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181-085
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 M-15 OA Downsqueeze Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-085 50-029-20612-00-00 ADL 0028260 9657 Conductor Surface Intermediate Liner Scab Liner 9309 80 2638 8820 1308 1240 9460 20" x 30" 13-3/8" 9-5/8" 7" 5" 9132 28 - 108 27 - 2665 25 - 8845 8349 - 9657 8302 - 9542 28 - 108 27 - 2665 25 - 8577 8136 - 9309 8095 - 9206 9390 2670 4760 5410 10490 None 5380 6870 7240 9910 8863 - 9089 8593 - 8797 4-1/2" 12.6# x 5-1/2" 17# 13cr80 23 - 8305 Structural 4-1/2" Baker S3 Packers (2 ea) 4-1/2" TIW Packer 8029, 7856 / 8170, 7979 8244, 8044 Date: Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 PRUDHOE BAY 12/23/2025 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 No SSSV Installed Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.12.09 13:47:24 - 09'00' Torin Roschinger (4662) 325-749 By Grace Christianson at 3:30 pm, Dec 09, 2025 A.Dewhurst 11DEC25 DSR-12/9/25J.Lau 12/16/25 10-404 JLC 12/16/2025 12/17/25 OA Sealant Downsqueeze Well/PTD:M-15 / 181-085 Well Name:M-15 API Number:50-029-20612-00 Current Status:SI, Not Operable Pad:M-Pad Reg. Approval Reqd?10-403 / 10-404 Regulatory Contact:Abbie Barker Job Type:OA Downsqueeze First Call Engineer:Hunter Gates Phone:(215) 498-7274 Second Call Engineer:Tyson Shriver Phone:(406) 690-6385 Current Bottom Hole Pressure:2355 psi @ 8,600 TVDss SBHPS on 4/6/2024 Current T/I/O:SSV/415/0 psi Max Dev:29.3 deg @ 8,100 MD Min ID:3.725 @ 8,204 MD XN Background: Back in June, M-15 was reported with gas bubbling/gurgling in the conductor/cellar. IA is bled down to about 400 psi and the OA is bled down to 0 psi. MIT-OA w/ both diesel and nitrogen both failed in July. It appears that we may have developed a PC leak and a microannulus in the cemented OA. The plan now is to pump a time activated sealant pill down the OA to isolate the microannulus that has formed in the OA cement downsqueeze. Passed CMIT-TxIA to 2620 psi on 7/3/2025. MIT-OA w/ diesel (1200 psi) and N2 (1000 psi) failed on 7/7/2025 and 7/20/2025, respectively. No returns were seen at surface (conductor by OA annulus) when pressure testing with diesel. Objective: Utilize Seal-Tite time activated sealant to pump an OA top job to resolve the microannulus that has formed in the historic OA downsqueeze. POP well UE and confirm pressure has been isolated. Procedure: Fullbore: 1.IA should be fluid packed with crude. Top off if needed. Valve Shop: 1.ND OA gate valve and NU OA integral. DHD/Seal-Tite: 1.Rig up a heater w/ trunk directed at the base of the wellhead and warm up with sufficient time prior to pumping Seal-Tite to ensure there is a not a layer of freezable fluid that could negatively impact the efficacy of the squeeze job. 2.Once wellhead is sufficiently warmed, perform OA downsqueeze as per Seal-Tite procedure below. 3.Bleed 9-5/8 x 13-3/8 annulus down to 0 psi. Confirm no flow to surface. 4.Open annulus valve and drop weighted soft line down the annulus to tag TOC (expected ~1 down). 5.Install ball valve w/ conduit on annulus valve to carry sealant through the valve into the annulus. 6.RU Seal-Tite pump box and sealant injection cylinder to ball valve on annulus valve and PT. OA Sealant Downsqueeze Well/PTD:M-15 / 181-085 7.Load 3-liter sealant injection cylinder w/ Micro-Seal sealant. 8.Pump sealant from injection cylinder via the conduit into the annulus to work down to the TOC. 9.Monitor annulus pressure build up rate and bleed of any gas/diesel as needed. 10.Refill sealant injection cylinder and repeat injections until minimum of 9 liters of sealant has been pumped in the annulus. 9 liters equates to 1 in sealant height (may need to be adjusted depending on TOC). 11.Refill sealant injection cylinder and repeat sealant injections until maximum of 18 liters is in the annulus. Top of sealant should be at least 6 inches below the wellhead outlet (may need to be adjusted depending on TOC). 12.Pressure up the annulus with diesel to squeeze sealant into the microannulus cement channels. 13.Allow sealant to cure under pressure for 48-72 hours. 14.Reapply annulus pressure w/ diesel as needed during the curing process. 15.PT sealant in the annulus from above to 1,200 psi target pressure. 16.Inflow test annulus to confirm no pressure build up on surface. Ops/DHD: 1.After set-up time has been adequately reached, POP well UE and monitor for OA repressurization. Valve Shop: 1.ND OA integral and NU OA gate valve. Fullbore: 1.Perform MIT-OA w/ diesel to max applied 1,200 psi. Attachments: Current Wellbore Schematic Proposed Wellbore Schematic Sundry Change Form OA Sealant Downsqueeze Well/PTD:M-15 / 181-085 Current Wellbore Schematic OA Sealant Downsqueeze Well/PTD:M-15 / 181-085 Proposed Wellbore Schematic Seal-Tite downsqueezed on OA Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: December 9, 2025Subject: Changes to Approved Sundry Procedure for Well M-15Sundry #: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.Step Page Date Procedure ChangeHNS PreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date 2025-0424_No-Flow_PBU_M-15_bn Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 4/24/2025 P. I. Supervisor FROM: Bob Noble SUBJECT: No Flow Test Petroleum Inspector PBU M-15 Hilcorp North Slope LLC PTD 1810850 4/24/2025: I traveled to Hilcorp’s PBU M-15 to witness a No-Flow Test on the well. Hilcorp representative Ryan Holt and I did a visual inspection of the test rig up and it all looked good. Ryan talked to me about how they were going to perform the test. He plans to shut the well in for an hour and then bleed and do this 3 times. He told me that Hilcorp representative Andy Ogg had their method approved by AOGCC. Both test meter and pressure gauge had current calibrations. The following table shows test details: Time Pressures1 Flow Rate2 Remarks (psi) Gas – scf/hr Liquid – gal/hr 07:32 0/0/9 Shut well in 08:07 8/0/9 08:37 12/0/9 >1800 0 Open to flow through meter 08:42 900 0 08:56 0 0 Shut well in for pressure build 09:14 6/0/9 09:44 12/0/9 >1800 0 Open to flow through meter 09:49 900 0 09:56 0 0 Shut well in for pressure build 10:22 6/0/9 10:52 11/0/9 >1800 Open to flow through meter 10:57 900 11:02 0 End Test 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr The gas rate initially exceeded the meter rating then fell off to <900 scf/hr after 5 minutes and to 0 scf/hr within 10 minutes by the end of the 3rd flow period. The results meet AOGCC criteria for passing a no-flow test. Attachments: none 9 9 9 9 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.05.05 12:31:16 -08'00' Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov May 5, 2025 Mr. Andy Ogg Field Well Integrity Hilcorp North Slope, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Prudhoe Bay Unit M-15 PTD 1810850 Dear Mr. Ogg: On April 24, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Prudhoe Bay Unit M-15. The AOGCC Inspector confirmed that the proper test equipment as outlined in AOGCC Industry Guidance Bulletin 21-001 was rigged up on Prudhoe Bay Unit M-15. The wells performance was monitored for more than 3 hours consisting of 1-hour pressure build-up periods followed by up to 20-minute flow monitoring checks. Gas rates during each flow period initially exceeded 1800 standard cubic feet per hour (scf/hr), declined to less than the allowed 900 scf/hr limit within 5 minutes, and to zero scf/hr within 10 minutes by the final flow period. There was no liquid flow to surface during the no- flow test. The results witnessed by AOGCC on April 24, 2025, indicate a passing no-flow test. Prudhoe Bay Unit M-15 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Prudhoe Bay Unit M-15 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter at the Prudhoe Bay Unit field office. