 5664.46 25 36 6100.00 5828.60 5754.60 25 40 6200.00 5918.75 5844.75 25 35 6300.00 6008.97 5934.97 25 36 6400.00 6099.14 6025.14 25 33 6500.00 6189.35 6115.35 25 34 6600.00 6279.54 6205.54 25 36 6700.00 6369.74 6295.74 25 29 6800.00 6460.05 6386.05 25 22 6900.00 6550.40 6476.40 25 21 S 19 26 W 1359.59 S 19 5 W 1402.81 S 19 23 W 1445.99 S 19 43 W 1489.04 S 19 44 W 1532.21 S 19 37 W 1575.28 S 19 23 W 1618.39 S 19 29 W 1661.47 S 19 37 W 1704.34 S 19 52 W 1747.14 0.41 0.17 0.28 0.24 0.17 0.02 0.24 0.20 0.21 0.33 1301.20 S 414.47 W 1365.61 S 17 40 W 1342.10 S 428.73 W 1408.91 S 17 ~2 W 1382.9~ S 443.02 W 1452.17 S 17 45 W 1423.59 S 457.43 W 1495.Z8 S 17 48 W 1464.29 S 472.05 W 1538.50 S 17 52 W 1504.91 S 486.59 W 1581.62 S 17 55 W 1545.63 S 501.00 W 1624.80 S 17 57 W 1586.34 S 515.35 W 1667.95 S 17 59 W 1626.81 S 529.73 W 1710.88 S 18 2 W 1667.16 S 544.20 W 1753.74 S 18 4 W 7000.00 6640.81 6566.81 25 17 7100.00 6731.24 6657.24 25 9 7200.00 6821.88 6747.88 24 50 7300.00 6912.69 6838.69 24 45 7400.00 7003.43 6929.43 24 52 7500.00 7094.08 7020.08 25 6 7600.00 7184.58 7110.58 25 17 7700.00 7274.94 7200.94 25 25 7800.00 7365.28 7291.28 25 22 7900.00 7455.68 7381.68 25 14 S 20 44 W 1789.82 S 21 20 W 1832..47 S 22 15 W 1874.71 S 22 58 W 1916.58 S 23 I W 1958.60 S 23 23 W 2000.81 S 23 43 W 2043.37 S 24 3 W 2086.20 S 24 17 W 2129.08 S 24 3Z W 2171.80 0.31 0.47 0.61 0.21 0.47 0.49 O.ZZ 0.03 0.23 0~16 1707.25 S 559.01 W 1796.44 S 18 7 W 1747.07 S 574.34 W 1839.06 S 18 11 W 1786.31 S 590.01 W 1881.23 S 18 16 W 1824.95 S 606.15 W 1922.98 S 18 ZZ W 1863.63 S 622.58 W 1964.87 S 18 28 W 1902.42 S 639.22 W 2006.94 S 18 34 W 1941.43 S 656.22 W 2049.33 S 18 40 W 1980.59 S 673.58 W 2092.00 S 18 46 W 2019.72 S 691.14 W 2134.70 S 18 53 W 2058.63 S 708.81 W 2177.24 S 18 59 W ARCO ALASKAt INC. D.S. 1~-39 PRUOHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 11-JAN-89 PAGE 3' DATE OF SURVEY: 19-DEC-88 KELLY BUSHING ELEVATION:* 74.00 FT* ENGINEER: To WEST INTERPOLATED VALUES FOR EVEN lO0 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEViATiON AZIRUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIRUTH OEPTH DEPTH OEPTH DE6:!~:#IN DEG MIN FEET OEG/IO0 FEET FEET FEET DEG 8000.00 7546.16 7472.16 25 7 S 25 12 W 2214.38 8100o00 7636.89 7562.89 24 36 S 26 3 W 2256.38 8200.00 7727.96 7653.96 24 8 S 26 27 W 2297.62 8300.00 7819.38 7745.38 23 41 S 28 36 W 2338.02 8400°00 7911.18 7837.18 Z3 I S 30 50 W 2377.40 8500°00 8003.39 7929.39 22 34 S 33 47 W 2415.60 8600.00 8095.83 8021.83 22 16 S 37 5 W 2452.84 8700.00 8188.40 8114.40 22 15 S 39 11 W 2489.33 8800.00 8280.91 8206.92 22 20 S 39 30 W 2525.75 8'900.00 8373.36 8299.36 22 32 S 39 51 W 2562.31 9000.00 8465.62 8391.62 22 50 9100.00 8557.65 8483.65 23 19 9200.00 8649.41 8575.41 13 30 9.300.00 8741.32 8667.32 23 3 9400.00 8833.40 8759.40 22 49 9500.00 8925.76 8851.76 21 58 9600°00 9018.64 8944.64 21 37 9700-00 9111.71 9037.71 Z1 9 9800.00 9205.10 9131.10 20 52 9850.00 9251.82 9177.82 20 52 S 40 15 W 2599.19 S 40 20 W 2636.53 S 40 25 W 2674.51 S 41 38 W 2711.97 S 42 53 W 2748.79 S 42 26 W 2784.87 S 41 ~,8 W 2819.90 S 41 23 W 2854.58 S 40 49 W 2888.59 S 40 49 W 2905.55 0.52 0.50 0.80 1.15 1.19 I .29 1.23 0.34 0.14 0.31 0.23 1.14 2 0.58 0.24 1.21 0.17 0.53 0.00 0.00 2097.29 S 726.71 W 2219.62 S 19 6 W 2135.19 S 744.91 W 2261.40 S 19 13 W 2172.25 S 763.15 W 2302.40 S 19 21 W 2208.19 S 781.85 W 2342.52 S 19 29 W / 2242.62 S 801.53 W 2381.55 S 19 40 W , 2275.36 S 822.14 W 2419.33 S 19 51 W 2306.42 S 844.27 W 2456.08 S ZO 6 W 2336.10 S 867.71 W 2492.04 S 20 22 W 2365.43 S 891.80 W 2527.95 S ZO 39 W 2394.80 S 916.16 W 2564.06 S 20 56 W 2424.31 S 940.99 W 2600.53 S 11 12 W 2454.11 S 966.31 W 2637.50 S 21 29 W 2484.46 S 992.01 W 2675.19 S 21 45 W 2514.14 S 1017.93 W 2712.39 S ZZ 2 W 2542.98 S 1044.18 W 2749.01 S 22 19 W 2571.11 S 1070.21 W 2764.95 S 22 35 W 2598.61 S 1095.07 W 2819.91 S 22 51 W 2625.98 S 1119.32 W 2854.58 S 23 5 W 2652.95 S 1142.79 W 2888.62 S 23 18 W 2666.43 S 1154.43 W 2905.61 S 23 24 W ARCO ALASKA, INC. D.S. 14-39 PRUDHOE BAY NORTH SLOPEp ALASKA COMPUTATION DATE: 11-JAN-89 PASE 4' DATE OF SURVEY: 19-DEC-88 KELLY BUSHING ELEVATION: 74.00 FT . ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA : COURSE MEASURED VERTICAL VERTICAL 0E:~ATION AZIMUTH DEPTH DEPTH DEPTH DEG/!::#IN DEG MIN 0.00 0-00 -74.00 O 0 1000.00 1000.00 926.00 0 4 ZO00.O0 1999.94 1925.94 I 10 3000.00 2975.43 2901.43 22 38 4000.00 3894.32 3820.32 23 19 5000.00 4819.48 4745.48 ZO 34 6000.00 5738.46 5664.46 25 36 7000.00 6640.81 6566.8! 25 17 8000.00 7546.16 7472.16 25 7 9000.00 8465.62 8391.62 22 50 9850.00 9251.82 9177.82 20 52 VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 0 0 E 0.00 S 55 39 E 1.20 S 2O B E 0.20 S 13 31 W 198.¢1 S 16 17 W 588.67 S 21 23 W 966.61 S 19 26 W 1359.59 S 20 44 W 1789.82 S 25 12 W 2214.38 S 40 15 W 2599.19 S 40 49 W 2905.55 0.00 0.00 1.93 1.69 0.15 0.23 0.41 0.31 0.52 0.23 0.00 N 0.00 E 0.00 N 0 0 E 1.37 S 0.16 E 1.38 S 6 30 E 4.02 S 8.92 E 9.79 S 65 45 E 192.40 S 54.59 W 199.99 S 15 50 W ) 574.02 S 154.45 W 594.44 S 15 3 W · 933.87 S 274.04 W 973.25 S 16 Z1 W 1301.20 S 414.47 W 1365.61 S 17 40 W 1707.25 S 559.01 W 1796.44 S 18 7 W 2097.29 S 726.71 W 2219.62 S 19 6 W 2424.31 S 92,0.9:9 W 2600.53 S 21 12 W 0.00 2666.43 S 1154.43 W 2905.61 S 23 24 W ARCO ALASKA, INCo D.S. 14-39 PRUOHOE BAY NORTH SLOPE9 ALASKA COMPUTATION DATE: 1t-JAN-89 PAGE 5- DATE OF SURVEY: 19-DEC-SB KELLY BUSHING ELEVATION: 74.00 FT ' ENGINEER: T. WES'T INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE qEASURED VERTICAL VERTICAL -I)EVl~ATZON AZIMUTH DEPTH DEPTH DEPTH OEG, H'IN DEG MIN 0.00 0.00 74.00 74.00 174. O0 174.00 274.00 274.00 374.00 374.00 474.00 474.00 574.00 574.00 674.00 674.00 774.00 774.00 874.00 874.00 -74.00 0 0 N 0 0 E 0.00 0 9.' S 89 47 W 100.00 0 4 S 15 51 E 700.00 0 0 N 24 0 E 300.00 ,0 0~' N 79 8 E ~'00.00 0 7 S 7 1Z E 500.00 0 13 S 35 21 W 600.00 0 2 N 55 11 E 700.00 0 14 S 6 39 E 800.00 0 5 N 48 20 E VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 0.00 0.00 0.00 N 0.00 E 0.27 0.00 0.23 S 0.15 W 0.47 0.30 0.34 S 0.38 W 0.44 0.00 0.35 S 0.31 W 0.42 0.00 0.33 S 0.30 W 0.47 0.12. 0.41 S 0.24 W 0.80 0.24 0.72 S 0.34 W 0.91 0.7.8 0.82. S 0.42 W 1.08 0.16 1.06 5 0.27 W 1.17 0.37 1.18 S 0.21 W 0.00 N 0 0 E 0.27 S 34 0 W 0.51 S 48 7 W _ 0.47 S 41 28 W ~ 0.45 S 41 28 W 0.48 S 30 24 W 0.80 S 25 9 W 0.92 S 27 0 W 1.09 S 14 11 W 1.20 S 9 55 W 974.00 974.00 900.00 1074.00 1074.00 1000.00 1174.01 1174.00 1100.00 1274.01 1274.00 1200.00 1374.01 1374.00 1300.00 1474.01 1474.00 1400.00 1574.02 1574.00 1500.00 1674.02 1674.00 1600.00 1774o04 1774.00 1700.00 1874.05 1874.00 1800.00 012 S 45 0 E 0 9 N 54 54 0 8 S 65 10 E 0 20 N 83 49 0 15 S 84 25 0 36 S 89 41 0 32 S 8046 0 48 S 79 45 0 49 S 72 50 0 55 S 63 35 1.18 0.54 1.32 S 0.11 1.16 0.87 1.35 S 0.21 1.03 0.55 1.39 S 0.63 0.89 0.00 1.36 S 0.92 0.71 0.00 1.43 S 1.54 0.43 0.00 1.43 S 2.27 0.11 0.30 1.56 S 3.38 -0.19 0.09 1.74. S 4.57 -0.42 0.55 2.11 S 6.02 -0.47 0.00 2.67 S 7.47 1.33 S 4 41 E 1.36 S 8 55 E 1.53 S 2~* 31 E 1.65 S 3& 8 E 2.10 S 47 3 E 2.69 S 57 50 E 3.72 S 65 11 E 4.89 S 69 8 E 6.38 S 70 43 E 7.93 S 70 18 E 1974.06 1974.00 1900.00 0 54 Z074o13 2074.00 2000.00 3 40 2174.58 2174.00 2100.00 6 41 2275.43 2274.00 2Z00.00 8 16 2376.71 2374.00 2300.00 9 47 2478.40 2474.00 2400.00 11 5 2580.41 2574.00 2500.00 11 51 Z68Z.89 Z674.0~ 2600.00 13 29 2786.26 2774.00 2700.00 16 0 2891.20 2874.00 2800.00 19 20 S 34 45 E S 10 34 W S 19 3 W S ZO 37 W S 22 49 W S 25 21 W S 24 31 W S ZO 56 W S 15 51W S 13 55 W -0.09 0.89 3.61 S 2.82 5.08 6.84 S 12.15 1.40 15.78 S 25.18 2.56 28.07 S 41.20 1.56 42.94 S 59.65 0.95 59.79 S 79.77 1.79 78.00 S 102.16 2.13 98.65 S 128.21 3.13 123.47 S 159.62 3.50 154.20 S 8.71 E 9.43 S 67 31 E 8.87 E 11.20 S 52 21 E 6.07 E 16.91 S 21 I E 1.64 E 28.11 S 3 21 E 4.29 W 43.16 S 5 42 W 11.82 W 60.95 S 11 11 W 20.43 W 80.63 S 14 40 W 29.07 W 102.85 S 16 25 W 37.27 W 128.98 S 16 47 W 45.29 W 160.71 S 16 22 W 2998.45 Z974.00 2900.00 22 37 3107.16 3074.00 3000.00 23 18 3216.02 3174.00 3100.00 23 15 3324.86 3274.00 3200.00 23 12 3433.67 33T4.00 3300.00 23 15 3542.54 3474.00 3400.00 23 18 3651.34 3574.00 3500.00 23 6 3760.12 3674.00 3600.00 23 9 3868.93 37T4.00 3700.00 23 25 3977.87 3874.00 3800.00 23 19 S 13 32 W 197.83 1.75 S 13 39 W 239.87 0.15 S 14 20 W 282.37 0.10 S 14 22 W 324.83 0.10 S 14 20 W 367.Z4 0.09 S 14 37 W 409.80 0,13 S 14 49 W 452.21 0,38 S 15 10 W 494.59 0'45 S 15 30 W 537.10 0.31 S 16 12 W 579.97 0~i20 191.82 S 54.45 W 199.40 S 15 50 W 233.26 S 64.44 W 242.00 S 15 26 W 275.02 S 74.85 W 285.02 S 15 13 W 316.62 S 85.52 W 327.97 S 15 6 W 358.19 S 96.14 W 370.87 S 15 I W 399.87 S 106.89 W 413.91 S 14 57 W 441.34 S 117.75 W 456.78 S 14 56 W 482.70 S 128.80 W 499.59 S 14 56 W 524.05 S 140.19 W 542.48 S 14 58 W 565.61 S 152-.00 W 585.68 S 15 2 W ARCO ALASKAt INC. D.S, 14-39 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 11-JAN-89 PAGE 6 ' DATE OF SURVEY: 19-0EC-88 KELLY BUSHING ELEVATION: 74.00 FT ' ENGINEER: T. WEST INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH qEASUREO VERTICAL VERTICAL 'BE¥T~TIDN AZIMUTH OEPTH OEPTH DEPTH O,~G' NIN OEG MIN 4086.76 .3974.00 3900.00 23 16 4195.56 4074.00 4000.00 23 6 4304.22 4174.00 4100.00 22 58 4412.76 /+274.00 4200.00 22 45 4521.07 4374.00 4300.00 22 20 4628.95 4474.00 4r+O0. O0 21 48 4736.60 /+574.00 4500.00 21 43 4844.15 4674.00 4600.00 21 25 4951.39 4774.00 4700.00 20 50 5058.21 4874.00 4~00.00 20 27 VERTICAL OOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 5165.19 4974.00 4900.00 21 28 5272.94 5074.00 5000.00 21 59 5380.79 5174.00 5100.00 22 8 5489.16 5274.00 5200.00 23 19 5598.49 5374.00 5300.00 24 9 5708.27 5474.00 5400.00 24 32 5818.26 5574.00 5500.00 24 43 5928.59 5674.00 5600.00 25 19 6039.42 5774.00 5700.00 25 40 6150.37 5874.00 5800.00 25 38 S 16 39 W 622.77 S 16 45 W 665.39 S 17 13 W 707.64 S 17 39 W 749.67 S 18 14 W 791.11 S 18 20 W 83'1.43 S 19 56 W 871.18 S ZO 43 W 910.73 S 21 9 W 949.44 S 21 47 W 986.99 6261.24 5974.00 5900.00 25 30 6372.13 6074.00 6000.00 25 36 6482.98 6174.00 6100.00 25 33 6593.86 6274.00 6200.00 25 36 6706.72 6374.00 6300.00 25 29 6815.44 6474.00 6400.00 25 21 6926.11 6574.00 6500.00 25 18 7036.72 6674.00 6600.00 25 17 7147.21 6774.00 6700.00 24 59 7257.40 6874.00 6800.00 24 42 S 21 18 W 1024.97 S 19 57 W 1065.07 S 20 59 W 1105.40 S 21 6 W 1147.15 S 20 55 W 1191.29 S 21 35 W 1236.57 S 20 58 W 1282.35 S 20 4 W 1328.93 S 19 12 W 1376.61 S 19 18 W 1424.57 7367.56 6974.00 6900.00 24 53 7477.82 7074.00 7000.00 25 4 7588.30 7174.00 7100.00 25 17 7698.96 7274.00 7200.00 25 25 7809.66 7374.00 7300.00 25 21 7920.25 7474.00 7400.00 25 14 8030.73 7574.00 7500.00 24 58 8140.79 7674.00 7600.00 24 26 8250.40 7774.00 7700.00 23 53 8359.56 7874.00 7800.00 23 18 S 19 32 W 1472.34 S 19 44 W 1520.19 S 19 39 W 1567.94 S 19 23 W 1615.75 S 19 29 W 1663.50 S 19 39 W 1710.94 S 20 I W 1758.29 S 20 59 W 1~05.50 S 21 43 W 1852.47 S 22 45 W 1898.75 S 22 59 W 1944.95 S 23 19 W 1991.41 S 23 41 W 2038.36 S 24 2 W 2085.75 S 24 19 W 2133.22 S 24 38 W 2180.43 S 25 2~ W 2227.37 S 26 9 W 2273.29 S 27 27 W 2318.08 S 29 57 W 2361.63 0.41 0.17 0.23 0.44 0.51 0.31 0.20 0.57 0.92 0.50 606.94 S 164.20 W 628.75 S 15 8 W 648.00 S 176.54 W 671.62 S 15 14 W 688.65 S 138.92 W 714.10 S 15 20 W 728.93 S 201.58 W 756.29 S 15 27 W .....) 