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors PBWellsIntegrity@hilcorp.com 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 M-15 Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 181-085 50-029-20612-00-00 9657 Conductor Surface Intermediate Liner Scab Liner 9309 80 2638 8820 1308 1240 9460 20" x 30" 13-3/8" 9-5/8" 7" 5" 9132 28 - 108 27 - 2665 25 - 8845 8349 - 9657 8302 - 9542 28 - 108 27 - 2665 25 - 8577 8136 - 9309 8095 - 9206 9390 2670 4760 5410 10490 None 5380 6870 7240 9910 8863 - 9089 4-1/2" 12.6# x 5-1/2" 17# 13cr80 23 - 8305 8593 - Structural 4-1/2" Baker S3 Packers (2) 8244, 8044 8029, 8170, 8244 7856, 7979, 8044 Torin Roschinger Operations Manager Hunter Gates hunter.gates@hilcorp.com (907) 777-8326 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 0028260 23 - 8097 N/A N/A 19 Well Not Online 0 1718 1978 0 716 900 N/A 13b. Pools active after work:PRUDHOE OIL 5-1/2" TIW Packer 8029, 7856 / 8170, 7979 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 No SSSV Installed By Grace Christianson at 2:07 pm, Apr 08, 2025 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662) Date: 2025.04.08 12:56:30 - 08'00' Torin Roschinger (4662) DSR-4/11/25 RBDMS JSB 041025 JJL 5/8/25 ACTIVITY DATE SUMMARY 3/28/2025 LRS CTU #2 2.0" Tapered .250-.134" DC-110 Job Objective: Mill CIBP MIRU, Fly bop to the well. ***Function test BOP*** ***Continue on 3-29-25 WSR*** 3/29/2025 LRS CTU #2 2.0" Tapered .250 - .134" DC-110 Job Objective: Mill CIBP Bleed down IA pressure from 1308-845psi, Replace all reel motors. Troubleshoot electronic problems w/ hydraulic controllers. Rig down. Travel to ct shop for repairs. ***Continue on 3-30-25 WSR*** 3/30/2025 LRS CTU #2 2.0" Tapered .250 - .134" DC-110 Job Objective: Mill CIBP At LRS coil shop troubleshooting hydraulic circuits / making repairs. ***Continued on 3-31-25 WSR*** 3/31/2025 LRS CTU #2 2.0" Tapered .250-.134" DC-110 Job Objective: Mill CIBP Continue troubleshooting hydraulic circuits / making repairs. Finish making repairs and testing unit. Travel to M-15, begin rig up. ***Continue on 4/1/25 WSR*** 4/1/2025 LRS CTU #2 2.0" Tapered .250 - .134" DC-110 Job Objective: Mill CIBP Continue rigging up. Fly bop to the well ***Function Test BOP*** MU YJ 2-7/8" milling assem w/ 3.70" RC JM. PT 350/4150psi. Good DHCV test. Load well 4.5bpm 10bbls 60/40 spear, 69bbls slick 1%KCL w/ SL, well too tight to cont bullhead. RIH, Swap ct to KCL, taking returns to OTT. Dry tag plug 9003' ctm. Begin milling. Push plug down to 9390' ctm. POOH. FP well and coil while POOH. Lay down tools. Weekly bop test. ***Complete*** Daily Report of Well Operations PBU M-15 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations ❑ /s��hutdo/�wn Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing 13Chang�fp)r G n ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Pull K -Valve & Set COP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Drill Number. 181-085 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Slratigraphic ❑ Service ❑ 6. API Number. 50-029-20612-00-00 1 7 Property Designation (Lease Number): ADL 028260 B. Well Name and Number: PBU M-15 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 9657 feet Plugs measured 8975 feet true vertical 9309 feel Junk measured None feet Effective Depth'. measured 8975 feet Packer measured 8034, 8172, 8244 feet true vertical 8694 feet Packer true vertical 7860, 7981, 8044 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 28-108 28-108 Surface 2638 13-3/8" 27-2665 27-2665 4930 2670 Intermediate 8620 9-5/8" 25-8845 25-8577 5750/6870 3090/4760 Scab Liner 1240 5" 8302-9542 8095-9205 10140 10490 Liner 1308 7" 8349-9657 8136-9309 7240 5410 Perforation Depth: Measured depth : 8863-9250 feet True vertical depth: 8593-8943 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# x 5-1/2" 17#, 13Cr80 23-8305 23-8098 4-1/2" Baker S-3 Penn Packer 8034 7860 Packers and SSSV (type, measured and 4-1/2" Baker SABL-3 Packer 8172 7981 true vertical depth) 5-1/2" TIE HBBP Packer 8244 8044 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: 19 0 1718 1978 716 Subsequent to operation: Shut -In 650 1340 14. Attachments: (required per20 MC 25.070 25.071, 825.293) 15, Well Class after Work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 319-015 Authorized Name: Infanti, Samuel Contact Name: Infanti, Samuel Authorized Title: Petroleum Engineer Challenger Contact Email: samuel.infantilabp.com il� Authorized Signature: Date: pa Contact Phone: +1 9075645676 Form 10404 Revised 04/2017 //,ro 1/q1 � � IBDMS L^' FEB 1 42020 Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report Of Sundry Well Operations (10-404) February 12, 2020 To Whom it May Concern: Attached please find the Report Of Sundry Well Operations for Well PBU M-15, PTD #181- 085. Since M-15 is within 660' of the Kuparuk River, it requires a SSSV, if it is able to flow by itself. Since we shutoff the lower perforations and added perforations uphole in the Sag formation (12/30/2019), the original plan was to POP the well with gauges in hole to come up with a design for the SSSV. When we went to POP the well on 1/27/2020, the well did not surface any fluids and was eventually shut-in on 1/29/2020. This proves that a SSSV is no longer required, since it cannot flow in its current state, so we decided to not to set one. The well will be shut-in indefinitely and will be looked at for future wellwork opportunities (hydraulic fracturing or sidetrack). When the future wellwork is completed, pending a NFT, the well will be outfitted with a SSSV. Sincerely ;4U6 !/� Samuel Infant i - W Petroleum Engineer GC2 (M&U Pad) BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Daily Report of Well Operations PBU M-15 AfTIVITYnATF SI IMMARY ***WELL FLOWING ON ARRIVAL*** PULL 4-1/2" K -VALVE FROM X -NIPPLE @ 2,126' MD DRIFT FOR CIBP TO 9,354' SLM W/ 3.70" CENT & 2-1/2" S.BAILER DRIFT TO 9,354' SLM W/ 33'x 3.16" DMY PERF GUNS 11/16/2019 ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** ***JOB STARTED ON 29 -DEC -2019*** (SLB SET CIBP) WELL S/I ON ARRIVAL. INITIAL TWO = 1715/1550/0. SET 5" WFT BIG BOY CIBP AT 8975' MID -ELEMENT. LOG CORRELATED TO SLB CEMENT BOND LOG DATED 27 -AUG -1981. LAY DOWN FOR THE NIGHT. NIGHT CAP ON AND TESTED. 12/29/2019 ***JOB CONTINUED ON 30 -DEC -2019*** ***JOB CONTINUED FROM 29 -DEC -2019*** (SLB ELINE PERF) PERFORATE 8860'- 8891' (REFERENCE DEPTHS: 8863'- 8894') W/ 2-7/8" PJO, 6 SPF, 60 DEG PHASE GUN. ALL LOGS CORRELATED TO SLB CEMENT BOND LOG DATED 27 -AUG -1981. 12/30/2019 **`WELL S/I ON DEPARTURE, PAD OP NOTIFIED*** ***WELL S/I ON ARRIVAL— (under eval) DRIFT & BRUSH TO SVLN AT 2,126' MD SET BP GAUGES ON FLOW THRU SUB IN SVLN AT 2,126' MD RAN CHECK SET TO X -LOCK AT 2,126' MD 1/3/2020 ***WELL S/I ON DEPARTURE*** TRIM= 6'CIW V(/3LHEAD= WEVOY ACTUATOR= BAKER KB. ELEV = 51.76' BF. ELEV = 26.46' KOP= 5700' Max Angle = 29'@81W Datum MD = 9150' Datum TVD= 88001SS 9-518" CSG, 40#, L-80, TGA D = 8.835' — 2036' 13-3/8' CSG, 72#, L-80, D = 12.347" 2665' Minimum ID = 3.725" @ 8204' 4-1/2" XN NIPPLE 4-12" TBG, 12.6#,13CIR80, VAMTOP .0152 bpf, D= 3.958" M-15 12& 5-1 CHROME TBG & 5- NOTE: WELL CHROME LNR''" 2023' 95/8' HES ES CEMENTER 2126' 4-12' HES X NP, D = 3.813- 2126' 14 -10'X -LOCK /FLOW THRU SUB & STATIC GAUGES (01/0420) GAS LFT MANDRH.S 8005' —14-12- HES X NP, D = 3.813" ANGLE AT TOP PERF: 26'@ 8863' Note: Refer to Pmduction DB for historical perfdata ST MD TVD DEV TYPE VLV LATCH PORT DATE 01/19/12 4 3654 3654 0MMG 0.6 DOME RK 16 N4ES 2-718' 4 9048 -9086 3 5699 5698 10 MMG DOLE RK 16 01/19/12 2-7/8" 4 9100-9157 S 2 7071 6985 20 MMG DOLE RK 16 01/19/12 4 9220-9250 S 06/18191 1 7934 7773 28 LMC' SO m 24 01/19!12 8005' —14-12- HES X NP, D = 3.813" ANGLE AT TOP PERF: 26'@ 8863' Note: Refer to Pmduction DB for historical perfdata 8026' 9-5/8" X 4-12" BKR S-3 PKR R� 4-1/9"HP.SX NP In=a R1a" 19-5/8" X 4-12" UNDUE OV ERSHOT 19-5/8" X 4-12' BKR S-3 PKR D = 3.875" I 4-12' TBG, 12.6#, 13CR-80, 0152 bpf, D = 3.958" 8226' 8224' 4-112' X 5-12' XO, ID = �� 5-1/2' TUBING STUB 8225' I 8233' 5-12" CUSTOM TBG 01 8269' —J 5-1/2" OTB X NP, D 8285' 5-12" OTB XN NP, D = 4.455' TOP OF 5' LNR 6302' WL13=4.892" 8305' "ane. c"n-,v eco TOP OF 7' LNR 8349' ' 9-518" CSG, 47#, L-80, D = 8.681" 8845- 15- WFT BIG BOYCBP (1229/19) 8875 PBTD — 9460' j li5"SrABLWIB#,Nf13CR-80,.OfBBbpf,D=4.276" 9542' 7' LNR, 26#, L-80-03 bpf, ID= 6.276' -F—w—Ar 8314!—[!= PERFORATION SUMMARY REF LOG: CBL ON 0827/81 ANGLE AT TOP PERF: 26'@ 8863' Note: Refer to Pmduction DB for historical perfdata SIZE SPF INTERVAL OPNISOZ I DATE SOZ 2-718" 6 8863-8894 0 12/30/19 0612990 3-3/8' 0.6 9012 -9050 C 07/03191 N4ES 2-718' 4 9048 -9086 S FR/PJC 06/18/91 3-3/8" 6 9065-9089 C 11109/12 01/0620 2-7/8" 4 9100-9157 S 06/18MI 2-718" 4 9166-9198 S 06/18/91 2-7/8" 4 9220-9250 S 06/18191 DATE REV BY COMMENTS DATE REV BY COMMENTS 8891 ORIGINAL COMPLETION 01/30/12 MSS/PJC GLV C10(01119/12) 06/30/91 N18ES RWO 11/13/12 JCM/JMD REPERF (11109/12 0612990 NSES RWO 02103/16 GRC/RH K VLV UPDATE PER STATE REG 1211396 N4ES RWO 1126119 MH/JMD PULLED K VALVE (11116/19) 04109107 FR/PJC DRLG DRAFT CORRECTIONS 0110620 NXVWJMD SET CBP IADPERFS 1220/10 MB/JMD ADDED SSSV SAFETY NOTE 01/0620 LLG/JMD SET XLOCKW/FLOWTHRU SUB 1I PRUDHOE BAY UNIT WELL: M-15 PERMITNo:9810850 API ND: 50-029-20612-00 BP Expklretion (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ryan Thompson Interventions Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU M-15 Permit to Drill Number: 181-085 Sundry Number: 319-015 Dear Mr. Thompson: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279-1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. wr[unissiuucr DATED thisZ 9 day of January, 2019. RBDMS�" � 1 *1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS ,?j jPa 25.280 1. Type of Request: Abandon ❑ Plug Perforations Stimulate ❑ Repair Well ❑ Operations shutdown ❑ f,(F�ra/q/t�►ure Suspend ❑ Perforate er Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other New K -Valve Design 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number 181-085 3, Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029.20612-00-00 99519-0612Stretigrephic ❑ Service ❑ 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU M-15 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028260 4 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(f) : Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 9657 9309 8460 9132 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" x 30" 28-108 28-108 Surface 2638 13-3/8" 27-2665 27-2665 4930 2570 Intermediate 8820 9-5/8" 25 - 8845 25 - 8577 5750 / 6870 3090 / 4760 Scab Liner 1240 5" 8302 - 8542 8095 - 9205 10140 10490 Liner 1306 7" 8349-9657 8136-9309 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MO (ft): 9012-9250 8728 - 8943 4-1l2" 12.6# x 5-1/2" 17# 13Cr80 23-8305 Packers and SSSV Type: 4-12' Baker S-3 Penn Packer Packers and SSSV MD (ft) and TVD (ft): 8034, 7860 4-12' Baker SABL-3 Packer 8172, 7981 &12" TIE HBBP Packer 8244, 8044 4-12" HES K -Valve 2126, 2126 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigrephic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: 2/11/2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is We and the procedure approved herein will not Contact Name: Thompson, Ryan be deviated from without prior written approval. Contact Email: RYARTHOMPSONAbp.com Authorized Name: Thompson, Ryan Contact Phone: +1 907 564 4535 Authorized Title: Interventions Engineer Authorized Signature: Date: ( 115'1 11 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /; l LJ I ( I Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑/ RBDMS%` s0 4 �8 Spacing Exception Required? Yes ❑ No IvSubsequent Form Required: IV+L10 4f &11 APPROVED BYTHE Approved by. 04W COMMISSIONER COMMISSION Date: / Z- �°` ORIGINAL MG (Ljj'_WIb Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. , Attachments in Duplicate W/ / 10-403 Sundry Application for Well PBU M-15 PTD# 181-085 Expected Start Date: February 11, 2019 Current condition of well: Gas Lift Producer Well, Operable, Offline: FTP Pressure: 204 psi Shut-in Wellhead Pressure: 120QOpsl Reservoir pressure: 13259 psi Well objective(s): Set a new K Valve in SSSV nipple per GL engineer design. Proposed program: 1. Pull K Valve from the SSSV nipple @ 2126'. 2. Drift to TD for 3.71" CIBP r n 3. Adperf — RAY Q`)'. 4. Set 3.71" WFD Big Boy CIBP plug @ 8980'. 5. Set Gauges (1 data point every minute) a. Have Well Integrity pop well under eval and flow for –7 days to collect pressure data at SSSV nipple. Discuss with ops flowing well at multiple choke settings per the GL engineer. 6. Pull pressure gauges from SSSV nipple and send data to GL engineer for K valve set up. 7. Set K Valve in SSSV nipple per GL engineer design. BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 TREE= 6'CNV WELLHEAD= MtEVOY ACRIATOR= BAKER Ke. EFEV = 51.76 EF. aEV I DEVI KOP= 5700' M9x Angle = 29' Q 8100' Datum MD = 9150' Datum TVD= 8800'SS 1 2665' 1 Minimum ID = 3.725" @ 8204' 4-112" XN NIPPLE M-1 's SAFETY NOTE: WELL REQUIRES A SSS V. "'4- 12" & 5-12" CHROME TBG & 5" CHROME LNR"• 2023' 9-518' HES ES CEMENTER 2126' 4-1/2" FES X NP, r = 3.813' 2126' 4-1/2-KVALVENSTALLED05MI15 GAS LFT MAN7FZEFS BW5' 142/2- HtS X NF', D = 3.813' 1 80 9-518' X 41/2' B1(R S3 PKFR, D = 3670" 8053• 4-112' HES X NP, D= 3 813' I, 12.6#, 13CR.80, VAMTOP 8116' ANGLE AT TOP PERF: 25' Q 9012' Note: Refer to Production DS for historical perf data ST I MD I TVD I DEVI TYPE I VLV I LATCH I PORT DAIS O 4 3 2 1 3654 5699 7071 7934 3654 5698 6985 0 10 20 28 AMG AMG AMG AMC' DOAE DOLE DOLE SO RK RK RK RC 16 16 16 24 01/19/12 01/19/12 01/19/12 01/19112 6 7773 BW5' 142/2- HtS X NF', D = 3.813' 1 80 9-518' X 41/2' B1(R S3 PKFR, D = 3670" 8053• 4-112' HES X NP, D= 3 813' I, 12.6#, 13CR.80, VAMTOP 8116' ANGLE AT TOP PERF: 25' Q 9012' Note: Refer to Production DS for historical perf data SIZE SPF NTERVAL OPWSOZ D = 3.958' SOZ 3-3/8' 0.6 9012-9050 O 8118' 9-5/8" X 4-1/2" UNIQUE FIOT 4-1/2'TUBNG STUB 1 8118' 9048-9086 S 06/18/91 338" 6 9065-9089 O 11/09/12 2-71W 8159' 4-12" HES X W. D = 3.613' S 06118/91 2-7/8' 4 $170' S 9-5/8" X 4-112' BKR S-3 PKR, D= 3.875- 06/18191 2-78' 4 9220-9250 S A9nA• 4-1 /2' XN Np in= 3 795• 14-1/2- TBG, 12.6#, 13CR-80, .0152 bpf, D = 3.958' 8226' 5-12' Tl18NG STUB 8225' ITOPOF5' LNR 8302• TBG, 17#, 13CR-80, 0232 bpf, ID=4.892" MARKER JONT I 9098' Pero 9460 18#, NT13CR-80, .0188 bpf, D= 4.276' 9542• 7- LW 26#, L-80, .0383 bpf, ID = 6.276' 9657' B2W 4-1/2" X 5-12" XO, ID = 3.958' 8233' 5-12' CUSTOM TBG OV ERSHOT 8244' 9-5/8' X 5-1/2' TW PKR 8269' Sit' OTIS X NP, D = 4.562' R9� 5-1/2" OTLB XN NP D = 4 455- 8314' —19-5/8' x 5' TIW HB -SP PKR w/ FIGR PERFORATION SUMMARY REF LOG_ CBL ON 08/27/81 ANGLE AT TOP PERF: 25' Q 9012' Note: Refer to Production DS for historical perf data SIZE SPF NTERVAL OPWSOZ DATE SOZ 3-3/8' 0.6 9012-9050 O 07/03/91 2-718' 4 9048-9086 S 06/18/91 338" 6 9065-9089 O 11/09/12 2-71W 4 9100-9157 S 06118/91 2-7/8' 4 9166-9198 S 06/18191 2-78' 4 9220-9250 S 06/18/91 P RUDHOE BAY LIr7T WEI-L: M.15 PERMIT Kb' 9810850 API No: W029-20612-00 SEF 22, TI to R14F� 606' WEF & 1716 SNL DATE REV BY COMMENTS DATE REV BY OOMMEITS 08181 ORIGINAL COMPLETION 01/30/12 MSS/ PJC GLV C/O (01/19/12) 06130/91 MMES RWO 11/13/12 JCANJMD RWERF(11/09/12) 0529/00 N9M RWO 02/03116 GR(%ILH K VLV UPDATE PER STATE REQS 12113106 WES RWO 04/09/07 FR/PJC DFILG DRAFT CORFU'-, 0NS BP Exploration (Alaska) 1220/10 M8/JMD ADD® SSSV SAFETY NOTE woPENDING PERFORATING PROCEDURE feet Log: EfHCI I Wall:M-15 -- ------ ---- ---------- -- Ml #: 50-029-20612-00 Data Dide: 111012019 Pond Engr Ryan Thompson off—Ph. (90])564-4535 Company: ... LI IIS _- H."m Ph .-8800'.WDss.M0 is Depth* lfrom4gl C011pa'., 9h?) 301.120 CC or ME: APBNRWOS Zen. PERF TYPE 8,863'_. 894' ----- - -- --------- - PeaPeclure See pmomimy H2S L-1 102 "." References LogT" In Lee Add 3 feet Log: EfHCI I to the tie -In to Mon Data Preleased Amount of DmendoertSug,Wman to Achieve Drawdown depth with In. off ... Put I.e. -------- ------ -- --- --- Company: ... LI IIS _- Last DML 9 388. It MD on 514/2015, Est Res. Pres. @ .-8800'.WDss.M0 is Depth* lfrom4gl Oepme(firce.4.) F.W SPF oneem. Phasing Zen. PERF TYPE 8,863'_. 894' ----- - -- --------- - 8,860'... 891 ------------ - ---- ---------- Random 60 . ... ....... SAG ADD PERF Rn,u..Wd Gap Sam; 2 875'.. Charge: Maxime Min Wellipurs, ID: 3725 M. Swell in Liquid: 3,05" Mae Stung In G.; MR le Drawdown Wcaaaaaryllfinassulfil ....... a, items, Ptshmmurt, Preleased Amount of DmendoertSug,Wman to Achieve Drawdown ------------ -------- ------ -- --- --- Last DML 9 388. It MD on 514/2015, Est Res. Pres. @ .-8800'.WDss.M0 is _3259 psi Perforation Summary Well. M 15 Chan. "10: Nod En,,: General Comments:Pi Death. Balance R.f.mm,.ul to BHCS G. one. eased. SPF Phasing Zen. 01131U Claw 01BILI WIN 01BILI Claw 01BW OIBIU o/Blu PPPcJ Em" Ad,dlR.,d TRff = 6" Cfdd N�H..LF1gAD= %VOY ACRIATOR= BAKER KB. ELLV = 51.76' BF. ELEV = 26.46' KOP = 5700' Mb Angle = 29- @ 8100' Wtum W 9150' Datum TVD= 88W SS 9-5/8- CSG. 40#, L-80, TG& 6=-8 —8357 2036' 13-318' CSG, 72#, L-80, D = 12.347" 1 2665' 1Minimum–ID--= 3--.7-25--"@- 8204' 4-112" XN NIPPLE 4-1/2' TBG, 12.6#, 13CR-8Q VAMTOP .0152 bof. D = 3.958' 12.6#, 13CR-80, .0152 bpf, D = 3.958" 8225' ITOPOF 5 -LW I 8302' TBG, 17# _13CR-88, _0232 bpl, D = 4.89T 8305• LSk`j r � � =NOTIE,:REQUIRES A SSSV. •'"4- E TBG & 5" CHROME LNR""• 2023' 9-518• HES Es 2128'-�4-12'tieSXNF', D=3.813'1 2126' 4-12'KVALVE NSTALL®05/05/15 GAS LIFT AMNri'94 S ':Ifs'➢ 1 8118' 1 8204' 8224' 8233' 8244' y4-W-F[JR NP, D=3.813' 1 BKR S3 PKJ;, 4-1/2' FES 9-5/8- X 4-1/2' L MOLE OVBZSHOT 4-12-KSX NP, D=3.813'1 9-5/8' X 4-12- BKR S-3 PKR D = 3.875- 4-12- XN NP, D = 3.725- x = 4.552- :)=4-455" x )=4.455 - ST 4 M) TVD DEN TYPE VLY LATCH POW DATE 3654 3654 0 MW DOA,£ R( 16 01/19/12 3 5699 5698 10 AMG DOA,£ RK 16 01/19/12 2 7071 6985 20 MA; DOME R( 16 01/19/12 1 7934 7773 28 M.IG SO RK 24 01/19/12 ':Ifs'➢ 1 8118' 1 8204' 8224' 8233' 8244' y4-W-F[JR NP, D=3.813' 1 BKR S3 PKJ;, 4-1/2' FES 9-5/8- X 4-1/2' L MOLE OVBZSHOT 4-12-KSX NP, D=3.813'1 9-5/8' X 4-12- BKR S-3 PKR D = 3.875- 4-12- XN NP, D = 3.725- x = 4.552- :)=4-455" x )=4.455 - STATE OF ALASKA OLASKA OIL AND GAS CONSERVATION