768.50 S 214.43 W 797.86 S 15 35 W 806.93 S 227.12 W 838.28 S 15 43 W 844.57 S 2/+0.17 W 878.06 S 15 52 W 881.69 S 253.96 W 917.53 S 16 4 W 917.86 S 267.81 W 956.13 S 16 15 W 952.83 S 281.55 W 993.56 S 16 27 W 2.05 0.57 0.82 1.27 0.51 0.22 0.58 0.73 0.24 0.24 988.09 S 295.69 W 1031.38 S 16 39 W 1025.73 S 309.6/+ W 1071.44 S 16 47 W 1063.56 S 323.72 W 1111.74 S 16 55 W 1102.48 S 338.88 W 1153.39 S 17 5 W 1143.77 S 354.59 W 1197.48 S 17 13 W 1185.98 S 371.04 W 1242.67 S 17 22 W 1228.63 S 387.74 W 1288.36 S 17 30 W 1272.29. S 404.10 W 1334.92 S 17 37 W 1317.29 S 420.12 W 1382.66 S 17 41 W 1362.70 S 435.90 W 1430.72 S 17 /+4 W 0.39 0.35 0.03 0.25 0.18 0.16 0.42 0.29 0.54 0.37 1407.84 S 451.81 W 1478.56 S 17 47 W 1452.96 S 467.98 W 1526.47 S 17 51 W 1497.99 S 484.12 W 1574.28 S 17 54 W 1543.13 S 500.12 W 1622.15 S 17 57 W 1588.26 S 516.03 W 1669.98 S 17 59 W 1633.04 S 531.96 W 1717.50 S 18 2 W 1677.67 S 548.01 W 1764.90 S 18 5 W 1721.91 S 564.60 W 1812.11 S 18 9 W 1765.68 S 581.69 W 1859.03 S 18 14 W 1808.52 S 599.22 W 1905.21 S 18 19 W 0.38 0.63 0.27 0.03 0.25 0.21 0.68 ~.38 1.15 1851.06 S 617.24 W 1951.26 S 18 26 W 1893.78 S 635.49 W 1997.57 S 18 32 W 1936.85 S 654.21 W 2044.35 S 18 39 W 1980.18 S 673.40 W 2091.55 S 18 46 W 2023.49 S 692.84 W 2138.82 S 13 54 W 2066.48 S 712.40 W 2185.83 S 19 I W 2109.04 S 732.28 W 2232.55 S 19 8 W 2150.39 S 752.36 W 2278.21 S 19 17 W 2190.52 S 772.46 W 2322.73 S 1'*) 25 W 2228.90 S 793.48 W 2365.93 S 19 35 W ARCO ALASKA, INC. D.S. 14-3~ PRUDHOE BAY NORTH SLOPEr ALASKA COMPUTATION DATE: 11-JAN-B9 PAGE DATE DF SURVEY: 19-DEC-~$ KELLY BUSHING ELEVATION: 74.00 FT' ENGINEER: T. WEST INTERPOLATEO VALUES FOR EVEN 100 FEET OF SUB-SEA OEPTH TRUE SUB-SEA ,i: ~,, COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DE¥~:ATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAS'T/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG"iMIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8468.16 7974.00 7900.00 .:22 40 S 32 45 W 2403.54 8576.,0 8074.00 8000'00:'22 20 S 36 20 W 2444.14 868,.,, 817,.00 8100.00 22 13 S 39 I W 2,83.67 8792.52 827,.00 8200.00 :22 20 S 39 29 W 2523.02 8900.70 837,.00 8300.00 22 32' $ 39 51 W 2562.57 9009.09 8,T,.O0 8'00.00 22 51 S '0 17 W 2602.56 9117.81 8574.00 8500.00 23 23 S ,0 11W 2643.28 9226.78 867,.00 8600.00 23 13 S ,0 52 W 268,.62 9335.51 8774.00 8700.00 22 59 S ,2 8 W 2725.13 9,4,.0, 887,.00 8800.00 22 ,1 S 'Z 52 W 2764.82 9551.96 8974.00 8900.00 21 43 9659.53 9074.00 9000.00 21 26 9850.00 9251.82 9177.82 20 52 S 42 5 W 2803.11 S 41 25 W 2840.63 S 40 49 W 2905.55 1.32 1.32 0.47 0.12 0.31 0.19 0.00 0.68 0.71 0.69 0.41 0.93 0.00 2265.11 S 815.43 W 2407.42 S 19 47 W 2299.2, S 838.91 W 2447.51 S 20 2 W 2331.53 S 864.00 W 2486.46 S 20 19 W 2363.23 S 889.99 W 2525.26 S 20 38 W ~, 2395.00 S 916.33 W 2564.31 S 20 56 W 2427.01 S 943.27 W 2603.86 S 21 14 W 2459.50 S 970.88 W 2644.19 S 21 32 W 2492.50 S 998.92 W 2685.22 S 21 50 W 2524.49 S 1027.20 W 2725.47 S 22 8 W 2555.46 S 1055.79 W 2764.98 S 22 26 W 2585.,1 S 1083.21 W 2803.15 S 22 43 W 261,.95 S 1109.61 W 2840.63 S ZZ 59 W 2666.43 S 1154.43 W 2905.61 S 23 24 W ARCO ALASKA, INC. O.S. 14-39 PRUDHOE 13 AY NORTH SLOPE, ALASKA MARKER SAG SHUBL[K TOP SADLEROCHIT ZONE 4~ HOT OWC ZONE 3 LAST GCT READING PBTD TD COMPUTATION OATE: 11-JAN-89 PAGE DaTE OF SURVEY: 19-0EC-88 KELLY BUSHING ELEVATION: 74.00 FT , ENGINEER: T. WEST INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 2539' FNLt 1599' FEL9 SEC99 TION9 R14EgUM MEASURED DEPTH TVO BELOW KB FROM K8 SUe-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9391.00 8825.10 8751.10 2540.41 S 1041.81 W 9414.00 8846.30 8772.30 2546.95 S 1047.88 W 9495.00 8921.12 8847.12 2569.73 S 1068.95 W 9495.00 8921.12 8847.12 2569.73 S 1068.95 W 9640.00 9055.83 8981.83 2609.59 S 1104.86 W 9692.00 9104.25 9030.25 2623.81 S 1117.41 W 9736.00 9145.30 9071.30 2635.70 S 1127.86 W 9752.90 9161.09 9087.09 2640.25 S 1131.82 W 9802.00 9206.97 9132.97 2653.49 S 1143.26 W 9850.00 9251.82 9177.82 2666.43 S 1154.63 W ARCO ALASKA, INC. D.S. 14-39 PRUDHOE BAY NORTH SLOPEr ALASKA MARKER SAG SHUBLIK TOP SADLEROCHIT ZONE 4 HOT OWC ZONE 3 LAST GCT READING PBTD TD COMPUTATION DATE: 11-JAN-89 PAGE 9 ' DATE OF SURVEY: 19-DEC-88 KELLY BUSHING ELEVATION: 74.00 FT '. ENGINEER: T. WEST ************ STRATIGRAPHIC SUMMARY SURFACE LOCATION = 2539' FNL, 1599' FELt SEC9, TION, R14E,UM NEA~URED DEPTH ..... ELOW KB TVO FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 9391.00 9414.00 9495.00 9495.00 9640.00 9692.00 9736.00 9752.90 9802.00 9850.00 8825.10 8751.10 8846.30 8772.30 8921.12 8847.12 8921.12 8847.12 9055.83 8981.83 9104.25 9030.25 9145.30 9071.30 9161.09 9087.09 9206.97 9132.97 9251.82 9177.82 2540. ~1 S 2546.95 S 2569.73 S 2569.73 S 2609.59 $ 2623.81 S 2635.70 S 2640.25 S 2653.49 S 2 666.43 S 1041.81 W 1047.88 W 1068.95 W 1068.95 W 1104.86 W 1117.41 W 1127.86 W 1131.BZ W 1143.Z6 W 1154.43 W FINAL WELL LOCATION AT TO: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH OEP'TH DEPTH 9850.00 9251.82 9177.8Z HORIZONTAL DEPARTURE OISTANCE AZIMUTH FEET DEG MIN 2905.61 S 23 24 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA. INC. WELL O.S. 14-39 FIELD PRUOHOE BAY COUNTRY USA RUN ONE BATE LOOOEO 19 - OEC - 88 REFERENCE 73088 WELL'''D.S. 14-39 (2'539' FNL, 1599' FEL, SEC 9, TION, R14E, UM) HORIZONTAL PROJECTION NORTH 1000 - I i~O0 -2OOO REF 73088 SCALE = 1/500 IN/FT -+m4.+.~...~-4..m~-.....~...~-..~.+-~..~-~-.~...-~...:-~..~..:~..~-.i_,.~......~..;_.~...~q...~...?'....~_....~..~...;...~...~....!...:...i i ~ 7i'Z ~"]'~ ....... ~"'~'";"~: ....... i'T'?"7-r" "'7":'"r"71---':'-'7"~ .... ~:;]~;: ~ ~:~'~:~ ~'~l~i~ ~ :~'~ : : ~ :[ :.. ' :. :~ : ~::,:~ r; T . . ?..-? ....... v-.t .... d-.~.++--~.+.~...~-~ ..... +-+-..~-~..~,4.4-+~---.4...~...~...;-4-~...~..+..~... 4...;...~...;..+..~...~...~...~ ...... ~...; ...... ~...~ ....... ~...~...: ........... ~ ....... ;...~...; ....... : ....... L.~...~...:....L4...L.L.L.; ...... -~-~-4-+4--+.-~-~-'~.~-~--~--~-~-.-~-.~-~-.~-~.-;-~-4--.~...~-~-.&.-~--~..-~.-.~ .~-..~-..~-.-;. ~-- ~ ~ ;..4-.-~...~...L.~ ! 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T"?"?-'-?-7-?'"77"' r~"7'"~T-7'"7 .... ~' "~'7?'~T~'~'?'t'TV~' ~"~T~'-TT"7 ~'~?'T"I'"7'T"7"V' '"?i-7"7"t'"7'7"7"~ ....... 7"7"7"7"1''7'v''7''; ...... 7": ...... r'T'7";~'7"7'' '"7'~'"7'7"I'"7'7"7"~ -L~:l:~ - i ~ - 1000 -SOO 0 SOO 1000 I SOO WELL' "D.S. 14-39 VERTICAL PROJECTION (2'539' FNL, 1599' FEL, SEC 9, TION, R14E, UM) 209. PRO~ECTION ON VERT~C~ PLANE ~0~. - ~3. ~ED IN VER?IC~ ~PT~ HORIZ SCALE = !/500 IN/FT · . WELL LOG ~TORY PAGE I of LOG LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL -- (dual induction log) CNFD (compensated neutron density) (compensated neutron formation/ litho-density) CFD (compensated formation density) BHC/SL ' ' (borehole compenSate~l sonic) · _ . . · · . LSS (long7 spaced sonic) . . · SSS (short spaced sonic) CYB ( cyb erlook) .. GCT (groscopic survey) DIPMETER SAMPLES: Require~t/-:"~ye) 'Comments: ! no Date Received: STATE OF ALASKA AL, ...... ~A OILAND GAS CONSERVATION COMMIb,.,ON REPORT OF SUNDRY WELL OPERATIONS ~' 1. Operations performed: Operation shutdown __ ·Stimulate __ Plugging m Pedorate m Pull tubing ~ Alter casing __ Repair well ~ Pull tubing ~ Other Complete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. BoX 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2539' FNL, 1599' FEL, Sec. 9, TION, R14E, UM At top of productive interval 171' FSL, 2612' F~L, Sec. 9, TION, R14E, UM At effective depth 88' FSL, 2538' FWL, Sec. 9, TION, R14E, UM At total depth 75' FSL, 2.527' FWL, Sec. 9, TION, R14E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) RKB 74' 7. Unit or Property name Prudhoe Bay Unit 8. Well number 14-39 9. Permit number/approval number 88-138/9-011 10. APl number 50-- 029-21888 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 9850 'MD feet 925 2 ' TVD feet 9802 ' MD feet 9207 ' TVD feet Plugs (measured) None · Junk(measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size 80 ' 20" 3579 ' 13-3/8" 9436 ' 9-5/8" 695 ' 7" None Cemented Measured depth True vertical depth 2150# Poleset 1lO'MD 110'TVD 2000 sx CS III & 3612'MD 3538'TVD 600 sx Class G - Top job w/250 sx CS I 600 sx Cl ass G 9467'MD 8895'TVD 325 sx Class G 9155'-9848'MD 8608 '-9250 'TVD true vertical None Tubing (size, grade, and measured depth) 4-1/2", L-80, tbg w/tail ~ 9224' es dql t , Pa¢,k~rsancJ.~,~SV,(typ~e~r~ ~.~/( ~t_hs)sv SSSV (~ 1997 uaKer 'u~ pKrL~ RECEIVED 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure JAN 2 Alas .0il & Gas Cons. Commis$i.oii 14. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run '/' Gyro Daily Report of Well Operations ..Z_ . 16. Status of well classification as: Oil _._/ Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,Form 10-404 Rev 06/15/88 ~/ * Complet'i o ~, gTell Hlstory(Dani ) SW04/008 Date ~/2../~'~' SUBMIT IN DUPLICATE// ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial ReicH" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to spudding ~hould be summarized on the form giving inclusive dates only, District ICounty, parish or borough I I Lease or Unit Auth, or W.O. no. ITitle '.~C21 81 J state DS 14-39 IWell no. Operator Spudded or V~%~gun IDate Date and dept~CCZ'~T as of 8:00 a.m, Complete record for each day reported 01/08/89 ( TD: 9850 PB: 9802 SUPV:BB 01/09/89 ( TD: 9850 PB: 9802 SUPV:BB 2~) The above is c~,,~rect '{,,-- For *orm preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IARCO W.I. 21.0000 IHour 1330 IPrior status if a W,O. RU TO RUN COMPLETION 9-5/8"~ 9467' MW: 9.0 NaCl ACCEPT RIG AT 1330 HOURS 1-7-89. ND TREE, NO AND TEST BOP'$ TO 5000 PSI. RU DA E-LINE AND SET PACKER ASSEMBLY AT 9100' MD. RD DA AND TEST PACKER AND CSG TO 2500 PSI FOR 15 MINUTES - OK. DAILY:S111,735 CUM:$2,061,768 ETD:S2,061,768 EFC~$2,722,000 TESTING TREE 9-5/8"@ 9467' MW: 8.5 FSW MU AND RIH W/ 4-1/2" COMPLETION, LOCATED PACKER AND DISPLACED WELL TO 8.5 PPG INHIBITED SEAWATER. LANDED TUBING. TESTED TUBING AND CASING TO 3000 PSI AND SSSV TO 1000 PSI DIFFERENTIAL. ND BOP'S, NU TREE AND TEST. (AVA 'SC-SSV' SSSV @ 1997', BAKER 'DB' PKR ~ 9100', & TT @ 9224') DAILY=S238,463 CUM~$2,300,231 ETD:S2,300,231EFC~$2,722,000 ]RN 2 Oil & Gas Cons. Commis io AR3B-459-1-O INumber all dally well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. Accounting cost center code District County or Parish State ARCO ALASKA INC. NORTH SLOPE AK Field ~Lease or Unit PRUDHOE BAY I ADL: 28312 DS 14-39 Auth. or W.O.AS2181nD' ]TitleCOMPLETE Ooerator ARCO IWell no. Spudded or W,O. begun ACCEPT Date and depth as of 8:00 a.m. 01/10/89 ( 2 TD: 9850 PB: 9802 SUPV:BB API: 50-029-21888 A.R.Co. W.I. 21.0000 Date 01/07/89 Complete record for each day repo~ed AUDI RIG 4 Iotal number of wells (active or inactive) on this Dst center prior to plugging and ~ bandonment of this well our 1330 HRS IPrior status if a W.O. 1 RIG RELEASED 9-5/8"@ 9467' MW: 8.5 FSW TEST TREE. DISP TBG AND ANN W/ DIESEL TO 3198'. PRESS ANN TO 1000 PSI. PRESS TBG TO 3500 PSI AND SHEAR BAKER SHEAR OUT SUB. SET BPV. INJECT 940 BBLS JUNK SEA WATER DOWN 9-5/8" ANN. FREEZE PROTECT W/ 125 BBLS DIESEL. RELEASE RIG AT 14:00 HRS, 1-9-89. DAILY:$50,183 CUM:$2,350,414 ETD:S2,350,414 EFC:$2,722,000 RECEIVED JAN 2 ~; i5~ A!as~a 0ii & Gas Cons. C0mmissl0[~ A[~chora.qe Old TD New TD Released rig Date PB Depth K nd of rg Classifications (oil, gas, etc.) Type completion (single, dual, etC.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production OII on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected Signature -,, ~'\ \~ \ Title _ \', For form preparation and distribution, ' - ~ see Procedures Manual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forma consecutively as they are prepared for each well. Page no. Olvl~lon of AtlantlcRIchfleldCompany ARCO ALASKA, INC. P.O. BOX JO~360 ANCHORAGE, ALASKA 995~0 DATE' ~-42-89 REFERENCE' ARCO CASED HOLE FINALS 4-23 4-6-89 COLLAR/PERF RUN 3-26 42-3i-88 PERF RECORD RUN 3-27 t 2-34 -88 F'DK- ~ ~O RUN 7-33 ~-4-89 TEMP SURVEY RIJN 4, 9-5 4 2-30--88 PFC RUN 4 , 44-39 4-5-89 PFC RUN t4-39 t-7-89 PRODUCTION PACKER RUN t4-4~ 42-29-88 CBT RUN 44-40 4-4-89 GAMMA RAY RUN PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. .... HAVE A NICE DAY SALLY HOFFECKER .... 'N~A',mitaiDmge';~'"--'~---~ ATO- ~ 529 TRAN$ ~89~ AF'F'ROVED ___ DISTRIBUTION 5' 5' 5' 5' 5' 5' 5' 5' A'¥LA~' SCH ATLAS' SCH A'¥LA~' ATLA~~ ATLAS SCl..! ATLAS CENTRAL FILES ~ ~ PHILLIPS CHEVRON F'B WELL FILEX D&M R&D EXTENSION EXPLORATION ~ ~ SAF'C EXXON ~ ~ 7TATE OF ALASKA MARATHON ~ ~ TEXACO MOBIL ** THE CORRECTED AF'I$ FOR THIS LOG IS 5-8-829.-2~809. ARCO ALA~gKA, INC. F'~ 0 · BOX t ANCHORAGIE ~ ALA~'KA 995t DATE' F(EF'ERENC;E' ARCO MAGNETIC TAPES' W/L..ISTIN(~ t 4-S9 'i '2'"t 2-88 OH' DIFL/BHC/CZD-CN/CZD-RAW & .JOB:~,S642 CH · CNL F'I_EA,S'E J;IGN AND RETUFi:N THE ATI'ACHED COPY A6' RECEIF'T 01::'DATA, SALLY HOFFECKER ATO-I..,-..'~ APl:: ROYED DISTRIBUTION A l' L A ~' CENTRAL FILES (CH) CHEVRON D & M TAMMA,9 BROWN (OH) EXXON MARATHON MOBIL '~' Pi"i i Li_ i F',S' F'B WELL F'I:t..E~' R & ~ '"' ,S'AF'C -"- STATE OF' ALA.~KA TEXACO -IC-ir,,-08- ~ 89 0?: 08 ID:I.~J Ld 1 TEL NO:99372634600 Þ3.3E, POl ----~- , /,' ' 5/3 ,~ ;' ; , , STAtl or ALASU ALASKA 011.. & GAS CONSP,VATION CO~~ISSION : 1,0"11., Inlpacticn lapert : ; " : ',t ~!,~, '; ," ,\ i~' ", ' ¿I I, ¡ .1 :; , ~\I ~.J I , ! , r, I J~4 ,; IJ" TI ,¡ ,:.' 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"-í¡ , " ' "~'I':¡>' 1111:" L1þ.; 1 ,"" ' , "" >1<, , ,,'i, ':~ '" "f¡¥ ",.,' "" ,":,. \.CJ~,~~Ifj~~!~y~~ ' , " " , (J """"':",, " .",..,~ ,.. 0"" ","v:r."::¡"W'.I:.....,).",.. ,¿'" ", ".. ,,""","..,~, ..:;n¡_,"":J!n""" -- Dati--, / _-:-1J';JI~ f- ::~ CO , " L -.. . I ' W ~ w tll.. -4.£J ~ ~ 1J_:-.~3!L ,- --. ll.pt...t\'lt1v.~~_- - ...'en1t 'J2.T:/,lL. 1/ " ,'. 7 ,.C..ins S8t L,9.],3 ~ - -Mft" I, R- r...nt.!.~YI ¿tl.¡;AN~('¿ð1.. ,... L"" - ,~~\ ACC'fJKt1tÂTOI SYSTEM' , , ""'R, "., _0"'_"'-' lull ChaJ:,,' Fr...tn:a .3 (0°- p11L- -,d.064~.L- 1 . 'ralluta Attar Clolur.~ "1:tL..~- PWDp 1ftQI'. el~ø It pr., f 200 'li,I...---_..min~lI.c" lull Char,. rr..luraAtta1ntd """WlíIt.- d.. min. 1i.1_."c" N2~W~~ "~.t.. I ' ,~~~,~~Ol'& Ha~ttr4~. .'¡IOIl J...-- ""' ....- ~- -- --v.. In ,- Jrll -- ..~.!'.. j~i:L. Blind. Ini.9b ,.,9-9:!!L t~ J,-' 'Jlw-I,:;:"i'\~11ftqL~ . 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'i -- .,~., - . ,~_... .--- ¡ ¡ I ! !:FT..c PI'I.I\:u~.:i~,::' ~,'( ~ ,- ~ ----"-- ,)~:, ~¡I!:; ~,\:", . ,I '¡, . )'1<\- "" ' , i i j , ..:r\'~',':.,':,', ;'¡':',;h;~-':-"r;ihl ", ""'I"I;,,""I'\I"!"""""',' ," ",' '~ .¡Ù¡¡' ~;ti,~~;s.O~ ¡'~;!'~:" "Kit?,,~i:' ~'"'<I Ij~ II'" JJ ¡ 1,!i.i,¡:~,h i\<i;.¡>I:,;""" .,,1 '.. I ¡ ! ì ! , ......... ",;:,'¡If;¡'~ ':'~~"f,"\': "'fr"I1,.I)"i"I¡"'" ., ' " ....-.-.- ' ", .. _. '" -, ".:'j,,', ý ;" i ';,: '" ' - 1.1!8JI--...¡n- o::,""~";':'~'-""'.~:.Î¡-'.<~~'~;I~~:"';"o:' ,.-),;¡j, ~f:~:.';';.t~" ..' "'~ '. ':, ':..\" ¡,~:~',", ¡"..j' , " :,j' ': ':' , , . :', .. .' .~ ' ':';/~ :': ,,), "."."..,1(..'."""",. I",., ,'ji'r.'JI" ;111.. ... Õ, ..(.'......,... 2 "\.....,iC, ':,~ ~"!"..~:,~ ""':--"."""."~T"G"'C:""' ,.:1/ "¡ '1:"- ..', ,~J "',," It ',~. ~""D. ~ ,t~(i;:Jl'Pí.; ... I> .. 'if, 7' ":.. ' ",' . - " " ~I:~ ' ':.., L~.lijr..t:,,!? . I J , u' 'bin.""'. tU~" to be ..dl v1th~D dlYI and In'pectorl .........._-~. ..."'01'<11"_-- -'- ~.......... ,. "~:;""~;~:"::""""~""':':'" ,',":" :, ",,;~,"" \ ":- .' , " ,,:,¡'.d~:':; "~:" '" :'" . , "" ~,~ :;" ,.' '<,"" '. ' , ,:', \ .. ' ---..- .---- .""_" ",", - - ¡ I e~...-.._._... ..........'.._a.__- ---- -,- _r ," ~a' , ,"'. "" ',I, In,8J:'HIc.H:"r Rt<1 t\ \j ~t) ~P<~ \J 4l'jo~ " ' " . . CO\\\m\s$\O{\ , ".~ Sa. Gas cot\s.,' ' . ;\\as\Øt. ~~~( ¡fJ\cnota.~er', I ":, ,,', '" i" \, , , , , " ," STATE OF ALASKA AL,-,,.,KA OIL AND GAS CONSERVATION COMMIb,.,,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Operation shutdown v- Re-enter suspended well __ Alter casing m Repair well ~ Plugging m Time extension m Stimulate ~ Change approved program Pull tubing __ Variance __ Perforate __ Other __ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2539' FNL, 1599' FEL, Sec. 9, TION, R14E, UM At top of productive interval 200' FSL, 2600' FWL, Sec. 9, TION, R14E, UM (approx.) At effective depth 70' FSL, 2543' FWL, Sec. 9, TION, R14E, UM (approx.) At total depth 57' FSL, 2531' FWL, Sec. 9, TION, R14E, UM (approx.) Development Exploratory Stratigraphic Service RKB 74' Z UnitorPropedyname Prudhoe Bay Unit 8. Well number 14-39 9. Permit number 88-138 10. APl num~b"e'r'-21 888 50-- 11. Field/Pool Prudhoe Bay 0il Pool feet 12. Present well condition summary Total depth: measured true vertical 9850 'MD feet 9244 ' T VD feet Plugs (measured) Non e Effective depth: measured true vertical 9802 'MD feet 9200'TVD feet Junk (measured) None Casing Length Structural Conductor 80 ' Surface 3579 ' Intermediate 9436' Production 695 ' Liner Perforation depth: measured None None true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) Size 20" 13-3/8" 9-5/8" 7" Cemented Measured depth True vertical depth 2150# Poleset 1lO'MD 110'TVD 2000 sx CS Ill & 3612'MD 3536'TVD 600 sx Class G - Top job w/250 sx CS I 600 sx Class G 9467'MD 8892'TVD 325 sx Class G 9155'-9848'MD 8604'-9242'TVD RECEIVED JA d o Alaska 0ii & 6as Cons, .C0mmissi0r None 13. Attachments Description summary of Proposal Detailed operations program """"~"~etch ~ Well History, 14. Estimated date for commencing operation J 15. Status of well classification as: February 1, 1989 i 16. If proposal was verbally approved ' J Oil v- Gas ~ Suspended ~ I Name of approver .. Date approved J ServiCe ~_ ~ 17. I hereby certiJLy th~ng is trUe and correct to the best of my knowledge. Signed /, Title Regional Drilling Engineer Date // ' ~ FOR COMMISSION USE ONLY Conditions of approval: Notify C~mmission so representative may witness I Approval No. Plug integrity m BOP Test ~ Location clearance ~ /.),~ Mechanical Integrity Test ~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commissiom[~ONNIE C, SMITH Form 10-403 Rev 06/15/88 043/SA4 Copy Returne~_ Date /--~ ~¢ - S~' SUBMIT IN TRIPLICATE ARCO Oil and Gas Company "' Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial ReDort" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District County. parish or borough l State I AR~O ~T. ARKA TN~_- I NORTH SLOPE I AK Field I Lease or Unit I pRUDHOE ~A¥ [TitleADL: 28312 DS 14-39 Auth. or W.O, no, I ' , z~R91 R1 ,, I D~T%L Well no. AkI: 50-029-2181~I~ Operator IARCO W.I. ~,~cn I 23..OriOn Spudded orW.O, begunspl~ IDate 11/25/~ IH°ur 0300 HRS IPri°rstatus~faw'°' Date and depth as of 8:00 a,m. 11/25/88 ( TD: 285'( SUPV:JCP 11/26/88 ( ' TD: 1766'( 1 SUPV:JCP/DW 11/27/88 ( TD: 2530'( SUPV:JCP/DW 11/28/88 ( TD: 3625' ( 1 SUPV:JCP/DW 11/29/88 ( TD: 3625' ( SUPV:JCP/DW 11/3o/88 ( TD' 3723'( ' ak/ui/~ ( '% TD: 5663' ( 1 SUPV:MDD Complete record for each day reported NABORS Z~S ) DRLG 20"@ 110' MW: 8.7 VIS:250 185) FIN MOVE F/ 14-40 TO 14-39. ACCEPT RIG 1800 HRS 11/24/88. NU DIVERTER. PU 17-1/2" BHA. FUNCTION TEST DIVERTER. FIN BUILDING SPUD MUD. RIH TO 110'. SPUD WELL @ 0300 NRS, 11/25/88. DRILL TO 285'. DAILY:S47,796 CUM:$47,796 ETD:S47,796 EFC:$2,722,000 ) DRILLING 20"@ 110'~ MW: 9.4 VIS.:126 81) DRLD F/ 285' TO 857'. SURVEY. POOH. CHNG BHA. RIH. DRLD F/ 857' TO 1470'. SURVEY. POOH. CHNG BHA AND RIH. DRLD F/ 1470' TO 1766'. ~ DAILY:S63,769 CUM:$111,565 ETD:S111,565 EFC:$2,722,000 I) MU NEW DYNADRILL 20"@ 110~ MW: 9.7 VIS:162 ~64) DRLD TO 1986'. RUN GYRO ON WL. POOH. CHNG BHA AND RIH. DYNA DRILLED F/ 1986' TO 2530' POOH. LD DYNA DRIL. PU NEW DYNA DRIL. DAILY:S69,111 CUM:$180,676 ETD:S180,676 EFC:$2,722,000 1) POOH TO RUN CASING 20"@ 110' MW: 9.9 VIS: 88 195) TEST AND ORIENT TELECO. TIH. DYNA DRILD F/ 2530' TO 3241'. CIRC AND COND MUD. DYNA DRLD TO 3625'. CBU. RUN GYRO ON W/L. SHORT TRIP TO HWDP. CIRC HOLE CLEAN. POOH TO RUN 13-3/8" CSG. DAILY:S59,291 CUM:$239,967 ETD:S239,967 EFC:$2,722,000 ,) NU BOP'S 13-3/8"@ 3612' MW: 9.6 VIS: 36 0) FIN POOH. LD BHA. RU CSG TOOLS. RUN 90 JTS 13-3/8", 72#, L80 BTC CSG & i JT 13-3/8", 68~, K55 CSG W/ SHOE AT 3612'. CIRC AND COND MUD. PUMP 100 BBLS WTR. PUMP 2000 SX CS II! AT 12.2 PPG. TAIL W/ 600 SX OF CLASS G AT 15.8 PPG. CIP AT 18:30 HRS, 11/28/88. OB~ SX OF CS I AT 14.8 PPG. SET SLIPS. WELD, TEST CSG HEAD. NU STACK. DAILY:S327,797 CUM:$567,764 ETD:S567,764 EFC:$2,722,000 i) DRILLING 13-3/8"@ 3612' MW: 8.6 VIS: 28 98) FIN NU BOP. MAGNAFLUX KELLY. TEST BOP. INSTALL WEAR BUSHING. PU BHA %3 & RIH. TEST CSG TO 2500 PSI. DRILL FLOAT EQUIPMENT & 10' NEW FORMATION. PERFORM LOT TO 14.7 EMW. DRILL TO 3723'. DAILY:S42,485 CUM:$610,249 ETD:S610,249 EFC:$2,722,000 t) DRILLING 13-$/8"~ 3612' MW: 9.3 VIS: 32 ~40) DRLD TO 5663'. DAILY:S49,873 CUM:$660,122 ETD:S660,122 EFC:$2,722,000 The above is correct For form ~rep~-ration and distribution, see Procedures Manual, Section Drilling, Pages 86 and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. iPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and depth as of 8:00 a.m. ARCO ALASKA INC. ICounty or ~(~r~H SLOPE I PRUDHOE BAY ILease°rU~i.~ 14 39 I Comp.et ...... ,~ f~..~%%6~3~. ~,~ dr.,,n~ ..... k .... ,n prog .... 