COMMIADN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing El Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well Re-enter Susp Well ❑ Other:K-Valve IZI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 181-085 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-20612-00-00 7. Property Designation(Lease Number): ADL 0028260 8. Well Name and Number: PBU M-15 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: RECEIVED 9639 Total Depth: measured feet Plugs measured feet true vertical 9293 feet Junk measured feet FEB 2 6 2016 Effective Depth: measured 9460 feet Packer measured See Attachment feet true vertical 9132 feet Packer true vertical See Attachment feet Aj("""► Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 27-107 27-107 Surface 2637 13-3/8"72#L-80 26-2664 26-2664 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9012-9032 feet feet 9032-9048 feet 9048-9050 feet 9050-9065 feet 9065-9069 feet 9069-9086 feet 9086-9089 feet 9100-9151 feet 9166-9198 feet 9220-9250 feet True vertical depth: 8728-8746 feet feet 8746-8760 feet 8760-8762 feet 8762-8775 feet 8775-8779 feet 8779-8794 feet 8794-8797 feet 8807-8853 feet 8867-8896 feet 8915-8943 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 4-1/2"K Valve 2126 2126 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: ANO i 1 r ,'.,,,i I-' 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 46 455 2352 1783 368 Subsequent to operation: 46 0 1566 1756 185 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development m Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil IZI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ 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: 316-091 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer tn�(f,(', Signature ,Pct_4_l C,,7'c- Phone +1 907 564 4424 Date 2/25/16 Form 10-404 Revised 5/2015 1/71.-- �f�y//6 RBDMS LL/ FEB 2 g LU 16 Submit Original Only 31 RP • • Packers and SSV's Attachment PBU M-15 SW Name Type MD TVD Depscription M-15 SSSV 2126 2125.96 4-1/2" K Valve M-15 TBG PACKER 8035.25 7861.58 4-1/2" Baker S-3 Perm Packer M-15 TBG PACKER 8167.46 _ 7976.93 4-1/2" Baker SABL-3 Packer M-15 TBG PACKER 8243.95 8043.82 7" TIW HBBP Packer • • a) o 0 0 0 0 0 0 ca � coC) cO — Cfl rnO ti OLO OLO p N M LO t� i,- CO U y 0 0 0 0 0 0 0 0 7 O 1*-- CO N Nr m VLO (O I- co co N- r, -r O O LC) C) O N CO co CO �Y O O O V CO O) CO O CO N CO CA 0 0 N N CO C)) O) N- CO CO H LO CO CO CO CA CO Cr) CO N N N N O O N C3) O N CO CO r cc a) O N O LC) O (fl V LO N M O CO O CO LO O N CO N N CO 0) 0) CO CO CO C.) p i i i i i Q CNI CO I� CO CO CO O M N N cnC CV N CV O M CO N — N = C N CO 00 Cb CO CO a O co co O L L a) O co i °OOpUocUMU O J J co co M = of CO N J F— a; O Zo _ _ Z N N N U \ cow _ � M L? `_ N N LO ' 'CI- =t CO CO O CO CO O CO N— CO cr CD 0 CO E CO CO O CO N CO CO N N N CO CO J W W — — • I— W0 Wen U U W W U o c c[ Z_ Z_ Z Z WUJUJW U cn Z ? 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ANGLE AT TOP PERF:25'@ 9017 [ Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL OFTWSQZ DATE SQZ 3-38" 0.6 9012-9050 0 07/03/91 MARKER JOINT H 9098' • 2-7/8' 4 9048-9086 S 06/18/91 3-3/8' 8 9065-9089 0 11/09/12 pgTD — 9460' 2-7/8' 4 9100-9157 S 06/18/91 /,4•••1•4/ 2-7/8" 4 9166-9198 S 06/18/91 15"SCAB LNT2, 184,NT13CR-80,.0188 bpi,D=4.276" J-- 8642' l iff.'����-f • '4...4.....0 2-7/8' 4 9220-9250 S 06/18/91 T LW,26#,L-80,.0383 bpf,ID=6.276' 965T .1..././.4 f f f f f f f ,SS 4 4 441144i DATE REV BY CORN&6YTS DATE REV BY C)P.4UfTS FRIAFDEBAY LJKT r 08181 ORIGINAL COMPLETION 01/30/12 MSS/PJC GLV C/O(01/19/12) MIL: M-15 06/30/91 N18P.5 RINO 11/13/12 JCMJMD RETERF(11/09/12) PERMIT ND:'1810850 05/29/00 N9EI3 RINO 02/03/16 GRaTLH K VLV LFDATE Pat STATE REGS API Pb: 50-029-20612-00 12/13/06 N4E-S RANO SEC 22,T11N,R14E 606'VEL&1716'SPL 04/09/07 FR/PJC 'DRRLG DRAFT CORRECTIONS 12/20/10 r ROM) ADDED SSSV SAFETY NOTE BP Exploration(Alaska) y of Ty • \ i//77,, THE STATE Alaska Oil and Gas of LASI�:A Conservation Commission A ' ist = 333 West Seventh Avenue � '— I. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ".° Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Ryan Daniel Alaska Wells Integrity and Compliance Team Leader BP Exploration(Alaska), Inc. %AWED MAR 0 3 2016 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU M-15 Permit to Drill Number: 181-085 Sundry Number: 316-091 Dear Mr. Daniel: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a/4 Cathy . Foerster Chair DATED this 23 day of February, 2016. RBDMS FEB 2 5 2016 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COM ION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 I1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tabing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other K-Valve Design E ' 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 181-085 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development E. 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-20612-00-00 - 7, If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes 0 No E PBU M-15 9. Property Designation(Lease Number): 10. Field/Pools: (/''t-'•> { •3 i ADL 0028260 PRUDHOE BAY,PRUDHOE OIL k 11 PRESENT WELL CONDITION SUMMARY TotalDepthMD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): k7-� a6 1-0,.9295-- 9460 9132 Casing %rP Length Size MD TVD .4), tom. l .52 Burst Collapse Structural 7'''&' Conductor 80 20"x 30" 27-107 27-107 Surface 2637 13-3/8"72#L-80 26-2664 26-2664 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment 4-1/2"K Valve 2126, 2125.76 12.Attachments: Proposal Summary H Wellbore Schematic E 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development E• Service ❑ 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil E " WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17.I hereby certify that the foregoing is tru and the procedure approved herein will not Contact Daniel,Ryan be deviated from without prior written app//v.. Email Ryan.Daniel@bp.com Printed Name Daniel,Ryan Title Alaska Wells Integrity&Compliance Team Leader �y Signature tit/ [, Phone +1 907 564 5430 Date /< fog COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 3 \LQ — O 9 l Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other. Post Initial Injection MIT Req'd? Yes 0 No 0 Spacing Exception Required? Yes 0 No Q Subsequent Form Required: `()-4-V 4 aVe /,• Approved by: 1 APPROVED BYTHE COMMISSIONER COMMISSION Date: 2 . ,l/ ORIGINAL RBDMS IA/ FEB 252016 , m Z i tq I I Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ,4 M'/( ,,,,,,5?) _z E, 4.- • • m cy CD• C ) � m000CD p N M ch u) ti r- 0 U NO o 0 CD 0 0 0 0 O N- c M M N- N- 03 d 0 CD CO N. 000 000 ti • C▪ SD tt 0 0 0 V- 007 C D 7- CO O 0 N M O) O O N N 00 O7 CD r- 00 OD 0 1 I 1 1 1 1 1 1 1 H OD U1 CO Ln M O) 007 M M N N N N O O r- N O) O N OD 00 N- 00 4.0 ttO O N N. 0 Cn O 0 r- ,Y 0 N MCD c- 0 O 00 (n 0 �- N N N 00 O) O) 00 00 00 V C 03 2 1 I I I � 10 Q CD CD CV 01 0 M 0 V'M N N o) N N N O M M N N C N CO 00 00 CO CL OO CD 00 00 C3 OO O 00 00 O� OD � UoUUU J J M 0 M M .N N x N- 0H # C aD 4 0 _ _O CO Z CAD NM ODD © 4t _ (h cf) ti N N O O c\- 7 0 V C 0 .c *a 0 0 O OD M 0O CO .- M 0 0 0 01 = O CD O 00 N M r- O OO J N N 0 .- 0 W W c)O — — NH U W 0 U UJ ()Ou_ X � ccZZZ Z a W W W W m m m O D H H Z Z D D 0 Z z H • ! 07 07 0 0 CO M d' c- N M OD V" O CO cr O 'ct T- CC) In G. O 6 4 M Cn 0 r CO CC) N- CD O CD O) 4 p CO t` 0 I"- N- 0 CO OD O) CO O OD OD CO O CO CD CO 0 I-" NCO ti M ' CC) OD MD « MD CO O 00 V CD tt CD CCS d I� Oa N- N- C` N- I` 00 CCD CD OO CA p CO O CO CO CD CD CO CO CO OD 0 W o 0 0 co w W W 0 a p5 Q v 0 O 0 0 Y Y N 00 CD MD C D CCS CA c- CO CD J W Q Q W W W .�.r Q to CO O CO CO t() O O Q Q Q W a a Z_ = 0) 0 CD CD 0 CD 0 CD c- T- N 0 0 0 J W W 0 --I 0 CA Cr) (A CA O CA (fl (A CAW Q Q Q 0 J _, D00 L 2 0 0 0 w l2 W Z o Z W W W (L I- ♦- Q J Q i 2 O co cn co co co 4.3 T7 CI a Q C 12 C N N CO CD 10 O) CO O co CD O CO a- M moi' MD CO CO CO CD CO N il 0 0 0 0 0 0 0 .