12/02/88 ( TD: 6300'( SUPV:MDD 12/03/88 ( TD: 7048'( SUPV:MDD 12/04/88 ( TD: 7825'( SUPV:MDD 12/05/88 ( TD: 8167'( SUPV:MDD 12/06/88 ( TD: 859'0'( SUPV:MDD 12/07/88 ( TD: 9245'( SUPV:MDD 12/08/88 ( TD: 9475'( SUPV:JCP 12/09/88 ( TD: 9475'( SUPV:JCP State AK 8) 637) 9) 748) 0) 777) .1) 342) .2) 423) ~3) 655) L4) 230) L5) 0) LOGGING 13-3/8"@ 3612' MW: 9.3 VIS: 34 REPAIR MUD PUMP. DRILL TO 6300'. CBU, SHORT TRIP, CBU. POOH TO LOG. RU WESTERN ATLAS, RUN #1 DIL/GR/CAL. LOGGING W/ RUN #2: GR/RFT. DAILY:S49,150 CUM:$709,272 ETD:S709,272 EFC:$2,722,000 DRLG 13-3/8"@ 3612' MW: 9.5 VIS: 34 FIN LOGGING W/ RFT. TOOK 19 FORM TESTS. RD WESTERN ATLAS. RIH. NO FILL ON BTM. DRLG TO 7048'. DAILY:S98,329 CUM:$807,601 ETD:S807,601 EFC:$2,722,000 DRILLING 13-3/8"@ 3612' MW: 9.6 VIS: 37 DRLD F/ 7048' TO 7281'. MIX SLUG. SURVEY. POOH. CHNG BITS AND RIH. DRLD F/ 7281' TO 7825' DAILY:S56,199 CUM:$863,800 ETD:S863,800 EFC:$2,722,000 TRIP F/ BIT 13-3/8"@ 3612' MW:10.0 VIS: 41 DRLD TO 8164'. POOH TO CHNG BIT. RIH AND WORK BIT TO BTM. ATTEMPT TO MAKE BIT DRL. NO SUCCESS. DRLD TO 8167' POOH TO CHNG BIT. DAILY:S55,230 CUM:$919,030 ETD:S919,030 EFC:$2,722,000 DRILLING 13-3/8"@ 3612' MW:10.0 VIS: 40 FIN RIH W/ BIT ~10. DRILL TO 8590'. DAILY:S47,021 CUM:$966,051 ETD:S966,051 EFC:$2,722,000 DRILLING 13-3/8"@ 3612' MW:10.0 VIS: 37 DRILL TO 8685'. DROP SINGLE SHOT, PUMP SLUG, POOH FOR BIT. RIH, SLIP & CUT, FIN RIH. REAM LAST 40'. DRILL TO 9245'. DAILY:S47,792 CUM:$1,013,843 ETD:S1,013,843 EFC:$2,722,000 POOH TO RUN CASING 9-5/8"@ 9467' MW:10.2 VIS: 40 DRILL TO 9475'. SHORT TRIP 20 STDS. CIRC & COND. DROP SURVEY & PUMP SLUG. POOH TO RUN 9-5/8" CSG. DAILY:S56,427 CUM:$1,070,270 ETD:S1,070,270 EFC:$2,722,000 INSTALL WEAR RING 9-5/8"@ 9467' MW:10.3 VIS: 39 CHANGE R/%MS TO 9-5/8" & TEST SAME. RU CSG TOOLS. RUN 109 JTS 9-5/8", 47#, L-80, BTC MOD + 109 JTS 9-5/8", 47#, L-80, BTC. CIRC & COND MUD. PUMP 50 BBL MCS-A SPACER & 600 SX CLASS G + 1% BA-10, 0.2% CD-30, 0.4% FL-32, 0.3% A-2, 0.41% R-l, 1 GHS FP-6L @ 15.8 PPG. BUMP PLUG. LD LANDING JT. CHANGE RAMS TO 5". TEST BOP, CHANGE MANUAL VALVE, TEST BOP. INSTALL WEAR RING. DAILY:S306,372 CUM:$1,376,642 ETD:S1,376,642 EFC:$2,722,000 IWell no. /he above is correct Signat,are ~-, ~': ', ~--, For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when titled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin~ until completion. District i~RCO ALASKA INC. IC°unty°r~a(~il~l~H SLOPE JStateAK Field PRUDHOE BAY ILease or U~i~ 14 39 I Complet ...... d f~rA~:~(~y ~1~ drilling ..... k ....in prog .... Date and depth as of 8:00 a.m. 12/10/88 ( TD: 9502'( SUPV:JCP 12/11/88 ( TD: 9542'( SUPV:JCP 12/12/88 ( TD: 9660'( SUPV:JCP 12/13/88 ( TD: 9850'( SUPV:JCP 12/14/88 ( TD: 9850 PB: SUPV:JCP i2/i5/88 ( TD: 9850 PB: SUPV:JCP Well no. 6) 27) 7) 40) 8) 118) .9) 190) ~o) CLEANING PITS 9-5/8"@ 9467' MW: 8.9 VIS: 87 MU BHA. TIH. TAG FC AT 9375' TEST CSG TO 3000 PSI. OK. DRL FC AND ~MT TO 9457'. RETEST CSG TO 3000 PSI. OK. DRL FS AND 10 NEW HOLE. TEST TO 12.5 PPG EMW. OK. DRL TO 9502'. CBU. DISPLACE WELL W/ BLAND CORE FLUID. DAILY:S123,473 CUM:$1,500,115 ETD:S1,500,115 EFC:$2,722,000 TIH FOR CORE ~2 9-5/8"@ 9467' MW: 8.9 VIS: 91 FILL PITS W/ CORE FLUID. DRL TO 9512'. CIRC AND COND CORE BUILD. POOH F/' CORE BIT. MU CORE BBL AND TIH. CORE F/ 9512' TO 9542'. POOH W/ CORE ~ 1. DUMP CORE. 100% RECOVERY. MU CORE BIT # 2 AND RIH. DAILY:S62,566 CUM:$1,562,681 ETD:S1,562,681 EFC:$2,722,000 DUMPING FINAL CORE 9-5/8"@ 9467' MW: 8.9 VIS:107 CORE F/ 9542' TO 9570'. POOH W/ CORE # 2. DUMP CORE. 100% RECOVERY. MU CORE # 3 AND RIH. CORE F/ 9570' TO 9600' POOH W/ CORE # 3. DUMP CORE. 100 % RECOVERY. MU CORE # 4. RIH AND CORE F/ 9600' TO 9660'. POOH W/ CORE 9 4. DAILY:S42,942 CUM:$1,605,623 ETD:S1,605,623 EFC:$2,722,000 SHORT TRIP TO CSG 9-5/8"@ 9467' MW: 9.0 VIS:101 DUMP CORE # 4. RECOVERED 58.5' OF 60'. RD CORE TOOLS. MU BIT AND TIH TO 9498'. REAM F/ 9498' TO 9660' DRLD F/ 9660' TO 9800'. CIRC AND COND MUD. SHORT TRIP TO CSG SHOE. CBU. SURVEY. POOH TO RUN LOGS. RU AND RUN DIL/BHCS /GR/SP. RUN # 2 W/ CNL/Z-DEN/GR/CAL. RD LOGGERS. MU BIT AND RIH. CDL. DRLD TO 9850'. DAILY:S127,488 CUM:$1,733,111 ETD:S1,733,111 EFC:$2,722,000 CIRC OUT CMT 7"@ 9848' MW: 9.0 WBM CBU. POOH TO RUN 7" LINER. RU AND RUN 16 JTS 7", 29# LB0 BTC CSG AND BOT SHORTY HGR. CIRC. TIH W/ LINER ON DP. CIRC AND COND MUD. TEST LINES TO 3500 PSI. CMT W/ 325 SX OF CLASS G CMT AT 15.8 PPG. BUMP PLUG W/ 3500 PSI. CIP AT 21:00 HRS 12/13/88. SET HGR AND RELEASE. POOH W/ RUNNING TOOL. MU 8-1/2" BIT AND RIH TO TOL. CIRC OUT GREEN CMT. DAILY:S118,945 CUM:$1,852,056 ETD:S1,852,056 EFC:$2,722,000 POOH. LDDP 7"@ 9848' MW: 9.0 NaCl CIRC OUT CONTAMINATED CMT. POOH. LD 8-1/2" BHA. PU 6" BHA, 3-1/2" DP. TAG CMT AT 9155'. DRL CMT TO LC AT 9716'. CIRC. TEST CSG TO 3000 PSI FOR 10 MIN. OK. REV OUT W/ HEC SWEEP,H20 & NACL. TEST CSG TO 3000 PSI FOR 30 MIN. OK. POOH. LDDP. DAILY:S45,027 CUM:$1,897,083 ETD:S1,897,083 EFC:$2,722,000 The above is correct For form preparation and distribution see Procedures Manual Sechon tO, Drilling, Pages 86 and 87 AR3B-459-'2-B Number all daily well history forms as they are prepared for each well. consecutively Page no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Filial Report" form may be used for reporting the entire operation ff space is available. District County or Parish ARCO ALASKA INC,' 5]ORTH SLOPE Field ILease or Unit PRUDHOE BAY I ADL: 28312 Auth. or W.O. no. ITitleDRILL AS2181 API: 50-029-21888 0 perator A. FI. Co. ARco ~'i.0000 Spudded or W.O. begun Cate SPUD 11/25/88 Date and depth Complete record for each dayreported as of 8:00 a.m. NABORS 28~- 12/16/88 ( 2 TD: 9850 PB: SUPV: MDD Accounting cost center code State AK DS 14-39 IWell no. Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our 0300 }'].RS Prior sIatus if a. W.O. RIG RELEASED 7"@ 9848' MW: 9.0 NaC1 FIN LDDP AND BTU%. DISP TOP 400' W/ DIESEL. ND BOPE. NU TBG SPOOL. INSTALL DUMMY HANGER. NU DRYHOLE TREE. TEST SAME. CLEAN PITS. FREEZE PROTECT ANN. RIG RELEASED AT 2200 HRS, 12/15/88. DAILY:S52,950 CUM:$1,950,033 ETD:S1,950,033 EFC:$2,722,000 Old TD New TC Released rig Date PB Depth Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Sig r~,~,~%~ Dat~ h ITitle J !. /,~.~ t '-~ For form preparation and distribution, / see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well. iPage no. Division of AtlanflcRIchfieldCompany ARCO ALASKA, INC. P.O. BOX tSGJ6G ANCHORAGE, ALASKA 995~G DATE: t~--~8 88 REFERENCE: ARCO CASED HOLE FINALS 2-t& ~-~t-88~ ~ COLLAR/PERF RUN 7-26 t2-t6-88 PRODUCTION RUN t, 5' 7-27 t2-t6-88 CNL RUN t, 5' 7-2~ ~2-t6-88 CNL RUN ~, 5' t4-37 t2-t8-88 COLLAR RUN ~4-38 t2-~9-88 COLLAR/F'ERF RUN t, 5' t4-37 ~2-t~-88 CBT RUN ~, 5' t4-~9 t2-~9-88 CET RUN t, 5" PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF:'T OF DATA. RECEIVED BY HAVE A NICE DAY! ~ALLY HOFFECKER ATO-~527 TRAN£ ~88727 ,~ APPROVED AlaMm Oil & Gas Cons. Commission' _ Anchorage D I STR I BUT I ON ATLAS $CH ~'CH $CH ATLAS ATLAS $CH $CH CENTRAL FILES CHEVRON EXTEN£ION EXPLORATION EXXON MARATHON MOBIL F'HILLIP$ PB WELL FILES R & D SAF'C STATE OF ALASKA TEXACO ARCO ALA~?KA, INC P,O, BOX t00360 ANCHORAGE, ALA~'K A DATE' t2-22-88 RIFFERENC;E ' ARCO OPEN HOLE I::INAL~' ~ 4-'39 t 2-' t 2-88 t 4-39 t 2-' t 2'-88 ~ 4-'39 t2'"t2-'88 t4-39 t2-t2-88 BHCA-'GAMMA DIFL-GAMMA CZD'"GAMMA (RAW) CZD/CNL-GAMMA (F'ORO) RLJN RUN 2, RUN J, 2"&5' RUN t, 2~&~" F'LEASE." SIGN AND RETLJRN I'HE ATTACHED COF'Y AS RECEIF'T OF DA'FA, RECEIVED SALLY ~OI-'-F:'ECK ER ATO- i 52!9 DISTRIBU'FION A'FL.A~? ATI_A~' ATL. A~? AI'I..A.~ CENTRAL FILE~~ ~ PHILLIPS CHEVRON PB WELL FILES ~ R & I) D & M ... EXTENSION EXPLORAI'ION ~ 3'AF'C EXXON ~ ~'TATE OF ALASKA MARATHON ~ TEXACO MOBIL A h. ~., ALA:."TK A: ]]NC~ ~-'~. P,. O~ BOX 'i (~¢~..'56(') A .......... N i": H 0 F: A (:'., _..~:', A L. A g K A 9 9 ...:.'::' ~, .":"... , ..... , ~ ~.~ :.,-, -! E., T 'i" A F:' iii; ,'ii: i.d/i ! g 'T iil ~"~ ;" i ,'-i. .... 3 9 'i 2 .... i .... 8 8 0 i-I: Diil !::'i ...... iO }}: :i~: S 6 2 2 F:' i... ii!] A g iii] ,'? i C. ?-.! ,, ;, -:, c, :' .v..~, ',i --;-,... - ,.,..',:-.'r ,.,..,--. i':: '~"; ;'" ;'; ~::,': ..... ~::', ,'": ..--'.: :..-'-. i..t ..... f.. !~... r'! ~ r't ....L. :-..- F"i ,~i:i::, " ..... ~", .... ': ~'.. .: :.:,..,, , ........ I::..L r' i ,..., i::' }]/F'i 'i" ;lC A !... i.,. Y i-t 0 i::' I::' E C: i'.':.' ii!: F:..' AT'O .... i5::29 Anchorage 01 g T F:.: I B LJ'T ]: 0 N C;' ["' N"f' R A i... F: I i:.. Ii.;. ;i:..: ( C i"I ) ' C':HEVRON D & H 'T'AMHA,S: BF:.:C,'I, dN (OH) E X X O N H A R A T H 0 N HO B ]: i... EM-ORAN DUM State uf Alaska TO: ALASKA OIL ~D GAS CONSERVATION COFR4ISSION ,. / Lonnie C Smith ~ r-'':vf SATIn December ]6, 1988 Commis s ioner ~: ' FILE NO: D ADA. 14 7 TELEPHONE NO: THRU: Michael T Minder ~~'~: SUBdECT: Sr Pet=oleum Engineer BOP Test AAI PBU DS 14-39 Permit No. 88-138 Prudhoe Oil Pool FROM: Doug Amos ~ Petroleum Inspector Tuesday, November 29, 1988: I traveled this date from Anchorage to prudhoe Ba~" ~6 wit~eSS the BOP test at AAI PBU DS 14-39 well. The testing commenced at 1:45 p,m. and was concluded at 4:00 p.m. The one failure was repaired and retested this date. I filled out an AOGCC BOP inspection report which is attached. In s~ary, I witnessed the BOP test at AAI PBU DS 14-39 well on Nabors Rig 28E. Attachment 02-001A (Rev. 8~85) STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report ~Inspector ©~.~ Operator ~ ~Z, P~ ~, Location: Sec ~ T}OtQ R ~M ~,~ -Date Well Representative Permit # ~ M Casing Set @ ~[~ Drilling Contractor Rig # 'g~ Representative Location, General u,-/Well Sign u/ General Housekeeping ~-~{g, / Reserve Pit ~/ Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure M~oo BOPE S tack ~Annular Preventer~ Pipe Rams ~L~ Blind Rams ~ Choke Line Valves,-~, H. C.R. Valve Kill Line valves~ Check Valve ACCUMULATOR SYSTEM Full Charge Pressure ~~P Pressure After Closure ~C)~5~? Pump incr. clos. pres. 200 psig Full Charme Pressure Attained: psig ~//' psig L"'~ min t5 sec. ~ min~O_ sec. Controls: Master,, Remote ~,-" Blinds switch cover Kelly and Floor Safety ~alves Upper Kelly t Test Pressure ,~~ Lower Kelly i Test Pressure '~ Ball Type ~, Test Pressure Inside BOP ~'~ ....... Test Pressure Choke Manifold I ..... Test Pressure No. Valves I ~ No. flanges , ~Z. Adjustable Chokes Hydrauically operated choke Test Time -~ hrs. Test Results: Failures, Repair or Replacement of failed equipment to be made within days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor 'i 2 .... 'i. .... ~ii: :!i!~ "~, 'i ,.':' ''~: .:..."':: .... ,...."':' · i 'i," ':';, .... i'!:... 'i / · i 'i "-" .... "::, .~ .... ,::,,'::' '" :"*,:; ":*", F;:. r:'.", Y R'.i:; ]; ,'ii.' T ]: V' ]: "r' ,.~..~ / '~' :... i ?. U (".! 7:' ;.]" :'i';: C ~::' E C iii: i V E i'", B Y { ,: ..; ........................................................................................ l'-i A V F:' A i'a 'r r' i:." 'r'-, ;:':., ,,,' ~ ?.-.: A J... i... Y I"i [it F F:' iii] ;'",.... i'-'.'; iii] P. A '¥ 0 .... '~. ~''''_.. 2 9 'T F,: A N ~'., .~. o o ":, r:~ .":~ g P P R il) V E D ........................................................................................... 'f'~ T '7 'r' i.7 T 't':'..' J l T 'r f'i i"..! .*..- .,". :... 1 ~ ...1 ...... I .I. :,e i; November 9, 1988 Telecopy: (907)276-7542 Mr. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Prudhoe Bay Unit DS 14-39 ARCO Alaska, Inc. Permit No. 88-138 Sur. Loc. 2539'~, 1599'FEL, Sec. 9, T10N, R14E, b~{. Btmhole Loc. 124'FSL, 2567'FWL, Sec. 9, T10N, R14E, UM. Dear Mr. Oostermeyer: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not tndenmify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. tr.u y ! r~~~_~ Chatterto~ ' Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. r~ ~ STATE OF ALASKA /--',,, ALASK* OIL AND GAS CONSERVATION ~--'~MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill I~' Redrill FII lb. Type of well. Exploratory [] Stratigraphic Test [] J~evelopment Oil Lq'"" Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB 74' , PAD 42'GL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay 0il Pool P.O. Box 100360, Anchorage, AK 99510-0360 ADL 28312 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 2539'FNL, 1599'FEL,Sec. 9,TION,R14E,UM Prudhoe Bay Unit; Statewide At top of productive interval (¢ 8976 ' TVD) 8. Well nu .mber Number 200'FSL, 2600'FWL,Sec. 9,T10N,R14E,UM DS 14-39 #8088-26-27 At total depth 9. Approximate spud date Amount 124'FSL, 2567'FWL,Sec. 9,T10N,R14E,UM 11/14/88 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line DS 14-17 29' 9738'MD 124' (~ TD feet (~ 4148'MD/4032'TVDfeet 2560 9172'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2000'feet Maximum hole angle 23 0 Maximum surface 2970 psig At total depth (TVD) 3850 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 110' 110 2000# Poleset 17-1/2" 13-3/8" 68# K-55 BTC 20' 30' 30' 50' 50 2000 sx CS I.~l & 72# L-80 BTC 3527' 50' 50' 3577' 3500 600 sx CS I I 12-1/4" 9-5/8" 47# L-80 TC/Mod 9406' 30' 30' 9436' 8894 500 sx Class G 8-1/2" 7" 29# L-80 BTC 602' 9136' 8618' 9738!' 9172' 300 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth' measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production Perforation depth: measured AJ~ch0rage true vertical 20. Attachments Filing/,fee ~"' Property plat [] BOP Sketch Drilling fluid program 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~'~~J Title Re.qiona] Drillinq Engirl~,r Date//~/~/~ Commission UseOnly ~5~ (6SW) PD3/035 Permit Number I APlnumber IApprovaldate J See cover letter ~;~ ~ - / 3' ¢ 50-- O g,- '~ - 2_.-,/~'¢ ¢' 'l ]. / 0 9 / 88 for other requirements Conditions of approval Samples required J~Yes [] No Mud Icg requi.red El Yes ~No Hydrogen sulfide mea~sures ,e~l Ye~,% J~ No Directiona, I survey required ,,~ Yes [] No Required workin.g,,ffEes~u~ f~r~P~ ,,~2Mj/. E~] SM; ,,~ SM; [] 10M; [] 15M Other: / j ~'y/.~~~i~- - ~.~ by order of Approved by ~,._..~.. ~, ~~'~~~ Comm,ss,oner the. commission Date Sub~ in triplicate Form 10-401 Rev. 12-1-85 / PBU DS 14-39 OPERATIONS SUMMARY 1) MIRU drilling rig. 2) NU 20" annular diverter and function test same. 3) Spud well and drill 17-1/2" hole to 2000'. Kick off and build angle at 2.5°/100' to 22° 59' at S23°9'W. Drill to 3500'TVD/3577'MD. 4) Set 13-3/8" casing and cement same. 5) Install 13-5/8" 5000 psi RSRRA BOPE stack and test rams to 5000 psi, annular to 3500 psi. 6) Drill float equipment and 10' of new hole. Perform leak off test. 7) Drill 12-1/4" hole to 6000'TVD/6293'MD. Log open hole with DIL/GR/Cal and RFT/GR. 8) Drill 12-1/4" hole to 8894 'TVD/9436 'MD (15' TVD above Sadlerochit). 9) Set 9-5/8" casing and cement same. 10) Test casing to 3000 psi. Drill out and perform leak off test. Displace hole to core fluid. 11) Core 8-1/2" hole to TD of 9172'TVD/9738'MD. Run open hole logs. 12) Run and set 7" liner and cement same. 13) Clean out liner to PBTD. Test liner, liner lap and casing to 3000 psi for 30 minutes. 14) Circulate well to brine, freeze protect and release drilling rig. 15) Run cement evaluation logs and gyro. 16) MIRU completion rig. RIH and set packer. Run 4-1/2" tubing with GLMs and 4-1/2" tailpipe. NU 4-1/2" tree. RD completion rig. 17) Perforate and stimulate as necessary. Install SSSV. PD3/035.2 NOTE: a) b) c) d) e) In accordance with Area Injection Order No. 4, excess non-hazardous fluids resulting from well operations and as necessary to control fluid level in reserve pit will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The annulus will be sealed with 300 sx of cement followed by Arctic pack upon the termina- tion of fluid disposal. Wells within 200' of the proposed well are: DS 14-17 DS 14-21 DS 14-22 29' @ 4032'TVD/4148'MD 180' @ Surface 91' @ 2250'TVD/2251'MD The drilling fluid program and fluid surface system will conform to the regulations set forth in 20AAC25.033. Maximum surface pressure is based upon BHP and a full column of gas to TD (0.10 psi/ft). Based upon previous logs on DS 14, no potential productive zones are anticipated above 4000'TVD. PD3/031.3 tons, Comrmssmn Depth (TVD) DS 14-39 MUD PROGRAM Plas Yield Density Visc. Point Initial 1OM #/gal (CP) #/100 ft2 Gel Gel Surf 8.8 Funnel to to 100- 13-3/8" 9.2 250 Csg Poi nt FL % % CC/30M Oil Solids 40-60 30+ 50+ 25 0 8 13-3/8" 8.8 Minimum 2 2 5 25 Csg Shoe to Possible to to to to to 9.4 4 4 10 10 K-10 3.5 0 to 6.5 pH and T)~pe of Mud Gel-Benex Spud Mud Low solids/ non-dispersed K-lO 9.2 10 6 4 8 8 to TD to to to to to to 9-5/8" 10.2 15 10 8 12 4 Csg Point 9-5/8" 8.8 Minimum 2 2 5 8 Csg Shoe to Possible to to to to to TD 9.2 4 4 10 4 2 to 5 4 to 8 pH 8 Low solids/ non-di spersed 4 to 8 Low solids/ Bland core fluid pH 8 EQUIPMENT - DRILLING FLUID SYSTEM 1. Degasser 2. Shakers 3. Pit level indicator (with both visual and audio warning devices) 4. Drilling fluid flow sensor (with readout convenient to the driller's console) 5. Trip tank 6. Agitators 7. Mud cleaner and centrifuges PD3/035.4 MUD SYSTEM NABORS 28E MUD CLEANER MUD CLEANER SAND TRAP 4 BBLS TRIP TANK PIT I 171 BBLS 130 BBLS PIT 2 PIT 3 81 BBLS 137 BBLS PIT 5 117 BBLS PIT 4 179 BBLS PILL PIT 20 BBLS PIT 6 135 BBLS ,~,~'" Cons · .C~mnii~aion.- ~ . ~' " '.Anchorago , CAVIEM SB-7 MUD CLEANERS (2 @ 750 GPM EACH) DESANDER 3 X 12" DIAMETER CONES DRILCO DEGASSER BRANDT CENTRIFUGE MUD PUMPS: 2 CONTINENTAL EMSCO FB-1600 DACRO GAS BUSTER JG 8/6/87 D814-39 0 1000 , 2000 3000 4000 5000 6000 7000 1000 - 1000 ARC 3 AL ,SKA, INC. ¢~p 'rvn. ~a,~n !~{~ALI; I IN = 18813 F'T 2000 :2.b · P. O00 5 SEC: g, T10N, R14E, ~t 17.5 THL: 200' :SLo 2600' F~ .15 EOC TVD-- !895 MD--2g'8 DEP=-182 3000 RF~: g~ 11[3N, fl14F= U ~1 3000 13-3/8' CASING TVD = 3800 MD = 3! i77 DEP - 43e 4000 4000 K-15 TVD -- 4339 MD -- 4488 OliP -- 764 5000 ~:~ 5000 ~701 F~ (TO TARGET) AVEnAG E ANGLE ~. 'ago 6000 ~ CEa Em UlN 6000 K-lO TVD=886a MD=7220 DE~--IB~I 7000 7000 K'~ TVD = 76,~4 MD = 787~ DEP = 211~ 8000. LCU TVD- 8124 MD - ~=SeO DEP -- 24110 8000 ¢~'C~VD- es; 4 MD -- 9436 DEP -- 2[[[. SAG RIVER TVO m ~ 810 MD m 936 ~ OEP -- 21196 . T~0~ ~'~ =D = ~4~ ~ =..=.. 9000 ~ TAFiQET TVD - BG 78 MD - g~ OEP - ~761 ' ' ' TVD m g MD g581~ DEP -- 2788 //~TVD - ')34 -- BASLE SADLEROC~IIT TVD 803, MD 9588 E El 278e 172 MO-973~ 0EP-2644 0000 - ~ 0000 ~ 000 ........................... , ..................................... 1 ~ 000 7000 0 1000 2000 3000 4000 5000 6000 £ - 14 COORDINATE~. o -SO00 -4000 "'~'"'-3000 -2000 - ! 000 0 1000 2000 0 I OS ! ~-37 : ~su- ~bUl 2 7~~ ~6 ~ O; 1 0 79 2;' ¢ ¢7027 ~~6~~ 43 ~ ' ~&7' -- o ns,~ 4-'~8 8)78 OS 9 · °o 35i u ~ 8 , t S7NA ' ' 607 z 613~ ~2 ~, e~/' 3S 1~"17 ' 700 3 ,, .~ /870E I I I I I I I I I I I Il I I I I [ I I I I I [ I I I , [ I I I I : I [ I I I [ I I I I I I [ I I I I I I I I I I I I -5000 -4000 -3000 -2000 -1000 0 1000 2000 311 67'~ E - N COORDINATES I' E - 1,4 COOROINFt"rE''-'--'~-, 0 I z I cz) I 0 I OS 1 -400 -300 -200 -100 0 100 200 300 I I I I, II I, I I, ' ' ' ' ' ' ' ' ' ' ' I I I I I t I ' ' ' ' ' ' ' ' ' ' ' ' '' ' ' ' ' I I ' ' ' ' I I, I I I ' ' ' ~ ' · ~ DSI~-: ~8 , ,I 35~2 ~7 (26 ~2958 ~ :27 ~ ~66 ~ '~2 36~ ~293 3817 :~3 3 DS 1~- 899 22 ~ ............................................ .......... -~O0 -300 -200 - 1 O0 0 1 O0 200 300 E - N COOROINFt"rES NABORS 28E DIVERTER SYSTEMSCHEMATIC ARCO ALASKA, INC. FILL-UP LINE I RISER I FLOWLINE ! I 2000 PSI 10" BALL VALVE 10" BALL VALVE I I CONDUCTOR NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS A VARIANCE FROM 20AAC25.035 10" VENT LINE RESERVE PIT WELL 10" VENT LINE DIVERTER LINES DISCHARGE 100' FROM RIG IGNITION SOURCE. ALL TURNS ARE 90° TARGET TEES. JG 8/6/87 13-5/8 '-5000 PSI BOP STAC - DIAGRAM ACCUMULATOR CAPACITY TEST I I REYENTER~ cI i~] I I PI PE RAMS BLI ND RAMS DRILLING SPOOL DRLG SPOOL CSG PIPE RAMS / . ]~ 13-3/8" STARTING HEAD ALL BOP EQUIPMENT 5000 PSI RATED 11. 12. 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS :3000 PSI WITH 1 SO0 PSI DOWNSTREAM OF THE REGULATOR. :3. OBSERVE TI ME, THEN CLOSE ALL UNITS SI MULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TI ME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. R U N I N LOC K DOW N SC R EWS. :3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4. FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF :3 MINUTES, THEN TEST AT THE HIGH PRESSURE. 6. INCREASE PRESSURE TO :3000 PSI AND HOLD FOR A MINIMUM OF :3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST :3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST :3 MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. BLEED PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR AT LEAST :3 MINUTES. 1:3. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL VALVES ARE SET IN DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI, 16. CHECK OPERATION OF DEGASSER. 17. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 18. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. GSW 11/07/88 ARCO Alaska, In?~'"~ Post Officc .)x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 3, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- ion Plat Dear Mr. Chatterton' Enclosed are as-built location plats for the subject wells. questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG'pk GRU13/11 Enclosure If you have any RECEIVED UAYo 1 88 Alaska 0il & Gas Cons, Commissiort Anct~ot'age ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany o3.~ - ~. ,.11 ~ · 1 / 7:./iN. 055 c~ 3/I r.,, I ~. ION. 034~// '~ $ 2 ! ICi " 10 , ~ ~ 160 l ~ OI LOCATED W/[NIN PNOTN~C~ED $EC. 9~108., 150 o~ I,~ o~ ' ~' o24P0°', j ~ .I 14o 14.~7 Y=5, 937,968.23 LA~.= 70°14'10..J~0 " I~ ~ . ~ 03 I , i ~~!l ~ 04 I~ k ~l X=674,8~5.286 , LONG.=I40°35 17.036", j I~~ J ~365' EN.L.~ 1636 EE.L. ELEK= 42.0 ~1o ~ J I ~ ~60 ~ j ~ 06 14'30 y=5,93X,910.5~ LRE= 70°14'09 ~ I ~ ~oo , % OX ~ ,~ X= 674,878.91 LONG.=I48°35'I6.680' ] ~ ~ ~ 24PI 'FN.L., 16P3'~E.L. ELEV. = 42.0 ~ j ~ Oe ~ J ~ j ~ 9-~0 · ~ ~ ~ ~ 036 ~ ~ , I i i4'3~ Y=5,93X, 793. P5 L~=70°l4 08.$30" 37e ~ ~ 03?-R j X=674,906.56 LON6.=I40°35'IS. 955" 38 · ~~ ~o' I~0 ~ Po0, 39 ~ P~ P?o ,, t40 · 14.40 Y=R937,67~.X6 LAT.= 70°14'07.470 PlO '~ - X:SX4;934. PO LONG.=I4O°BO'IS.P~O' P656' FN.L., 15?4' EE.L. ELEK = 42.7 LEG END NO TEE 0 EXIS~IN6 WEL& L BASIS OF LOCATION IS D.S. ~4 CONDUCTORS · CONDUCTOR AS-BUILT 20~21 AS 8U/LrS PER VECO, /NC. ~. ~ COORDINATES SHOWN ~RE A.S.R ZONE N~O ~7 DATUM. EEC :,iVED I HEREBY CERTI~ THAT I AM ~o~ PROPERLY REGISTERED AND ARCO Alaska, Inc. LICENSED TO PRACTICE LAND ~['~~~~]' "' : ' " - SURVEYING IN THE STATE OF ~'~"~'~=''""'~' D~/&& E/T~ A~S~ AND THAT THIS ~T ]~. .~S ~~~ CO~DUC~O~ ~~.~ RE~ESENTS AN AS-BUILT' SU~EY 'Ji~'~.~~~~ ,~/~ ~ ~ AS- BUILT LOCA TI ON MADE BY ME, AND THAT ALL ~ee~2~ ' DIMENSIONS AND OTHER DETAILS '''--' t~ t ~tJ[~, J~. ARE CORRECT, AS OF: i~ ~ [ I~ ~' ~~' ~,,. I. ox I oo,, I o,,~,,'~'~,I =o~V o,~.oo.,..~e~-~7Ro- 0O4 CHEC~ LiST FOR N~ WT~L ~ERMITS APPROVE DATE Company ~rc~o J~. Lease & Well No. ~ TES NO the per:tit fee attached .......................................... ~-- ---. (2) Loc thru '-8) . 3. 4. 5. 6. 7. (~ =h~ I3) I0. (10 ~d 13) 12. 