- — N {d a O) C CA D C)) CD CD 6) CD C)) O) N 00 d �_ C/) Y 0 O 0) a 2 2 2 0 co co can cp can w a a, O U C 2 LL LL LL N LL LL LL N N N .m CL CL CL CYQaa000 (3 a0CCCEtOD <C (I) Cl) C)) 0 C, d a V I- CD (D (D l_ C' N CD C' C0 C CD CD CD C3 CD C3 CD O N N N CVT T- Z tL Q W i0 M M M CD CD 00 C0 MD MD MD Z O W p LU N LL W N N N a U W tL W 0 CO CO CO Q 0 J {- J J J 0 Cr a m O D W J J QC'J W < < a. co LL LL U co a.. 0) E 07 Z MD MD CC) CD MD MD CD CC) MD In W 1 1 1 1 i i 1 1 1 1 LL a. C/30 lL N LL CO CI- Cla- 0 -100W . • i Packers and SSV's Attachment ' PBU M-15 SW Name Type MD TVD Depscription M-15 SSSV 2126 2125.96 4-1/2" K Valve M-15 TBG PACKER 8035.25 7861.58 4-1/2" Baker S-3 Perm Packer M-15 TBG PACKER 8167.46 7976.93 4-1/2" Baker SABL-3 Packer M-15 TBG PACKER 8243.95 8043.82 7"TIW HBBP Packer • • 06/6/01 • WO Wireline Work Request M-1 5 global wells organization Distribution Wireline(4) Well: M-15 AFE: APBWELIRSL Reading File Date: 4/29/2015 Engineer: John Paul Kenda IOR: 25 FTS: NO AWGRS Job Scope: H2S Level: Problem Description Well passed a NFT in August of 2014. Since then, neighboring injector well R-11A has come online. This is expected to increase the formation gas rate of M-15 causing the need for a SSSV. • Initial Problem Review This design is based upon the test from 2/17/13 when the well last saw an MI buzz. Remedial Plan -WIRELINE ACTION Install K Valve. DSO: Flow well at WHP greater than 450 psi.Valve set to close when flowing wellhead pressure drops below 450 psi. HES Test rack set pressure to be 517 psi at 60 degrees F. Date Work Completed Well Status/Results Date by Problem Resolved ? Y N : Well Review(Post GLV or Choke Installation) Pre Installation Post Installation Liquid Rate (STBL/D) Expected NOB: Avg. WC (%) Actual NOB: Lift Gas (MMSCF/D) MGOR used for NOB: TGLR (SCF/STBL/D) FTP (psi)/Steady? MAINTENANCE ONLY CLP (psi)/Steady? (e.g. Fix AC,Shallower for Slugging) Casing Press. (psi)/Steady? RATE (Non-Post-WW) Orifice Depth:_ (e.g.deepen, optimize orifice) IA Fluid Level: Post-Wellwork Date of FL Survey:_ / / Follow-up Recommendations: • • "K"Valve Calculation Sheet M-15 Date: 04/08/15 SNAP: M-15 2015-04-08 K-Valve DESIGN Test Date 02/17/13 Gross Fluid Rate 4440 BLPD Flowing Well Head Pressure 455 psi Flowing Well Head Temperature 158 deg F GOR 5199 scf/bbl TGLR 1134 scf/bbl Flowing Pressure Calculations Based on Hagedorn-Brown Multiphase Flow Correlation "K"Valve Setting Depth TVD 2126 ft Flowing Tubing Pressure With Gas Lift 204 psi Flowing Tubing Pressure Without Gas Lift 0 psi Valve set to close at 450 psi Pwh Flowing Tubing Pressure @455 psi Pwh 824 psi "K"Valve Test Rack Set Pressure at 60 deg F I 517 ,psi Valve Size &Volume Ratio 4.5" 1.314 NOTE: Well needs to flow at>450 psi Pwh Valve set to close at 450 psi Pwh • • Tubing Pressure at Valve 824 BPT(psia) 838 >1238 <1238 Temperature (deg F)at Valved 159 a 1.822E-05 3.02346E-05 b 1.227502 1.191466 Base Pressure 704.310178 c -864.833 -838.62374 Base Temp (TV-60) 99 697.33092 691.7170251 Corrected Pressure 691.717025 psia TCF 0.82504416 /olume Ratio for Valve Size = 1.314 Pb @ 60 = 679.836389 Test Rack Pressure = 517 I Volume Ratios 4 1/2" & 5 1/2" 1.314 3 1/2" 1.257 2 7/8" 1.211 2 3/8" 1.204 TREE= 6"0W WELLFE4D s — EVOY M-15 SAFETY NOTE:WELL REQUIRES A SSSV. "4- ACfUTO AR= BAKH2 1/2"&5-1/2"CHROME TBG&5"CHROME LNR"'" KB.ELEV= 51.76' BF.ELEV= 26.46 •• '• • IT(0-0= 5700' •• .. Mix Angle= 29" 8100' .... �- 2023' 9-5/8"HES ES C EVE TER Datum MD= 9150' Datum ND= 8800 SS 11-0-.11___________I 2126' J—4-12'HES X NP,D=3.813" 9-5/8'CSG,,40#,L-80,TC-I,D=8.835' I— 2036' 2126' —I4-1/2'K VALVE NSTALLED05/05/15 13-3/6'CSG,72#,L-80,D= 12.347' 2865' ' GAS LFT MANDRELS ST ryp ND DEV TY FE VLV LATCH FORT DATE 4 3654 3654 0 MG DONE RK 16 01/19/12 3 5699 5698 10 MD DONE RK 16 01/19/12 Minimum ID = 3.725" 8204' 2 7071 6985 20 WAG DOME RK 16 01/19/12 4-1/2" XN NIPPLE 1 7934 /113 28 MUG_ SO RK 24 01/19/12 I I 8005' H4-1/2"HES X NP,D=3.813" Z X L 8029' —19-5/8'X 4-12'BKR S-3 PKR.D=3.870" I I { 8053' —4-1/2'HES X NP,D=3.813' 14-1/2"TBG,12.6#,13CR-80,VAM TOP H 8116' .0152 bpf,D=3.958' 8118' 9-5/8'X 4-1/7'UNIQUE OVERSHOT 4-12'TIBNG STUB -I 8118' —. , , 8159' J—4-12'HES X NP,0=3.813' Z. 8170' —9-518'X 4-1/2'BKR S-3 PKR,D=3.875" 1 1 B204' H4-12'XN NP,D=3.725" [4-1/2"TBG,12.6#,13CR-80,.0152 bpf,D=3.958" H 8226' -- \ 8224' H4-12"X 5-12"XO,D=3.958' 5-1/2'T1ENG STUB — 8225' ' I 8233' --{5-12'CUSTOM TBG OVERSHOT z 8244' F--9-5/8'X 5-12'T1W PICK 1 1 8269' .H5-1/2'o-ns X NP,D=4.562' J 1 1 8285' H5-1/7'OTIS XN NP,D=4.455' TOP OF 5"LNR — 8302' 5-12'TBG,17#,13CR-80,.0232 bpf,D=4.892' - 8305' \ 8305' —5-12'DUMMY SEAL 8314' H9-5/8"x 5'TPN HB-BP PKR w/HGR TOP OF 7'LNR 1-- 8349' H PERFORATION SUNAARY 9-5/8"CSG,47#,L-80,D=8.681' — 8845' 1 I\ REF LOG:C33L ON 08/27/81 . ANGLE AT TOP PERF:25°@ 9017 [ Note:Refer to Roduction De for Iistorical perf data SIZE SPF INTERVAL OPWSQZ DATE SQZ 3-3/8' 0.6 9012-9050 0 07/03/91 MARKER JOINT H9098' • 2-7/8' 4 9048-9086 S 06/18/91 3-3/8' 6 9065-9089 0 11/09/12 PBS J 9460' 2-7/8" 4 9100-9157 S 06/18/91 ,•••••••/••••I l 2-7/8' 4 9166-9198 S 06/18/91 5'SCAB LW,18#,NT13CR-80..0188 bpf,0=4.276" — 9542' ,;..............A 2-78" 4 9220-9250 S 06/18/91 1.,.,.,.1.1.A.A.., 7'LM.26#,L-80,.0383 bpf,D=6.276' 965T ' 1�1�����1���I���#i DATE REV BY CX)A ffS DATE FEV BY C OMENTS PRUDHOE BAY UNIT 08/81 ORIGINAL COMPLETION 01/30/12 PASS/PJC GLV C/O(01/19/12) WIFlL: M-15 06/30191 N18F3S RWO11/13/12 JC3WJMD F21 (11/09/12) PERMIT Pb:'1810850 _ 05129100 NBBS RWO 02/03/16 GRCITLH K VLV U'LMDATE PER STATE RE-GS API No: 50-029-20612-00 12/13/06 N4ES RMYO SEC 22,T11 N,R14E,606'W EL&1716'SNL 04/09/07 FR/PJC DRLG DRAFTCORRECTIONS + . C 12/20/10 MB/JMD ADDED SSSV SAFETY NOTE BP Exploration(Alaska) Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Wednesday, May 06, 2015 2:59 PM To: AK, OPS GC2 OSM;AK, OPS GC2 Field O&M IL;AK, OPS GC2 Wellpad Lead;AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan;AK, D&C Wireline Operations Team Lead;AK, D&C Well Services Operations Team Lead;AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale;AK, OPS Well Pad MN;AK, OPS GC2 Ops Lead;Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer;AK, D&C Well Integrity Coordinator;AK, OPS FF Well Ops Comp Rep; Sternicki, Oliver R;AK, D&C WL Completions Superintendent; Regg,James B (DOA) Subject: OPERABLE: Producer M-15 (PTD# 1810850) Production characteristics changed SSSV needed Attachments: image001.png All, Producer M-15 (PTD#1810850) has previously operated without a sub-suface safety valve(SSSV)due to a passing No Flow Test(NFT)on 06/22/14 as per 20 AAC 25.265(I)(1)(B). Production characteristics have changed,causing the previous test to be no longer valid. The well will require a SSSV when online as per 20 AAC 25.265(d)to prevent the possibility of unassisted flow of hydrocarbons to surface. Please call with any questions. Thank you, Kevin Parks (AIN,'nate F<ttos) SCAMMEDMAI/ . 12015 BP Alaska-Well Integrity Coordinator 1% Global Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegritvCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Friday, August 01, 2014 3:32 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Peru, Cale; AK, OPS Well Pad MN; 'chris.wallace@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; AK, D&C Projects Well Integrity Engineer; AK, OPS FF Well Ops Comp Rep; 'Regg, James B (DOA) (jim.re•g@alaska.gov)' Subject: OPERABLE:Producer M-15 (PTD # 1810850) Passing No Flow Test- Permission to Flow Well Without Sub Surface Safety Valve All, 1 Producer M-15 (PTD#1810850) passed an AOGCC witnessed no flow test(NFT)on.. 22,2014. The no flow test confirms that the well is not capable of unassisted flow of hydrocarbons to surface. The AOGCC has approved BP to produce the well without a sub-surface safety valve(SSSV). The well has been reclassified as Operable and may be placed on production without a SSSV. A NFT must be performed again if the well is perforated,cleaned out,stimulated in any way,or shows any sign of being capable of flowing hydrocarbons to surface unassisted. BP Base Management shall monitor for changes in flow characteristics to ensure the well remains incapable of flowing hydrocarbons to surface. The approval letter from the AOGCC is attached. Please call with any questions. Thank you, Jack Disbrow (alio rate I aot is nonce BP Alaska-Well Integrity Coordinator GVVGlobal Wells Organization Office: 907.659.5102 WIC Email:AKDCWellIntegrityCoordinator@bp.com 2 v` v,3'5 D La co v N n oln z m n x o oo K z - „a-, eh g , * Cn a O O� a- N N N Ol F —' im n N A , CD ^ �L.� O 0 N Ow N CO 01 �I O O CJ. 7,,,C� O O O r- K S �j!/ o o y D D z q a, a, C o4 Z n, � v CO n D a''` fD r (�D �'df N N �. m fD CZ' oa m vim, N C m t, D m CD. '9 D o O . t"D 01 N D vco t • n v073 <Lo co Lr/ 1.77 v,. CD Vco o alia n n ,07 W0 n m w n co n w n n n 0 c;' ow . CD a0 (D N . 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I ca G) N 70 A` m 0) n ed LL„ = 04 S U�ua 0 l^ * fp * O 0 K C ,t * .