13. (i4 eh~ 22) I4. 15. ... (23 thru 28) . . . 16. 17. 18. 19. 20. 21. · 22. 23. 24. 25. 26. 27. 28. Is well to be located in a defined pool ............................. Is well located proper distance from property lime .................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in Chis pool ............ Is well to be deviated and is wellbore pict included., .............. Is operator the only affected party " leeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee Can permit be approved before fiftaen-day-wai= ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... /~ Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~' Does the well have a unique name and number ........................ r ~, Is conductor String provided ........................................ Will surface casing protect all zones reasonably expected =o serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement cie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be k/eked off from an existing wellbore ............. Is old wellbore abandomment, procedure included on 10-403 ............ ' Is adequate wellbore separation proposed ............................ Is a dtverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~ . psig .. Does the choke man/fold comply w/API R~-53 (May 84) .... ' ............. Is the presence of HZS gas probable ................................. (29 thru 31) ~or 29. 30. 3I. eXPlorato~' and Stratigraphic wells: Are data presented on potential overpressure zones? ................. ,, ,, Are seismic analysis data presented on shallow gas zones ............ , If an offshore loc., are survey results of seabed conditions presented .... [6) Add: ~ology: ,c Eng~n. eering: ~v: 08/11/88 ,01i 32. Additional requirements ............................................. ,PooL, ~ot~o 'u~iziAn CLASS STATUS 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. PROGRAM: LISCAN REVISION: 5.1 PART NUMBER: OSI Y-3 c¡ T ctp.Q- ;tJ:. 31.£J II I 0 f ~ +- CWOJJd W5790-~' ~, Start of execution: Fri 6 JAN 89 2:50p 'LIS CUSTOMER FORMAT TAPE' **** REEL HEADER **** LIS 88/12/12 ATLAS 01 **** TAPE HEADER **** LIS 88/12/1 2 3462 0'1""" 'OIfL (RUN ...2)/' BHC, CZa. RAW DATA, CZD/CN1POR., CHCN (RUN 1)' FILE # 1 MAIN .001 **** FILE HEADER **** 1024 M lellFllMID Date CN W,N FN CDUN STAT : ARCO ALAS«A INC. : D. S. 1 4 -3 9 ./ : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE' 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 16 CURVES: NAME CHT GR RILM RILD 1 2 3 4 CODE SAMPLE# UNIT 68 1 La 681 API 68 1 OHMM 68 1 OHMM BYTES 4 4 4 4 ~ Kf'"'OC 68 1 OHMM 4 6 SPD 68 1 FT 4 7 TTEN 68 1 LBS 4 g CAL 68 1 INCH 4 9 TEMP 68 1 DEGR 4 10 SP 68 1 MV 4 11 AC 68 1 US/F 4 1 2 ACQ 68 1 4 13 T2R2 68 1 US 4 14 T2R1 68 1 US 4 15 T1R2 68 1 US 4 16 T1 R1 68 1 US 4 * DATA RECORD (TYPE# 0) 958 BYTES * DEPTH CHT GR RILM RILD RFOC SPD TTEN CAL TEMP SP AC ACQ T 2R2 T2R1 T1R2 T1R1 9812.000 155.5469 17.78207 2.669974 2.794502 2.780246 16.99831 3257.075 0.0000000 160.0840 -17.07829 989.1819 0.0000000 553.6875 414.1250 553 . 6 8 7 5 553.0000 9762.000 663.2800 17.80267 4.289513 4.458605 5.451232 25.03320 4324.977 -O.41O9999E-01 160.0840 -17.72589 71.99237 0.0000000 408.8750 562.1250 560.1500 409~OOOO 9712.000 678.1343 17.40219 1.458519 1 .437522 2.038669 22.61011 4348.563 0.5349995E-01 159.2007 -15.67175 93.80193 0.0000000 491.5000 667.6250 668.3125 492.2500 9662.000 656.4507 21.91963 8.896378 12.09089 10.30135 20.99789 4280.254 0.7120000 160.1831 -26.03682 86.56372 0.0000000 456.8125 624.0625 623.5000 454.5625 9612.000 653.8081 20.15199 10.58653 16.46529 16.71271 20.79189 4265.566 -0.2190000E-01 159.0265 -25.92612 92.77095 0.0000000 471.0000 651.8750 654.6875 469.9375 9562.000 663.8052 19.24609 13.78732 26.74904 18.01254 20.03369 4253.199 -0.7400002E-02 156.3929 -28.93376 85.29033 0.0000000 450.0625 635.8750 640.8750 449.5000 9512.000 679.0239 33.37437 11.46332 19.73224 16.72557 1 6 . 9 9 83 1 4238.102 0.5227997 154.7451 -44.13861 88.24205 0.0000000 473.8125 666.5000 666.8125 469.7500 9462.000 664.5452 40.98628 10000.00 5.232960 0.2106863 30.99692 4249.715 -4.312201 1 5 3 . 7 561 -17.73456 43.91295 0.0000000 330.2500 415.5000 401.2500 324.4375 9412.000 658.5098 5 5. 91 1 91 1.846972 1.823451 2.078362 39.99599 4245.000 0.6075001 152.5696 -28.68126 59.18159 0.0000000 309.5000 "..,4,§é~~,.?3?~. """-"""''',,-"-"""" - 4j~.jUUU j('4.18(5 9362.000 662.5862 58.31506 1.851968 1.830389 2.078666 39.63809 4223.742 0.7660007E-O1 151.7274 -24.15318 59.18159 0.0000000 309.5000 .486.9375 433.5000 374.1875 9312.000 665.2058 62.36493 1.847403 1.825959 2.068314 39.99599 4201.914 -0.3560000 150.6145 -35.32582 59.18159 0.0000000 309.5000 486,. 9375 433.5000 374.1875 9262.000 645.2751 52.93027 1.844738 1 .823660 2.073843 39.99599 4196.383 0.0000000 149.6674 -33.05872 59.18159 0.0000000 309.5000 486.9375 433.5000 374.1875 TOTAL DATA RECORDS: STARTING TAPE DEPTH = **** FILE TRAILER **** 82 9812.00 ENDING TAPE DEPTH = 9244.00 FILE # 2 REPEAT.aO2 **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 16 CURVES . . NAME CODE S.AMPLE# UNIT BYTES 1 CHT 68 1 LB 4 2 GR 68 1 API 4 3 RILM 68 1 OHMM 4 4 RILD 68 1 OHMM 4 5 RFOC 68 1 OHMM 4 6 spa 68 1 FT 4 7 TTEN 68 1 LBS 4 8 GAL 68 1 INCH 4 9 TEMP 68 1 OEGR 4 10 SP 68 1 MV 4 11 AC 68 1 US/F 4 12 ACQ 68 1 4 13 T2R2 68 1 US 4 14 T2R1 68 1 US 4 15 T1R2 68 1 US 4 16 T1R1 68 1 US 4 * DATA RECORD (TYPE# 0) 958 BYTES * DEPTH CHT GR RILM RILD Rf-UC SP T1R2 9813.000 2.784919 -17.93222 550.5625 9763.000 5.279784 -19.55864 559.6875 9713.000 2.013931 -15.25273 675.5000 9663.000 12.78994 -23.60361 613.5000 9613.000 13.43568 -27.34373 637.4375 9563.000 1 7 .32813 ;"';29:~~:'3'5:54;9 " 6 41 . 687 5 9513.000 16.78091 -56.10045 657.5000' 9463.000 0.2105589 -15.42848 433.5625 9413.000 0.2105589 -18.54216 435.8750 SP~ AC T1R1 55.37727 20.99789 71.78970 408.0000 572.3867 30.62051 71.63788 405.8750 603.7122 30.99692 94.65099 495.1875 604.6445 20.23380 82.12256 443.5625 613.0986 21 .62950 93.55473 471.6875 619.8291 21.82741 Bft:'94'179' " 463.3125 634.9441 22.22771 89.90999 474.0000 656.7778 24.99751 51.93152 371.6875 656.4072 24.99751 23.87262 371.2500 TOTAL DATA RECORDS: STARTING TAPE DEPTH = ****FILE TRAILER **** FILE # 3 MAIN.003 TTEN AC Q 15.04638 3159.484 0.0000000 18.86430 4306.371 0.0000000 1 6. 5390 6 4354.039 0.0000000 21.72853 4279.434 2.000000 30.04932 4256.699 0.0000000 20.20644 4243.422 Ö~oõ!/aàä'êfÖ' ' 29.93633 4238.367 0...0000000 37.92476 4223.934 0.0000000 29.40881 4208.578 0.0000000 59 9813.00 CAL T2R2 2.668944 -1.000000 412.7500 4.284041 0.1702000 406.2500 1.477009 -1.262601 489.7500 8.821898 -0.9960002E-01 446.2500 8.898819 -0.7945001 469.6250 13.49313 -0.8250002 4 6"O~ 68'15 ' 10.88539 0.4729000 474.0000 1 0000.00 "'3.935600 3 24 . 81 25 10000.00 -4.000000 369.1250 ENDING TAPE DEPTH = ****FILEHEADER **** 1024 TEMP T2 R1 2.799258 152.5848 557.3750 4.612482 152.5848 558.5625 1 .41 0364 152.6951 678.0000 11.75195 154.6408 614.0625 14.24500 154.3029 638.5625 26.14125 ,154.5243 '63'ä.3isÖ 19.53772 154.4962 655.9375 4.305959 1 53. 78 51 489 . 68 75 \ 6.615063 152.5780 400.0000 9405.00 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 1Q CURVES: NAME GAL CN GNC GR SSD SSN LSN lCOR lDEN SPD TTEN HRD1 HRD2 SFTS SHR RB CHT PE PORI 1 2 3 4 5 6 7 8 Q 10 11 12 13 .14 15 16 17 18 19 * DATA RECORD DEPTH SSD sPa SHR 9302.000 688.9314 43.99561 0.3199681 9352.000 2328.137 43.99561 0.1753569 9402.000 2356.404 42.03151 0.2116181 9452.000 2529.097 26.30669 0.1885090 9502.000 7311.098 CODE SAMPLE# UNIT 68 1 INCH 68 1 PCT. 68 1 PCT. 68 1 API 68 1 CTS 68 1 CTS 68 1 CTS 68 1 GMCC 68 1 GMCC 681FT 68 1 LBS 68 1 CTS 68 1 CTS 68 1 CTS 68 1 DIM 68 1 DEG 68 1 LB 68 1 BARN 68 1 PCT (TYPE# 0) 966 BYTES * CAL SSN TTEN RB CN LSN HRD1 CHT BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 8.732695 133.9866 4464.754 185.0289 39.69954 31.99681 182.9817 823.3594 8.732695 118.7387 4491 . 164 18 8 . 5 31 7 63.59045 23.78519 354.1289 811.6694 8.732695 168.5705 4482.484 183.6639 30.56796 45.46252 297.2375 799.7678 8.838461 143.1669 4459.207 185.3783 34.05705 35.11189 288.5237 807.0317 8.521156 269.9614 19.38400 110.7018 CNC lCOR HRD2 ' PE 43.69954 -1.679338 236.9763 9.056959 67.59045 -0.7627128 634.6882 20.81598 34.56796 -0.7246037 461 . 4 14 6 16.78831 38.05705 -0.6880603 520.8604 18.33548 23.38400 0 . 1 6 7 61 2 5~E - 0 1 GR ZDEN SFTS peRl 60.31474 1.487967 73.99261 70.42621 53.72055 2.054115 205.8760 36.11421 39.37837 2.188053 150.8817 27.99677 87.39252 2.252699 163.4504 24.07884 ¿6.ð¿6YU 0.6827630 4,¿1.8,¿ 188.2677 9552.000 7726.547 25.99739 0.6645461 8.415386 276.4753 4500.113 184.4848 9602.000 7483.902 25.99739 0.6641612 8.415386 285.0059 4493.465 184.6252 9652.000 7964.891 26.12399 0.7337331 8.439037 264.3833 4592.094 183.7205 9702.000 6756.609 25.99739 0.5016561 8.357298 256.5945 4605.000 183.7878 " 9752.000 7752.676 25.99739 0.8148751 8,405359 330.9700 4541.801 tg3~4531 9802.000 7781.730 27.18480 0.7287822 7.992309 379.9619 3 3 8 8 . 36 8 195.0215 TOTAL DATA RECORDS: STARTING TAPE DEPTH = **** FILE TRAILER **** FILE # 4 REPEAT.OO4 9¿8.9116 814.1863 21.44310 103.6863 1206.818 775.0029 20.93207 111.4353 1093.320 785.0078 21 .33896 90.38463 1241.518 832.4761 20.85307 , 91.32040 831.7698 833.4946 16.56480 152.4441 1173.663 822 . 7678. 14.56135 201.9798 1321.584 177.1763 85 9302.00 1209.627 2.276893 25.44310 0.7629204E-03 1493.238 2.274932 24.93207 0.2504219E-01 1368.353 2.341974 25.33896 0.1854203E-01 1536.052 2.333906 24.85307 O.1243292E-01 1037.499 2.1914?7 20.56480 0.2151001E-01 1428.037 1.757067 18.56136 0.0000000 1610.457 2.897564 ENDING TAPE DEPTH = **** FILE HEADER **** 1024 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 19 CURVES: NAME CODE SAMPLE# UNIT . " BYTES 766.0012 22.50510 27.97743 2.387828 1037.527 15.88920 20.77411 2.308252 961.3376 20.71196 31.77679 2.367593 1079.390 17.11557 87.54166 2.350604 696.4102 18.14519 18.47469 2.314761 1064.475 20.31749 22.67448 2.490617 1168.037 9.659565 9806.00 1 CAL 68 1 INCH 4 2 CN 68 1 PCT. 4 3 CNC 68 1 PC T. 4 4 GR 68 1 API 4 5 SSD 68 1 CTS 4 6 SSN 68 1 CTS 4 7 LSN 68 1 CTS 4 8 ICOR 68 1 GMCC 4 9 IDEN 68 1 GMCC 4 10 SPD 68 1 FT 4 11 TTEN 68 1 lBS 4 12 HRD1 68 1 CTS 4 13 HRD2 68 1 CTS 4 14 SFTS 68 1 CTS 4 1 5 SHR 68 1 DIM 4 16 RB 68 1 OEG 4 17 CHT 68 1 LB 4 18 PE 68 1 BARN 4 19 PORI 68 1 PCT 4 * DATA RECORD (TYPE# 0) 966 BYTES * DEPTH SSD SPD SHR GAL SSN TTEN RB CN LSN HRD1 CHI 9804~Ot),O 8009.203 19.991'99 0.7999202 .'g:O98"O7i6 " 364.9634 3135. 086 1 91. 6463 . 15~OO'ÖOO 197.9802 1 347.865 122.1558 9754.000 8063.395 24.99751 0.7923622 8.414614 340.4314 4515.230 180.4756 16.75920 151.4189 1306.643 756.2646 9704.000 7746.262 25.16791 0 . 681477 2 8.415005 256.3718 4652.113 182.3800 21.28847 86.86481 1194.446 , 8 18 . 189 2 9654.000 7967.691 24.99751 0.7175031 8.523346 265.3872 4592.195 181.0323 21.35219 96.39183 1261 .788 825.7742 9604.000 7861.500 24.99751 0 . 6 7 7 9 08 2 8.413588 2 7 0 . <] 48 7 4556.270 183.0410 22.20161 98.80029 1302.449 832.3450 9554.000 7616.574 24.99751 0.6295421 8.413589 260.7354 4535.699 182.2457 19.80923 93.34401 1145.538 810.7893 CNC ZCOR HRD2 PE f9.00000 0.0000000 1556.844 3.000000 20.75920 0.365S951E-01 1603.920 1.871947 25.28847 0.3483300E-01 1531.947 2.062959 25.35219 0.1139269E-0.1 1579 .852 2. 745439 26.20161 0.5757686E-02 1545.411 2.165174 23.80923 0.1157160E-01 1422.860 2.513020 GR IDEN SFTS PORI , '32.01105 2.50006.2 11 57 . 88,4 9 . 0871 33 26.50406 2.348102 1144.770 18.29686 50.42854 2.267198 1082.240 23.20012 \ 34.19994 2.325296 1110.803 19.67899 24.75095 2.29514.7 1136.696 21.50623 23.60495 2.359179 974.0896 17.62552 9504.000 7802.223 25.72368 0.4526161 9454.000 2316.476 25.99739 0.1794341 9404.000 2368.335 38.88692 0.1900349 9354.000 2660.345 41.99582 0.1660251 8.521156 262.6450 4518.129 184.6779 21.84183 95.46062 1120.202 809.5979 8.790390 136.6478 4447.313 183.2958 21.92664 30.93179 243.8833 802.3315 8.732695 166.4098 4467.695 181.7359 29.46814 46.57011 285.8904 787.6440 8.732695 123.0157 4459.375 185.4892 53.73537 20.43051 470.9375 777.8909 TOTAL DATA RECORDS: STA~TING TAPE DEPTH = **** FILE TRAILER **** FILE # 5 CHCN .005 1024 82 9804.00 ENDING TAPE DEPTH = **** FILE HEADER **** * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 19 CURVES: NAME CAL CN CNC GR SSD SSN LSN ZCOR ZDEN spa TTEN HRD1 HRO2 SFTS SH R 1 2 3 4 5 6 7 8 9 10 11 1 2 13 14 1 5 CODE SAMPLE# UNIT 68 1 INCH 68 1 PCT. 68 1 PCT. 68 1 API 68 1 CTS 68 1 CTS 68 1 CTS 68 1 GMCC 68 1 GMCC 681FT 68 1 L8S 68 1 CTS 68 1 CTS 68 1 CTS 68 1 DIM 8 Y TE S 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 25.84183 0.1319967E-01 1352.636 2.039928 25.92664 -0.6520078 410. 3430 22.85133 33.46814 -0.7466508 412.5532 17.95609 57.73537 -0.7533976 758.1155 18.10313 164.4895 2.247772 1014.495 24.37743 50.07947 2.180603 117.0944 28.44829 32.57568 2.196395 134.5291 27.49120 53.56711 2.138024 231 .0372 31.02881 9316.00 16 17 18 19 I<B CHT PE paRr 68 68 68 68 1 1 1 1 OEG LB BARN PCT 4 4 4 4 * DATA RECORD (TYPE# 0) 966 BYTES * DEPTH CAL CN CNC GR SSD SSN LSN lCOR lOEN SPD TTEN HRO1 HRD2 SFTS SHR RB CHT PE peRl 9494.000 6427.359 27.99719 0.5199482 9444.000 2450.194 45.60449 0.1938370 9394.000 2673.983 53.11540 0.20/+,8990 9344.000 2575.830 5,3.31551 0.2150182 9294.000 2623.405 53.11542 0.2145630 9244.000 2299.944 52.83832 0.1995102 9194.000 2370.196 52.92714 0.1958371 9144.000 2570.532 53.30893 0.1760922 9094.000 2335.819 1.434618 202.9797 4001.200 192.0738 1.496303 155.6687 4457.430 188.0251 1.435380 123.2794 4467.016 '188.9,$15 1.433200 1 20 .1 07 6 4443.738 189.0562 1.540386 124.7967 4426.738 188.5068 1.540386 136.6041 4399.648 188.3785 1.540386 129.4282 4377. 238 189.5135 1.434618 122.3018 4324.410 188.0801 1.434999 122.1837 15.00000 57.99416 677.9321 533.9741 38.35628 38.71335 264.0659 784.6982 29.86017 25.04074 415.5571 781.2236 7 3 .1 541 3 23.19276 419.4636 771.7034 71.07095 21.94089 418.5623 766.1082 63.22186 2 7. 3 2, 5 9 4 251.7160 761.5701 56.82948 25.59872 281.9199 776.4883 72.67300 22.14656 392.4592 764.6182 60.86501 22.76155 19.00000 0.0000000 835.9165 3.000000 100.0345 2.499992 561.9438 9.091352 42.35626 -0.6322886 398.2239 20.82561 154.7813 2.240404 112.2838 24.82397 33.86015 -0.6869525 688.1389 20.15105 55.57457 2.192628 203.5195 27.71950 77.15413 - 0 . 7 4 43 6 66 622.6406 21.58055 57.91046 1.981384 219.4552 40.52216 75.07095 -0.7782956 586.5994 1 6 . 91 893 56.96446 1.933787 199.2700 43.40681 67.22186 -0.9168090 472.7666 18.22989 59.22794 2.115964 145.1225 32.36580 60.82948 -0.7470757 451.8965 16.69571 62.85707 2 . 1 45 91 7 151.4017 30.55048 76.67300 -0.7131679 652.8032 17.83936 59.70329 2.065330 204.7633 35.43456 64.86501 -0.7345179 61.12744 ,,2 I!q~?Q~,6 " " ".." '" ,"' ."..."",."", . :>5.5:>5:>1 0.1495070 9044.000 2615.921 54.15691 0.2220950 8994.000 1960.730 53.11050 0.1700040 8944.000 2350.573 53.20081 0.2044232 8894.000 2625.997 52.62424 0.2195311 8844.000 262'0.387 53.29810 Q'~2 CrS9ltt2 8794.000 2134.644 53.35260 0.1711781 8744.000 2509.066 51.79460 0.1646480 8694.000 2552.865 50.39531 0.2061771 8644.000 2585.691 50.09772 0.1757001 8594.000 1432.196 49.94211 0.1772799 8544.000 2700.735 '" ~ 4.:>1/.949 189.1903 327.2373 758.7578 1.434618 121.7479 4320.750 188.6138 52.69215 23.05016 387.8840 777.8447 1.434618 121.1639 4261.289 187.6167 48.21411 24.94952 260.7896 764.4888 1.434618 121.1314 4281.293 188.4005 84.46355 23.17171 260.2649 771.9060 1.434618 121.5415 4 23 5 . 26 6 188.8824 63.74605 23.89101 374.3091 772.8386 1.434618 122.8995 4206.473 1ät~643'2 63.87799 24.79890 423;9595 769. 700'0 1 .434618 118.7011 4171.031 188.3186 80.74638 20.21625 299.5750 769.0286 1.434618 126.8344 4161.953 189.4010 67.03561 26.02760 377.1226 770.2322 1.434618 120.1209 4149.754 189.8021 62.01225 23.42645 413.5420 768.1821 1.434618 121.6555 4115.387 192.9786 63.44975 23.46132 385.3762 787.2825 1.434618 120.0051 4128.051 189.9634 78.99692 22.57500 206.2804 788.6179 1.434618 119.8366 54.68871 22.56108 536.2141 16.77541 56.69215 -0.7363247 659.7915 19.68808 52.21411 -0.7504221 494.3760 16.11116 88.46355 -0.7639967 480.0935 20.80418 67.74605 -0.7159916 656.4053 15.49854 67.87799 -0.7413085 643.71.61 18~22991 84.74638 -0.7647766 489.0232 14.67000 71.03561 -0.7324618 524.3408 20.93024 66.01225 -0.7527264 636.8948 19.31177 67.44975 -0. 7138474 573.4739 1 5 . 917 80 82.99692 -0.7247024 33S. 0637 16.76367 58 . 6 8871 -0.7099 42 145.7385 36.20386 56.59505 1.994906 213.3950 39.70262 52.41544 2.039274 150.6393 37.01367 54.62863 2.058895 146.6319 35.82452 56.28122 2.050122 ~218.4525 36.35622 60.11179 2.018694 227.1969 38.26096 52.04987 1.993303 139.7001 39.79979 56.60396 2.015400 184.8717 38.46060 55.62187 2.005681 226.8872 39.04962 77.15445 2.046036 208.8073 36.60388 139.8634 1.994910 96.80562 39.70239 104.7667 .160946 ,U.1¿161 0.2298990 4094.429 189.7675 370.7346 791 .2268 8494.000 2499.187 49.63121 0.1834602 1.434618 119.7875 4069.875 188.9114 84.44279 21.69490 359.6128 784.8901 8444.000 2231.917 49.93861 0.1767203 52.45993 28.19415 265.5076 796.9529 1.434618 133.6096 4056.626 189.6547 8394.000 2458.235 50.28581 0.2191740 1.434618 126.8421 4024.713 189.0258 62.51848 25.68063 329.9409 788.0049 8344.000 2452.213 50.70941 0.2025852 1.434618 132.8413 3986.999 188.9326 58.97629 25.71907 2 98 . 2 712 779.8337 8294.000 1405.116 49.83052 0 .~'151i3070 1.434618 133.6052 3988.616 188. 6709 64.21437 26.66885 162.3694 78S.6709 8244.000 2 25 2 . 73 6 50.16542 0.2618309 1.434618 128.0989 3904.206 189.6152 46.78049 23.43985 253.0011 780.7131 8194.000 2448.555 50.41522 0.1929170 1 . 43461 8 147.6471 3930.878 188.3097 42.90414 32.20955 300.6606 776.9678 8144.000 2367.710 50.7419,1 0.1957880 1.434618 139.8448 3882.739 187.1273 44.91002 30.07126 329.6543 775.4285 . 8094.000 2321.934 51.14651 0.1343360 1.434618 128.2042 3872.130 189.1108 56.56546 25.82114 310.4143 779.8013 8044.000 2493.735 51.51514 0 . 1 994 74 0 1.434618 138.4753 3864.642 189.3691 49.33844 30.76938 298.8848 789.1262 7994.000 2370.777 1.434618 122.3821 52.99107 23.07600 580.9141 17.04243 217.9170 29.63963 88.44279 -0.7241842 563.1060 17.53291 88.57739 2.099081 180.8888 33.38901 56.45993 -0.6857442 432.3953 18.13768 51.51335 2.142709 151.8749 30.74490 66.51848 -0.7322255 519.5859 19.12875 71.77563 2.150415 156.4982 30.27783 62.97629 -0.6470088 452.5754 14.73150 72.56506. 2.222794 174.0422 25.89128 68.21437 -0.7632097 3 1 2. 68 21 15.32442 79.41103 2.203800 89.19681 27.04239 50.78049 -0.7330508 437.8381 23.40955 95.54135 2.314050 156.2974 20.36061 46.90414 -0.7272795 445.6628 16.66153 72.84552 2.175752 166.0187 28.74231 48.91002 -0.7262681 497.7800 22.23866 106.9034 2.170667 162.4211 29.05049 60.56548 -0.7153571 460.7927 20.49376 85.57310 2.229654 156.4890 25.47548 53.33844 -0.7593485 507.9517 30.27223 81.16920 2.231978 1 6 7 . 1 41 3 25.33463 56.99107 -0.7104330 105.9821 2.190597 ~'1.~1:St\61 0.1883321 j8j6.164 189.1838 7944.000 2514.741 51.21893 0.2041271 1.461483 133.1300 3806.664 188.8509 7894.000 3147.884 51.24791 0.1745521 1.434618 130.5313 3800.916 189.3003 7844.000 3131.550 51.43231 0.2156380 1.459685 125.2182 3786.824 188.3615 7794.000 1628.172 52.09222 0.2299272 1.434618 134.9288 3759.545 188.1499 7744.000 2 333 . 93 0 51.68871 0" ."1'5 0 1~'(J'2 0 1 . 4 3 4 618 127.3448 3735.136 1'88 .461)5 7694.000 3214.069 51.34802 0.2127010 1.434618 127.4185 ' 371,,4.211 187.6251 7644.000 3318.479 51.84962 0.1956409 1.434618 122.4638 3689.336 186.9359 7594.000 2908.816 50.89212 0.1977850 1.434618 128.3602 3658.419 188.3556 7544.000 3 614 . 71 3 51.46202 0.1958029 1.434618 117.6914 3699.622 187.8798 7494.000 3068.408 51.17172 0.1783038 1.434618 129.5778 36 7 ~ . 3 5 1 187.4491 7444.000 3041.203 1.434618 123.6395 "'." " "'.'" j¿8.868i 782.3591 44.60808 27.16655 311.3215 774.8247 45.75975 30.70001 487.2495 780.7991 53.24908 27.49399 447.2874 790.5469 60.10353 29.81017 237.1809 783.4863 52.78563 25.78882 308.5547 '787~5146 44..44026 28.89696 536.9294 787.6997 49.76643 24.95033 677.7363 784.6550 44.71014 27.68.373 465.3137 781.4043 47.97845 22.41481 903.7266 799.7446 49.24054 25.82260 458.9973 794.3281 59.81929 26.99213 531.9292 19.68811 48.60808 -0.6870688 473.1787 17.68254 49.75975 -0.6632473 808.1287 19.74405 57.24908 -0.6092494 707.5347 17.56522 64.10355 -0.6623356 296.6792 19.01097 56.78564 -0.9597553 522.5623 14.65132 48.44026 -0.6360427 820.7063 18.38751 53.76643 -0.6585236 1072.468 19.76022 48.71014 -0.6859970 722.7097 21.93201 5 1 . 9 78 4 5 -0.6147128 1363.711 15.38255 53.24054 -0.5988051 749.0742 1 9 . 1 96 01 167.1551 27.84262 62.37881 2.170357 157.4821 29.06927 53.78909 2.123630 267.1477 31.90123 50.20734 2.155671 261.2041 29.95930 47.57776 2.017507 122.5789 38.33292 50.18005 1.968347 160.4596 41 . 31 232 51.75142 2.110392 269.0225 32.70352 52.00392 2.009366 355.6311 38.82629 51.94176 2.048502 279.4385 36.45441 51.47688 1.833755 478.1211 49.46941 51.26230 2.088883 236.5717 34.00705 ~1.1¿t4~ 0.2009390 7394.000 3618.635 51.58873 0.1850000 7344.000 3368.318 52'.27443 0.1777689 7294.000 2923.390 52.71510 0.1901459 7244.000 3240.742 52.16302 0.2127t01 7194.000 2919.249 52.23871 a';175S0'8';1' 7144.000 3457.141 52.43083 0.1807361 7094.000 3374.737 52.66202 0.2072299 7044.000 3413.950 52.83241 0.2128171 6994.000 3440.651 52.73581 0.1806540 6944.000 3270.603 52.59442 0.1954541 6894.000 3023.275 ~641.194 186.2733 1.434618 106.3229 3604.646 187.1572 1.434618 118.5458 3598.093 187.8466 1.434618 132.6353 3581.281 188.3676 1 .434618 117.8421 35 5 9. 40 5 188.1877 1.434618 122.7675 3533.076 1'87;1383 ' 1. 43461 8 120.8793 35 1 4. 94 2 1 88 . 351 2 1.434618 117.4560 3473.879 187.4491 1.434618 124.5537 3475.910 187.4496 1 . 4 0775 2 123.5105 3469.519 187.5652 1.434618 122.2733 3446.993 185.9308 1.434618 124.3175 525.5425 791.6946 52.28865 20.87698 1042.766 775.4333 49.85248 25.56332 671.5149 777.7634 43.27414 28.09760 499.0569 782.1914 53.74742 23.65877 631.6414 780.2124 50.10568 25.18932 584.1062 776.0530 46.79451 23.56693 863.7095 787.3638 48.30441 24.49675 810.1255 782.0500 50.93318 24.99327 675.5935 787 . 5 530 44 .57581 25.36113 657.3557 787.6797 53.88594 24.32071 545.9978 789.4778 50.03152 26.37469 918.3035 17.20277 56.28865 -0.6924933 1671.926 14.23039 53.85248 -0.6203843 1074.362 15.67812 47.27414 -0.6478359 824.4087 16.94965 57.74742 -0.6576142 1018.621 20.68732 54.10568 -0.7253109 968.4055 20.