-r 0V ' * O tir '1) - 0 :z-' Q ca I - n O �v n r n r4 0000000 0000 0 0 t 0 0 0 0 DDD 0 0 0 0 D D D 0 D cJ 0 0 I I I RECEIVED ' STATE OF ALASKA ALA. OIL AND GAS CONSERVATION COM ION DEC 13 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon [J Repair Well [J Plug Perforations [J Perforate [J Other [J Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re -enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development 0 Exploratory ❑ 181 -085 -0 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: ,, Anchorage, AK 99519 -6612 50- 029 - 20612 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028260 PBU M -15 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 9639 feet Plugs measured None feet true vertical 9293.19 feet Junk measured None feet Effective Depth measured 9460 feet Packer measured See Attachment feet true vertical 9131.91 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 84 20" x 30" 26 - 110 26 - 110 0 0 Surface 2640 13 -3/8" 72# L -80 25 - 2665 25 - 2664.94 4930 2670 Intermediate None None None None None None Production 8818 9 -5/8" 47# L -80 27 - 8845 27 - 8577.1 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet True Vertical depth See Attachment feet SCANNED FEB 2 8 2013 Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 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: 148 266 3283 578 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development 0 n Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 0 Gas ❑ WDSPL U GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Nita Summerhays Prepared by Nita Summerhays 564 -4035 Printed Name Nita Summerhays Title Petrotechnical Data Technician . , Signatur ' ,, —,------ _ , Phone 564 -4035 Date 12/11/2012 r '/ �7 _ Form 10-404 Revised 11/201 .;Me DEC 14 ' _ i ,2L. / 2--- !e... Submit Original Only t 7(t4 • • Daily Report of Well Operations ADL0028260 SVMMA'Y ** *WELL FLOWING ON A-ZRIO xl. EL A ER ) INTITAL FTP/ I/O = 200/1700/200 SIP T /I /O = 1300/1500/0 PERF GUN #1 - PERFORATED INTERVAL @ 9069' - 9089' W/ 20' x 3 -3/8" POWERJET HMX GUN LAID DOWN EQUIPMENT FOR THE NIGHT AND WILL RETURN IN AM TO RUN 2ND AND FINAL GUN WELL LEFT SHUT IN - NOTIFIED PAD OP OF WELL STATUS (FREEZE PROTECT ORDERED) 11/8/2012 * ** JOB CONTINUED ON 9- NOV- 2012* ** * **JOB CONTINUED FROM 09- NOVEMBER -2012. WELL SHUT IN ON ARRIVAL * ** (ELINE ADPERF) PERF GUN #2 - PERFORATED INTERVAL @ 9065' - 9069' W/ 5' x 3 -3/8" POWERJET HMX GUN (LOADED W/ 4' OF SHOTS) TIED PERFORATIONS INTO SWS CBL DATED 08/27/1981 FINAL T /I /O = 1220/1400/0 PSI ** *JOB COMPLETED. WELL SHUT IN ON DEPARTURE - NOTIFIED PAD OP OF WELL 11/9/2012 STATUS * ** ** *WELL S/I ON ARRIVAL ** *(perforating) DRIFT W/ 3.805" G. RING & 4 -1/2" BLB TO X -NIP @ 2113' SLM/ 2126' MD. SET 4 -1/2" X -LOCK (w/ sec. lockdown), FLOW THROUGH SUB & SLB SBHPS GAUGES IN X- NIP © 2113' SLM/ 2126' MD. 11/12/2012 ** *WELL S/I ON DEPARTURE, PAD OP NOTIFIED * ** ** *WELL FLOWING ON ARRIVAL * ** (perforating) PULLED 4 -1/2" X -LOCK W/ SLB MEMORY GAUGES @ 2108' SLM / 2126' MD 11/19/2012 ** *WELL S/I ON DEPARTURE * ** FLUIDS PUMPED BBLS 5 DIESEL 5 TOTAL • • Perforation Attachment ADL0028260 Perf Opera Meas Meas SW Operation tion Depth Depth TVD Depth TVD Depth Name Date Code Top Base Top Base M -15 5/20/00 BPS 8412 8424 8191.56 8202.16 M -15 6/16/00 BPP 8412 8424 8139.76 8150.36 M -15 2/9/85 APF 9012 9032 8675.72 8693.8 M -15 6/8/91 SQZ 9012 9032 8675.72 8693.8 M -15 7/3/91 RPF 9012 9050 8675.72 8710.07 M -15 2/9/85 APF 9048 9086 8708.26 8742.61 M -15 6/8/91 SQZ 9048 9086 8708.26 8742.61 M -15 11/9/12 APF 9065 9069 8723.63 8727.24 M -15 11/8/12 APF 9069 9089 8727.24 8745.32 M -15 2/9/85 APF 9100 9151 8755.26 8801.33 M -15 6/8/91 SQZ 9100 9151 8755.26 8801.33 M -15 8/1/82 PER 9166 9198 8814.88 8843.78 M -15 6/8/91 SQZ 9166 9198 8814.88 8843.78 M -15 8/1/82 PER 9220 9250 8863.65 8890.74 M -15 6/8/91 SQZ 9220 9250 8863.65 8890.74 AB ABANDONED MIR REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP PULLED MLK MECHANICAL LEAK BRIDGE OPEN BPS PLUG SET 01-I HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF . • • Packers and SSV's Attachment ADL0028260 SW Name Type MD TVD Depscription M -15 PACKER 8029 7804.32 4 -1/2" Baker S -3 Perm Packer M -15 PACKER 8170 7927.35 4 -1/2" Baker S -3 Perm Packer M -15 PACKER 8244 7992.06 5 -1/2" TIW Packer Casing / Tubing Attachment ADL0028260 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84 20" x 30" 26 - 110 26 - 110 LINER 1238 5" 18# NT- 13Cr80 8302 - 9540 8094.7 - 9204 10140 10490 LINER 1308 7" 26# L -80 8349 - 9657 8136 - 9309.4 7240 5410 PRODUCTION 8818 9 -5/8" 47# L -80 27 - 8845 27 - 8577.1 6870 4760 SURFACE 2640 13 -3/8" 72# L -80 25 - 2665 25 - 2664.94 4930 2670 TUBING 8198 4 -1/2" 12.6# 13Cr80 26 - 8224 26 - 8026.36 8430 7500 TUBING 81 5 -1/2" 17# 13Cr80 8224 - 8305 8026.36 - 8097.33 7740 6280 • • CM/ • " 'D pt � M-15 SA NOTE: WELL REQUIRES A SSSV. ***4- ACTUATOR & 5 -1/2" CHROME TBG & 5" CHROME LNR*** KB. EL.EV = ____ 51.76' BF. ELEV = 26.46' i i� KOP = 5700' • • PMx Angle = 29 r, • 8100' = 2023' H9 -5/8" HES ES C8VE ITER Datum %O = 9150' Datum TVD = W 8800 S S I 2126' 4-1/2" HES X NP, ID= 3.813" I9 -5/8' CSG, 40#, L-80, TGI, D = 8.835" H 2030' GAS LIFT MAPDRELS ' ST M) TVD DEV TYPE VLV LATCH PORT DATE " 13 -3/8 CSG, 72#, L-80, D = 12.347° 0 I H 2666• } 4 3654 MG DONE AK 16 01/19/12 3 5699 5698 10 MA) DONE RK 16 01/19/12 ij 2 7071 6985 20 MM DONE RK 16 01/19/12 Minimum ID = 3.725" @ 8204' 1 7934 7773 28 MVO SO RI( 24 01/19/12 4 -1/2" XN NIPPLE I I I 8005' H4- 1/2 "I-E'SX1•IP D =3.813" I Z 8029' 1_19-5/8' X 4-1/2" BKR S-3 PKR, D = 3.870" I I I 1 8053' H4 -1/2" HES X NP, D= 3.813" I 4-1/2" TBG, 12.6#,13CRr80, VAM TOP H 8116' I .0152 bpf, 0 = 1958' I 8118' j58" X 4-1/2" UNIQUE OVERSHOT I 14-1/2" TUBING STUB H 8118' ' , 8159' H4 -1/2" HES X NP, 0 =3.813" I Z I 8170' 1_1 9-5/8" X 4-1/2" BKR S-3 PKR, D = 3.875" I ( 8204' H4 -112" XN NP, D = 3.725" I ' ' I4 -112" TBG, 12.6#, 13CR-80, ' 15-1/7' TUBNG 3.958* TUB H 82 6 I- ----- 1 1 I $Z 5-1/2" CUSTOMM TBG OVERSHOT Z 8244'1-19-5/8" X 5-1/2' TIW PKR I 8268' H5-1/2" OTIS X NP, D = 4.567' I I 8285' H5-1/2" O T I S XN N P , D = 4.455" I ITOPOF5' L•j—L 8302' 1— (5-1/2' TBG, 17 #, 13CR -80, .0232 bpf, 0 =4.892" H 8306' 8305' H5 -112" UMW SEAL I 8314' H9-5/8" x 5° TW/ HB-BP PKR w / HGR I ITOPOF7" LNR H 8349' I—I PERFORATION SUMMARY 1 9-5/8" CSG, 47 #, L-80, D = 8.681" H 8845' I--A REF LOG CBL ON 08/27/81 • ANGLE AT TOP PERF: 25° @ 9012' I Note: Refer to Production DB for historical pert data SIZE SPF NTERVAL OPNISOZ DATE SOZ 3-3/8" 0.6 9012 - 9050 0 07/03/91 !MARKER Jaw 9098' • 2 -7/8" 4 9048 - 9086 S 06/18!91 3-3/8" 6 9065 - 9089 0 11/09/12 �� 9460' � 2 -78" 4 9100 - 9157 S 06/18/91 � $ 2 -78' 4 9166 - 9198 S 06/18/91 15" SCAB LNR, 158, PTTI3CR -80, .0188 bpf, D = 4.276' H 9542' .4444444441444141 2 -78• 4 9220 -9250 S 06/18191 17" L NR, 26#, L-80, -0383 bpf, D = 6276' H 9657' •�4�4y�4yyy�4� DATE REV BY CONSENTS DATE REV BY COM ENTS PRLDHOE BAY UNIT P 08181 ORIGINAL COMPLET CW 12/20/10 NB/JM3 ACOED SSSV SAFETY NOTE WELL: M•15 06/30/91 N18ES MO 01/30/12 MSS/ PJC GLV CIO (01/19/12) PERMT No: '1810850 05/29/00 N9ES RWO 11/13/12 .ICM.SD Rff13F (11/09/12) AR Pro: 50 -029- 20612 -00 12/13106 P44ES IMO SEC 22, T11N, R14E, 606' WEi_ & 1716' SPL 01/12/07 TBJR G GLV C/O 04/09/07 FRYPJC DRLG DRAFT CORRIKTIONS BP Exploration (Alaska) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission s ) 7th g •• 2 L 333 West 7 Avenue ,��.�� AUG AI� Anchorage, Alaska 99501 ' 1,.S Subject: Corrosion Inhibitor Treatments of GPB M -Pad r 1 try Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad M 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) M -pad Date: 04/14/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal M -01 1690780 50029200420000 Sealed NA NA NA NA NA M -03A 2011470 50029201020100 0.25 NA 0.25 NA 0.85 6/3/2009 M -04 1710230 50029201050000 0 NA 0 NA NA 4/14/2012 M -05A 1970810 50029201940100 0.5 NA 0.5 NA 2.6 6/3/2009 M -06A 1930930 50029203670100 0.25 NA 0.25 NA 0.85 6/3/2009 M -07 1790370 50029203730000 0.25 NA 0.25 NA 0.85 6/3/2009 M -08 1800860 50029204990000 1.75 NA 1.75 NA 10.2 6/24/2009 M -09B 2022200 50029205630200 6.25 NA 6.25 NA 44.2 6/3/2009 M -10 1810290 50029205670000 0.25 NA 0.25 NA 2.6 6/4/2009 M -11 1810570 50029205890000 0.25 NA 0.25 NA 1.7 6/4/2009 M -12A 2001510 50029205930100 0.25 NA 0.25 NA 1.7 6/4/2009 M -13A 2011650 50029205220100 2.75 NA 2.75 NA 17 6/4/2009 M -14 1801090 50029205120000 1 NA 1 NA 5.1 6/4/2009 --.)) M -15 1810850 50029206120000 6.75 NA 6.75 NA 55.3 6/4/2009 M -16 1810860 50029206130000 0.25 NA 0.25 NA 1.7 6/4/2009 M -17A 2000320 50029206280100 0.5 NA 0.5 NA 2.6 6/3/2009 M -18B 1930540 50029208550200 10 NA 10 NA 73.1 6/24/2009 M -19B 2081980 50029208970200 Sealed NA NA NA NA 4/13/2012 M -20A 1971990 50029209120100 8 NA 8 NA 52.7 6/24/2009 M -21A 1930750 50029209230100 0.5 NA 0.5 NA 3.4 6/24/2009 M -22 1830540 50029209360000 16 NA 16 NA 117.3 6/23/2009 M -23 1830550 50029209370000 0.25 NA 0.25 NA 1.7 6/4/2009 M -24A 2011260 50029209390100 0.25 NA 0.25 NA 0.85 6/24/2009 M -25 1860650 50029215700000 8 NA 8 NA 55.3 6/3/2009 M -26A 1920280 50029220040100 2.75 NA 2.75 NA 18.7 6/3/2009 M -27A 