¿~'585 50.79451 -0.6882346 1376.458 16.27863 52.30441 -0.6569957 1367.943 16.28740 54.93318 -0.6540474 1139.844 17.11629 48.57581 -0.6015755 1019.795 16.80397 57.88594 -0.6456320 896.9114 17.44072 287.0552 41.37178 48.83882 1.646548 566.8496 60.81525 53.91498 1.946120 377.1213 42.65936 49.88763 1.954391 284.2803 42.15814 78.48145 1.953806 340.3081 42.19357 76.03012 1.856418 303.7410 48.09589 57.48865 1. 7 8325 3 436.1978 52.53012 67.13156 1.731850 423.8899 55.64546 51.00046 1.908178 358.1108 44.95888 58.75099 1.932716 348.9521 43.47173 51.68918 1 .988777 287.5234 40.07410 :>¿.4o1o¿ 0.2026029 j4¿1.¿,8 136.4055 533.8364 780.1233 6844.000 3424.335 52.92Q21 0.2074651 1.434618 121.1671 3438.664 186.5524 49.02475 24.Q4592 650.8530 798.7837 6794.000 3183.327 52.52742 0.1754810 1.407752 122.7681 3393.086 186.9155 54.93932 24.73544 696.2297 788.1213 6744.000 2974.080 52.71512 0.1918851 1.434618 129.9190 3358.224 187.2194 46.13861 29.88933 585.5361 788.0901 6694.000 3438.267 53. 03252 0.2184930 1.434618 120.8243 3393.994 185.9238 48.18304 29.81326 773.384,3 804.9614 6644.000 3425.182 52.49173 o. 2125'ã6'1 45.33278 26.42685 761.7073 792.61'28 1.432819 122.0764 3323.419 '8'5;9'07'1 6594.000 2651.445 53.74480 0.2552820 1. 434618 147.4646 3313..638 185.8155 44.96161 33.83797 415.2129 795.3713 6544.000 2959.084 53.74141 0.2018959 1.434618 129.7660 3294.067 186.1428 47.01636 29.62146 500.5164 791.7397 6494.000 3345..117 5 3 . 644 8 1 0.2171291 1.434618 112.3916 3264. 203 1 85 . 8889 32.77792 22.38737 798.3577 791.9504 6444.000 2944.205 53.44780 0.1934950 1.407752 131.8985 3263.003 184.1982 43.26334 27.32025 418.5615 8 10 . 6 5 3 6 6394.000 3476.137 53.67940 0.1780782 1.434237 113.8577 3226.296 186.5349 59.74133 23.74162 964.0813 794.6511 6344.000 3260.920 1.380887 110.3055 758.1086 17.74821 265.8245 45.16475 53.02475 -0.5955656 973.0698 15.39112 54.56186 2.022188 339.4612 38.04918 58.93932 -0.6906434 1044.920 21.39532 58.02647 1.835268 372.9592 49.37769 50.13861 -0.8831689 945.2214 18.31609 43.47574 1.938313 316.7285 43.13257 52.18304 -0.6668692 1279.154 18.70958 44.80678 1.790761 445.9880 52.07509 49.33278 -0.6516203 1261.0,67 . 15 ;92 6~7 45.97998 1.871368 411 .0 1 8. 3 47."1S9t9 48.96161 -0.6502028 615.6665 21.02377 48.77034 2.038587 206.8644 37.05534 51.01636 -0.8545724 802.5571 18.70389 35.43082 1 . 9830 31 274.7529 40.42233 36.77792 -0 . 6 6 52 3 31 1264.772 19.24210 37.34999 1.960041 440.0071 41.81567 47.26334 -0.6644279 717.2468 21.23448 49.97246 2.124847 245.6034 31.82741 63.74133 -0.6656928 1589.210 15.69678 42.70186 1.864325 516.8840 47.61668 61 .21977 -0.7598637 56.17937 1.616577 55.~61:SU1 0.1970569 ;,219.215 186.9956 998.4312 801 .1597 6294.000 3224.128 53.71510 0.1904782 1.434618 124.3229 3164.399 185.9271 62.38730 25.87494 658.6794 793.3191 6244.000 3469.748 53.29761 0.1980130 52.86180 23.93736 743.1494 797.0425 1.434618 117.5022 3159.494 186.3010 6194.000 2198.781 52.99472 0.1399860 39.72762 38.42168 351.9648 767.7085 1.434618 149.3000 3159.484 186.4013 TOTAL DATA RECORDS: 554 STARTING TAPE DEPTH = 9494.00 **** FILE TRAILER **** 1523.656 18.42787 66.38730 -0.7465403 1060.536 19.91829 56.86180 -0.6571895 1128.633 17.24936 43.72762 -0.8697729 665.9336 50.88693 ENDING TAPE DEPTH = **** TAPE TRAILER **** LIS 88 1 12] 12 3462 01 TOTAL RECORDS IN THIS LOGICAL TAPE: **** REEL TRAILER **** LIS 88/12/12 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL: TOTAL RECORDS IN THIS PHYSICAL REEL: End of eKecution: 6 JAN 89 2:53p 3 minutes, 23.0 seconds. Fri E 1 a p sed e x e cut ion - t i m)e = SYSTEM RETURN CODE = 0 881 882 882 505.7405 62.63168 44.03627 1.735256 361.8469 55.43901 39.32407 1.969215 385.4126 41.25966 26.45003 1.907779 132.9867 44.98309 6174.00 PROGRAM: LISCAN REVISION: 5.1 Start of execution: Tue 13 DEC 88 3:53p **** REEL HEADER **** LIS 88/12/01 ATLAS 01 PART NUMBER: £)5 /~--37 ¥Þ:# 3?,,~~- 0 f2Wt- #' o-C/ W5790-PE32 MICROfiLMED 0atIt ..JIi)ß/ CD. - ~ ~ r ~ 6.~~ Ç.\~~ ¿ '-.,; 'Y ~~. ~v ~<J ~~ ~CJ ~~~. ~. #~ .~ ~ tp'" ., (/$I 'LIS CUSTOMER FORMAT TAPE' **** TAPE HEADER **** LIS. 88/12/01 3622 01 rDIFL~ MAIN AND REPEAT PASS. FILE # 1 MAIN.001 1024 CN WN FN COUN STAT **** FILE HEADER **** : ARC a ALASKA, INC. : DS 14-39 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 9 CURVES: NAME CHT TTEN SPD SP 1 2 3 4 " ~... ," CODE SAMPLE# UNIT 68 1 LB 68 1 LB 68 1 F/MM 68 1 MV BYTES 4 4 4 4 I, 6 7 8 9 GR1 CAL1 RFOC RIlM RIlO * DATA RECORD DEPTH GR1 6297.000 88.25911 6247.000 79.06569 6197.000 50.13559 6147.000 92.67403 6 097~ot'Ja 86.70041 6047.000 82.29678 5997.000 36.84187 5947.000 64.44858 5897.000 47.04492 5847.000 44.03291 5797.000 66.26967 5747.000 41.44562 5697.000 42.72386 68 68 68 68 68 (TYPE# CHT CAL1 71.98108 11.31618 460.8181 9.899336 465.0181 10.09619 458.2888 9.339773 463.9456 11.21671 515.3403 10.97261 458.7295 10.24632 492.8220 9.710323 483.8677 9.560818 4 61 . 0474 9.484909 486.4045 9.710459 487.8726 9.533098 475.0430 9.631016 1 1 1 1 1 API IN OHMM OHMM OHMM 4 4 4 4 4 0) 1006 BYTES * TTEN RFOC 1561.444 4.171990 2684.139 3.445775 2675.591 4.354528 2 69 6 . 4 82 4.083832 .2 653~O13 4.220883 2678.307 3.928946 2593.224 4.296968 2626.723 4.216872 2549.718 4.493691 2519.791 3.522217 2537.813 4.068403 2537.310 3.788383 1 2 71 . 4 4 5 4.772995 spa RILM 25.99739 3.697442 48.98921 3.087746 54.23041 1.369473 59.20610 3.801710 55..1.6490 3.705017 49.99501 3.687223 48.83281 1.035188 49.95932 3.587746 49.89171 1.449828 50.45961 1.811895 50.12752 3.257940 50.27463 1.223605 50.95921 1.663065 SP RILD -0.7875713 3.555994 2.881094 2.926618 -76.03072 1.219942 - 6. 82 996 7 3.638535 0.7809712 3.566298 2.876249 3.396281 -77.28685 0.8804128 -2.409757 3.307982 -63.94379 1.421996 -28.99825 1.756908 2 . 4 81 4 0 8 2.963415 -69.54163 1.077706 -60.84921 1.522057 5647.000 40.53331 473.3853 9.595886 2484.337 5.204870 51.90953 3.106370 5597.000 53.66335 473.0466 10.06361 2450.652 3.938720 50.88571 2.155747 5547.000 51.06723 496.4128 10.19029 2450.834 3.644773 50.40121 2.349340 5497.000 42.38776 502.3582 10.38039 2461.913 4.225876 50.86832 1.877139 5447.000 58.14003 485.8225 10.38812 2422.009 4.081261 50.82452 3.000065 5397.000 47.90562 526.0039 10.26404 2423.648 3.133623 59.15640 1.806419 5347.000 65.73128 505.9910 10.53759 2403.884 3.538881 59.31410 3.181226 5297.000 62.00591 59.75011 2.880118 , .' ' 511.5356 11.66964 2398.577 3.925130 5247.000 81.43387 513.2437 11.53746 2384.822 3.939592 59.82951 3.022820 5197.000 31.29922 510.8721 11.61176 2356.704 12.45260 59.99980 8.164688 5147.000 43.48193 510.2869 11.24961 2332.819 3.660539 59.83540 1.875213 5097.000 52.29283 507.4111 1 0 . 8 24 1 8 2300.620 3.607752 59.99402 1.705810 5047.000 92.02286 509.5623 11.25080 2283.328 4.805676 59.99402 3.645169 4997.000 68.12807 499.6873 11.36583 2263.029 4.334867 60.99390 2.737571 4947.000 75.26602 496.5811 11.20824 2241.499 3.711049 60.82939 2.378544 4897.000 44.72203 478.9238 11.62786 2187.481 8.302647 60.19411 8. 79 4 4 5 3 4847.000 525.5957 2209.208 60.42999 -60.25256 -26.14154 2.771181 -25.49091 1.971030 -31.89757 2.229396 -55.09756 1.758443 -9.514284 2.845515 -25.61057 1.641245 5.132054 3.149698 -11.96142 2.597617 1.948096 2.966996 -52.88643 8.051647 -44.83739 1.635909 -43.84988 1.601865 -13.09843 3.700899 -25.16710 2.598265 -34.85809 2.102540 -9.003834 9.407038 .:>1.tt6UU 4797.000 60.78592 4747.000 47.94130 4697.000 27.59718 4647.000 69.63556 4597.000 96.47772 4547.000 76.51881 4497.000 30.04411 4447~OOO 81.66707 4397.000 60.27042 4347.000 65.15317 4297.000 66.22729 4247.000 78.01418 4197.000 42.25409 4147.000 44.42067 4d97.000 77.43518 4047.000 61.70598 10.55/64 508.2542 10.27260 518.8108 10.39547 508.0601 10.39466 519.5784 10.05866 758.7810 9.971365 517.8936 10.48220 514.5603 10.17028 5¿3 .S¿'6 7 10.52877 506.9619 10.02781 508.6807 10.02975 507.3350 9.494347 506.8264 9.121267 502.8748 9.336084 500.4438 9.357708 493.3445 9.371969 488.7400 9.364120 3.888029 2214.195 4.870508 2202.506 4.275623 2131.640 4.037652 2141.453 4.987849 2465.833 4.324265 2096.743 4.797784 2101.138 8.129610 2061~..4S8 4.819510 2037.842 5.053905 1995.815 5.664716 1969.146 5.946578 1953.593 5.604814 1944.641 6.534346 1922.296 6.893521 1897.600 6.419297 1861 .358 7.444829 1.529875 60.26772 5.020141 60.33791 2.878303 60.17032 2.022581 60.15041 4.740436 59.52661 2.779378 59.99402 4.570998 60.37051 6.986188 60.33791 4.187751 59.99402 3.891283 59.77672 4.981236 59.77672 5.734068 59.38171 5.489218 61.02960 4.737661 61.22380 5.724265 61.66917 6.317350 61.41719 7.604790 1.290283 -4.004103 4.735781 -39.60577 2.601175 -54.73587 1.878577 -2.329031 4.753942 -10.63804 2.664456 -6.643231 4.675119 -31.63702 5.791507 -4.173524 4.397583 -24.39671 3 . 77 5 7 8 6 -14.86030 4.914458 -6.830282 6.033992 -4.988009 5.646893 -44.65630 4.447192 -43.20859 5.312163 -6.732560 6.540459 -16.90344 7.427988 3997.000 65.60370 3947.000 42.94530 3897.000 84.60974 3847.000 84.38333 3797.000 75.23346 3747.000 56.24249 3697.000 64.69482 3647.000 67.59633 3S 9 7.. 000 27...78700 502.5024 9.357630 1866.813 7.133195 504.6782 9.359987 1872.871 7.210089 493.8589 9.357983 1795.766 6.646420 513.8159 9.225626 1843.318 5.390882 492.4014 9.349932 1782.221 7.470556 489.2053 9.350534 1752.494 8.871622 500.4080 9.396898 1778.867 8.130901 482.8557 9.665060 1734.137 7..801.071 528.3181 .9.694563 1756.625 0.7016177 TOTAL DATA RECORDS: 217 STARTING TAPE DEPTH = 6297.00 **** FILE TRAILER **** FILE ## 2 REPT .002 1024 61.66699 7.590756 62.00960 5.347632 62.99370 6.417609 62.38849 4.034727 63.36420 7.110705 63.96379 8.853369 64.1 81 09 8.931562 64.55620 8.632277 46.99530 10000.00 ENDING TAPE DEPTH = **** FILE HEADER **** * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT: FT 9 CURVES: NA.ME 1 CHT 2 TTEN 3 spa CODE SAMPLE# UNIT 68 1 LB 68 1 La 68 1 F 1 MM BYTES 4 4 -20.20383 7.318721 -52.76846 4.864161 -7.836270 6.863710 -13.38796 4.219734 -13.16407 7.295251 -30.09740 8.670273 -17.64726 8.919874 -31.46614 9.173395 21.76953 10000.00 3585.00 4 SP 68 1 MV 4 5 GR1 68 1 API 4 6 CAL1 68 1 IN 4 7 RFOC 68 1 OHMM 4 8 RILM 68 1 OHMM 4 9 RILD 68 1 OHMM 4 * DATA RECORD (TYPE# 0) 1006 BYTES * DEPTH GR1 CHT CAL1 TTEN RFOC spa RILM SP RILD 6293.000 52.66232 0.1000000 9.922987 0.1000000 3.919834 0.1000000 2.660943 2.073792 2.477095 6243.000 63.00084 460.3901 9.902096 2724.166 3.386588 38.17250 2.838755 0.9936416 2.761546 6193.000 43.78090 464.7202 9.998838 2689.635 4.417516 52.15712 1.402004 -75.2461..7 1.243128 6143.000 80.19968 460.0999 9.223186 2690.860 4.032717 56.83202 3.743354 -9.990658 3.611878 6093.000 88.25911 439.2764 11..31618 2695.930 4.171990 54.99451 3.697442 -0.7875713 3.555994 TOT A. LOA T AR E C OR 0 S : STARTING TAPE DEPTH = ****FILE TRAILER **** 17 6293.00 ENDING TAPE DEPTH = 6093.00 **** TAPE TRAILER **** LIS 88/12101 3622 01 TOTAL RECORDS IN THIS LOGICAL TAPE: 244 **** REEL TRAILER **** LIS 88/1 2 101 "ATLAS 01 IOIAL KI:LOROS .lNIHIS LOGICAL REEL: TOTAL RECORDS IN THIS PHYSICAL REEL: End of execution: Tue 13 DEC 88 3:54p 1 minute, 18.0 seconds. Elapsed execution time = SYSTEM RETURN CODE = 0 245 245 "