1930860 50029219920100 0.25 NA 0.25 NA 2.6 6/24/2009 M -28 1860740 50029215780000 1 NA 1 NA 4.3 6/3/2009 M -29A 2000990 50029219040100 1 NA 1 NA 4.3 6/3/2009 M -30 1920300 50029222550000 0.5 NA 0.5 NA 3.4 6/3/2009 M -31 1920320 50029222560000 0.5 NA 0.5 NA 3.4 6/4/2009 M -32 1920330 50029222570000 0.25 NA 0.25 NA 0.85 6/4/2009 M -33 1941160 50029225040000 20 NA 20 NA 133.45 6/24/2009 M -34 1941330 50029225140000 6.25 NA 6.25 NA 25.5 6/3/2009 M -38A 2011320 50029225190100 21.3 NA 21.3 NA 210.8 11/26/2009 OPERABLE: Producer M -15 (PTD #10850) OART Confirms OA Pressure ageable By B1... Page 1 o2' Regg, James B (DOA) ! From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Thursday, August 25, 2011 7:50 PM 1 </1 '/( To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad SW; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Chan, Paul (PRA) Cc: AK, D &C Well Integrity Coordinator; King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: OPERABLE: Producer M -15 (PTD #1810850) OART Confirms OA Pressure Manageable By Bleeds All, An OA repressurization test was conducted on Producer M -15 (PTD #1810850) between 8/19 - 25/2011. After re- energizing the wellhead seals the OA pressure increased 0 psi /day over the length of the test making it manageable by bleeds. Therefore, the well has been reclassified as Operable and may continue on production. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 r Cell (907) 752 -0755 '" Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Wednesday, August 17, 2011 9:29 PM To: 'Regg, James B (DOA)'; AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations Tea • ead; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Fiel. • &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cismoski, Doug A; 'Maunder, Thomas E (DOA)'; 'Schwartz, Guy L (DOA)'; Dani- , Ryan Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer M -15 (PTD #1810850) Sustained Ca ' g Pressure on the OA Above MOASP All, Producer M -15 (PTD #1810850) was found to have stained casing pressure on the OA above MOASP. The tubing /IA/OA were equal to 900/1900/1440 p • on 08/15/2011. The well has been reclassified as Under Evaluation while diagnostics are conduc - d. The plan forward is as follows: 1. W: PPPOT -IC, Re- energize wellhead -eats 2. DHD: OA Repressurization Test A TIO plot and wellbore schem- *c have been included for reference. Thank you, 8/30/2011 UNDER EVALUATION: Producer M ( PTD #1810850) Sustained Casing Pure on the OA... Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.comj Sent: Wednesday, August 17, 2011 9:29 PM � t / To: Regg, James B (DOA); AK, RES GPB West Wells Opt Engr; AK, D &C Wireline Operations Team Lead; AK, RES GPB East Wells Opt Engr; AK, D &C Well Services Operations Team Lead; AK, OPS Prod Controllers; AK, OPS GC2 Field O &M TL; AK, OPS GC2 OSM; AK, OPS GC2 Ops Lead; Cismoski, Doug A; Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Daniel, Ryan Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC) Subject: UNDER EVALUATION: Producer M -15 (PTD #1810850) Sustained Casing Pressure on the OA Above MOASP Attachments: M -15 TIO Plot 08- 17- 2011.doc; M- 15.pdf All, Producer M -15 (PTD #1810850) was found to have sustained casing pressure on the OA above MOASP. The tubing /IA/OA were equal to 900/1900/1440 psi on 08/15/2011. The well has been reclassified as Under Evaluation while diagnostics are conducted. The plan forward is as follows: 1. W: PPPOT -IC, Re- energize wellhead seals 2. DHD: OA Repressurization Test - 56j = 7-G ,� t £ ? A TIO plot and wellbore schematic have been included for reference. (Chce_ «M-15 TIO Plot 08- 17- 2011.doc» «M- 15.pdf» Thank you, Mehreen Vazir (Aiternahe: Gerald Murphy ) ' °.»$� u.4 Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 8/26/2011 PBU M -15 PTD #1810850 8/17/2011 TIO Pressures Plot Weft: M -15 4,000 - s 3,000 — .— Tbg —�- IA 2,000 —�— OA 00A +— 000A On 1,000 • 05/21/11 05/28/11 06/04/11 06/11/11 06/18/11 06.125/11 07/02/11 07/09/11 07/16/11 07/23/11 07/30/11 08/06/11 08/13/11 TREE = 6" CM! WELLHEAD = McEVOY III ACTUATOR = BAKER WI - 1 5 SAFETY N REQUIRES A SSSV. ***4- KB. ELEV = 51.76 1/2" & 5-1 /2" CHROME TBG & 5" CHROME LNR*** BF. ELEV = 26.46' i,•, ■• KOP = 5700' ■ ' • ,■• Max Angle :--; 29 @ 8100' I A 1..... 11+ ....., 2023' ]_J 95/8" HES ES CEMENTER I *A •••■ Datum MD = 9150' Pr , Datum1VD = 8800' SS 1 2126' I-14-1/2" HES X NIP, ID = 3.813" 1 [9-5/8° CSG, 40#, L-80, TO-II, ID = 8.835" H 2036' GAS LIFT MANDRELS 1 13-3/8" CSG, 72#, L-80, ID = 12.347" I—I 2665' I i ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3654 3654 0 MMG DOME RK 16 01/10/07 pv-TAtp= ,53tor; 3 5699 5698 10 MMG SO RK 20 01/10/07 2 7071 6985 20 MMG DMY RK 0 01/10/07 Minimum ID = 3725" @ 8204' 1 7934 7773 28 MMG DMY RK 0 01/10/07 . 4-1/2" XN NIPPLE I 8005' H 4 - 1 1 2" HES X NIP, ID = 3.813" 1 1;23 Orto I 8029' _19-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.870" 1 111 4-1/2" TBG, 12.6#, 13CR-80, VAM TOP —I 8116' I 8 8053' I—I4-1/2" HES X NIP, ID = 3.813" 1 1 .0152 bpf, ID °° 3.958" I 8118' 14 9-5/8" X 4-1/2" UNIQUE OVERSHOT 1 14-1/2" TUBING STUB H 8118' 59, H4 -12" 4 1/2" HES X NIP, ID = 3.813" II 8170' _A9-5/8" X 4-1/2" BKR S-3 PKR, ID = 3.875" 1 ell IIM 8204' H 4- 1 /2" XN NIP, ID = 3.725" 1 14-1/2" TBG, 12.6#, 13CR-80, .0152 bpf, ID = 3.958" 1-1 8226' I I 8224' I—I4-1/2" X 5-1/2" X0, ID = 3.958" I 15-1/2" TUBING STUB 1-1 8225' 1 -15-1/2" CUSTOM TBG OVERSHOT 1 FL ■:14 8244' 1-19-5/8" X 5-1/2" TM/ PKR 1 I 8269' 1-15-1/2" OTIS X NIP, ID = 4.562" 1 1 8285' 1-15-1/2" OTIS XN NIP, ID = 4.455" 1 1TOP OF 5" LNR 1—i 8302' I 15-1/2" TBG, 17#, 13CR-80, .0232 bpf, ID = 4.892" 1 8305' :.-,4, 8305' I-15-1/2" DUMMY SEAL I 8314' H 9-5/8" x 5" TIM! HB-BP PKR w / HGR 1 'TOP OF 7" LNR 1—i 8349' .:- PERFORATION SUMMARY 1 9-5/8" CSG, 47#, L-80, ID = 8.681" I—I 8845' REF LOG: CBL ON 08/27/81 Il ANGLE AT TOP PERF: 25 @ 9012' MARKER JOINT I-1 9098' 1-• Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPN/SQZ DATE 3-3/8" 0.6 9012 - 9050 0 07/03/91 't .■ NIA 2-7/8" 4 9048 - 9086 9100 - 9157 S S 06/18/91 IPBTDJ-1 9460' 2-7/8" 4 06/18/91 15" SCAB LNR, 18#, NT13CR-80, .0188 bpf, ID = 4.276" I 9542' "if ' ' "4, 2-7/8" 4 9166 - 9198 S 06/18/91 1PBTD 1-1 9560. ... # 1 .4444■444444 rf l'ir ',IV 2-7/8" 4 9220 - 9250 S 06/18/91 itt ti 1 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" H 9657' WiNio e 4 ilri . DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 08/81 ORIGINAL COMPLETION 12/20/10 MB/JMD ADDED SSSV SAFETY NOTE WELL: M-15 06/30/91 N18ES RWO PERMIT No: r 1810850 05/29/00 N9ES RWO API No: 50-029-20612-00 12/13/06 N4ES RWO SEC 22, T1 1N, R14E, 606' WEL & 1716' SNL - 01/12/07 TEL/PAG GLV C/O 04/09/07 FRIPJC DRLG DRAFT CORRECTIONS _ BP Exploration (Alaska) 01/05/2007 Schlumberger SCANNED JAN 1 0 2007 NO. 4101 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ..,./ /~I-D~6 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 17 -20 11536189 PRODUCTION PROFILE 12/13/06 1 N-22A 11538587 LDL 12/10/06 1 R-04 11536188 LDL 12/12/06 1 17-12 N/A PRODUCTION PROFILE 11/27/06 1 B-01 N/A LDL 11/28/06 1 J-12 11513655 PRODUCTION PROFILE 11/29/06 1 13-24A 11522675 MEMORY INJECTION PROFILE 11/28/06 1 L2-06 11487579 LDL 11/29/06 1 DS 04-15 11477943 INJECTION PROFILE 12/01/06 1 P-25L 1 11513656 LDL 12/05/06 1 W-29 11549353 USIT 12/18/06 1 P2-50B 11513652 SCMT 11/26/06 1 03-08 11536186 SCMT 12/10/06 1 M-15 11486170 USIT 12/02/06 1 S-31A 11478134 US IT 11/27/06 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: RIAN 1 1) 20m Received by: n rìt!, . . I STATE OF ALASKA . t~1RECE\VEO ALA OIL AND GAS CONSERVATION COM ION ,,10 'AN 0 9 lOO? REPORT OF SUNDRY WELL OPERATIONS J .. C 'ssion ska Oil & Gas Cons. amffil . . fie lor o Re-Enter Suspended Well o Other 1. Operations Performed: o Abandon ~ Repair Well ~ Pull Tubing o Operation Shutdown o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 51.8' 8. Property Designation: ADL 028260 j 11. Present well condition summary Total depth: measured Tubing Size (size, grade, and measured depth): Effective depth: true vertical measured true vertical Length Casing Structural Conductor Surface Intermediate Production Liner Tieback Scab Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 110' 2665' 8845' 1308' 1258' 9657 9309 9460 9132 99519-6612 o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: ~ Development 0 Exploratory 181-085 o Stratigraphic 0 Service 6. API Number: 50-029-20612-00 9. Well Name and Number: "' PBU M-15 10. Field / Pool(s): J Prudhoe Bay Field / Prudhoe Bay Pool feet feet Plugs (measured) 8194 feet Junk (measured) None feet Size MD TVD Burst Collapse 20" x 30" 110' 110' 13-3/8" 2665' 2665' 4930 2670 9-5/8" 8845' 8577' 6870 4760 7" 8349' - 9657' 8136' - 9309' 7240 5410 5" 8302' - 9560' 8095' - 9222' 10140 10490 Sl~ANNED JAN 11 2007 9012' - 9050' 8728' - 8762' 4-1/2",12.6# x 5-112",17# 13Cr80 8305' 9-5/8" x 4-1/2" Baker 'S-3' Packer; Packers and SSSV (type and measured depth): 9-5/8" x 5-1/2" TIW packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13. 8170'; 8244' ]: ], 2007 Oil-Bbl Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory ~ Development 0 Service ~ Daily Report of Well Operations 16. Well Status after proposed work: ~ Well Schematic Diagram ~ Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 306-363 Printed Name Terrie Hubble Signature Form 10-404 Revised 04/2006 .\: .~ ,:,::l I r~AL Title Technical Assistant Phone Date °YD< (O Terrie Hubble 564-4628 Submit Original Only Prepared By NamelNumber: 564-4628 ~q((/ (::',', Dig,ital Wellfile . Well Events for SurfaceWell - M-15 Location: BP -> ALASKA -> GREATER PRUDHOE BAY -> GC2 -> M -> M-15 Date Range: 30/0ct/2006 to 20/Nov/2006 Data Source(s): DIMS, AWGRS Events Source Well AWGRS M-15 AWGRS M-15 AVLG.ßS M -15 AWGRS M-15 AWG.RS M-15 AWGRS M-15 AWGRS M-15 Date 11/20/2006 11/18/2006 11/14/2006 11/11/2006 11/08/2006 11/08/2006 11/07/2006 AwG.R5 M-15 11/06/2006 A WG.Rs M-15 11/06/2006 AWGRS M-15 11/04/2006 AWG~RS M-15 10/30/2006 . Page 1 of 1 Description T/I/O=VAC/10/0+ Temp=SI Supersuck gravel fo cellar liner (pre-RWO). Removed remainder of gravel out of cellar down to cement. Landing ring is exposed all the way around for liner install. T/I/O=VAC/10/o+ Temp=SI Install Rhinohide cellar liner (pre-RWO). Removed approximately 60% of gravel that is required to prep cellar for Rhinohide. Cement showed up l' below landing ring. Continue tomorrow. T/I/O=VAC/1o/0+. Temp=SI. Eval Cellar. (Pre Cellar Liner Installation). Cellar is "'3' deep, and will need "'4' of gravel removed to expose "'2' of the conductor. A heater was ordered to thaw the cellar. SHOT STRINGSHOT FROM 8119'-8131'. CHEMICAL CUT TUBING AT 8129'. CORRELATED TO BRIDGE PLUG SETTING RECORD ON 4-NOV-2006. HAD TO JAR ON TOOL TO GET LOOSE AFTER SHOOTING CHEMICAL CUTTER. T/I/O 0/0/0. ***JOB COMPLETE*** T/IA/OA = SI/O/O (Pre Rig Inspection) PPPOT-IC = Passed PPPOT-T = Passed Bled inner casing packoff void to 0 psi. Torqued lockdown pins to 550 ft/lbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up void to 3,800 psi. for 30 mins. = Passed Bled tubing hanger void to 0 psi. Torqued lockdown pins to 550 ftjlbs. Rigged up test equipment and pumped until clean fluid returns were achieved. Pressured up tubing hanger void to 5,000 ft/lbs. for 30 mins. = Passed T/I/O = VAC/0/2.5. Temp = S/I. ALP = 1980 psi, AL S/I at casing valve. Check WHPs. Bleed residual pressure (pre-Rig). Bled OAP to a bucket from 2.5 psi to 0 psi in < 1 min. Ice has extruded from flutes, no active bubbling. ***WSR continued from 11/06/06*** Circ Out Wellbore (PRE RWO) Pump 5 bbls neat, 872 bbls 1% KCL, and 152 bbls diesel down the TBG while taking IA returns to the flowline. Notify supervisor of liquid bubbling around the conductor. Cleared by ACS to continue. U-Tube for 30 minutes. CMIT- Tx IA to 3500 psi.[Passed on the first attempt] Lost 80 psi / 1st 15 min and 40 psi / 2nd 15 min. Pumped 8 bbls of 50* diesel to acieve test pressure. Bled well pressure down to 0 psi. Freeze protected flowline w/ 7 bbls neat meth, and 72 bbls diesel. Final WHP' s = 0/0/0. T/I/O = 680/750/60. Circ Out Well bore (PRE RWO) ***WSR continues on 11/07/06*** T/I/O=690/690/+o. Temp=SI. A/L 51 @ IA casing valve. T& IA FL pre-CMIT (pre-rig). TBG FL @ 5582' (88 bbls). IA FL @ 5920' (443 bbls). IA has Integral installed. Initial T/I/O: 900/600/0 Set HALLIBURTON FASDRILL PLUG @ 8194'. PLUG TAGGED TO ENSURE SETTING DEPTH. A 1.56" SMALL TUBING PUNCHER WAS SHOT FROM 8102-8104'. A TOTAL OF 9 SHOTS FIRED, 4 shots/foot. TUBING AND IA EQUALIZED AFTER FIRING. WELL LEFT SHUT IN, WITH SSV OPEN AS PER PAD OPERATOR REQUEST. Final T/I/O: 750/700/0 Will Return at later date to run string shot and chemical cut tubing. *** CONT FROM 10-29-06 *** PULL PRONG FROM 8164' SLM. PULL 4.5 PXN FROM 8172' SLM. DRIFT W/ 3.70 CENT. TO 8500' SLM. *** WELL S/I ON DEPARTURE *** http://digitalwellfile.bpweb. bp.com/W ellEvents/Home/Default.aspx 1/9/2007 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 11/28/2006 00:00 - 01 :30 1.50 RIGD P PRE Slip & cut 550' of sand line. RID rig. 01 :30 - 03:00 1.50 RIGD P PRE Scope down & lower derrick. Con't to rig down 03:30 - 06:00 2.50 RIGD P PRE RID Remove matting from under rig, pits & pipe shed. 06:00 - 07:00 1.00 RIGD P PRE Crew change. Hold PJSM wi Peak & moving personnal 07:00 - 23:00 16.00 MOB P PRE Move rig from 04-14i to M-Pad. Approx. 30 mile move. 23:00 - 00:00 1.00 RIGU P PRE Lay Herculite & spot matting boards. Spot camp. Prep to spot rig over M-15. 11/29/2006 00:00 - 01 :00 1.00 RIGU P PRE Spot rig over M-15 well. Spot in pits & pipe shed. ACCEPTED RIG @ 0100 hrs. 01 :00 - 02:00 1.00 RIGU P DECOMP Raise & scope up derrick. Con' to RlU rig & equip. 02:00 - 03:00 1.00 RIGU P DECOMP Hook Up lines to Tiger Tank& tree. Install 2nd annular valve. 03:00 - 05:00 2.00 RIGU P DECOMP Take on 120 degree heated seawater. Finish RlU. 05:00 - 06:00 1.00 WHSUR P DECOMP P/U lubricator & pull BPV. UD same. SITP = 0 psi, SICP = 0 psi. 06:00 - 07:00 1.00 KILL P DECOMP Pre tour meeting, rig service. 07:00 - 07:30 0.50 KILL P DECOMP Pre kill safety meeting with all associated personel. 07:30 - 10:30 3.00 KILL P DECOMP Test all lines to 3500 psi, OK. Line up and displace well to heated seawater, no gas back, circulate out all diesel, taking returns thru the choke to the tiger tank, 5 bpm I 650 psi. 620 bbls total pumped. 10:30 - 12:00 1.50 KILL P DECOMP PJSM. Line up & pressure test tubing x IIA @ 1000 psi to verify integrity of downhole plug, charted, good test. Set two way check & test from above & below @ 1000 psi, 10 minutes each, charted, OK. 12:00 - 12:30 0.50 KILL P DECOMP Rig down & blow down lines. 12:30 - 14:00 1.50 WHSUR P DECOMP PJSM. NID tree & adapter. Check lock downs, hanger threads. 8 1/2 turns on the hanger threads wi 7" NSCC crossover, threads look good. 14:00 - 17:30 3.50 BOPSU DECOMP PJSM. NIU 135/8" x 5M BOPE. Change out blind rams to blind I shear rams. 17:30 - 18:00 0.50 BOPSU DECOMP RlU test equip. M/U 3 1/2" test jt. 18:00 - 18:30 0.50 BOPSU DECOMP Crew change. Inspect derrick. Check PVT alarms. 18:30 - 20:00 1.50 BOPSU DECOMP Attempt to test choke manifold valves #1, 2, &12. No joy. Hunt for leaks. Found small drip from annulus. Blow down lines & drain stack. 20:00 - 21 :00 1.00 BOPSU DECOMP Wait on Cameron & DSM. 21 :00 - 21 :30 0.50 BOPSU DECOMP Torq up lock down screws. Fill stack & & attempt test. No good. 21 :30 - 22:30 1.00 BOPSU DECOMP P/U lubricator & pull TWC. Inspect same. Much scale & debris on plug. Install 2nd TWC. UD lubricator. 22:30 - 23:00 0.50 BOPSU DECOMP Fill stack & pressure test plug from top. Still leaking oft @ slower rate. Occasional drip out annulus. 23:00 - 23:30 0.50 BOPSU DECOMP P/U lubricator & pull TWC. Flush out hanger profile wi clean seawater. 23:30 - 00:00 0.50 BOPSU DECOMP Install TWC in hanger profile. 11/30/2006 00:00 - 01 :00 1.00 BOPSU DECOMP Pressure up & test TWC from top to 3500 psi for 10 min. Much joy! Test TWC from bottom wi 1000 psi for 10 min. Charted both tests. 01 :00 - 07:00 6.00 BOPSU P DECOMP Pressure test BOPE equip as per BP/AOGCC. LP 250 psi. HP 3500 psi. BOP test witnessing waived by John Crisp wi AOGCC. 07:00 - 08:00 1.00 BOPSU DECOMP Rig down test equipment. 08:00 - 11 :00 3.00 BOPSU DECOMP Wait on valve shop to puill 2 way check, (hands are changing Printed: 12/18/2006 11 :26:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 out). Pick up lubricator, pull 2 way check, UD lubricator. P PJSM. Pick up landing joint, back out lock down screws & pull hanger to floor. Hanger came loose w/11 OK up wt, & leveled off @ 105K up wt. 12:30 -18:00 5.50 PULL P DECOMP POOH & UD 4 1/2" tbg. BOP drill while POOH. 18:00 - 00:00 6.00 PULL P DECOMP Con't to POOH & UD 41/2" 12.6#, 13Cr, New Yam tubing completion. Having trouble wi slips gripping pipe. Total recovery: 187 full jts, 6 GLMs, 1 "X" Nipple Assy, + 20.82' Cut off jt. Chemical cut was clean & uniform. 12/1/2006 00:00 - 01 :00 1.00 PULL P DECOMP Clear & Clean rig floor. RID 4 1/2" tubing handling tools. 01 :00 - 01 :30 0.50 WHSUR P DECOMP Install Wear Bushing. RILDS. RlU DP handling tools. 01 :30 - 03:00 1.50 CLEAN P DECOMP Load, tally & MIU BHA #1 to dress off tubing stub as follows: Dress Off Shoe, WP Ext, Inside Mill, Top Sub, PxP, 2 - Boot Baskets, Csg Scraper, BS, LBS, Jars, XO, 9' 6 1/4" DCs, XO. TL = 322.79'. RIH wi same. 03:00 - 10:00 7.00 CLEAN P DECOMP P/U 3 1/2" DP 1x1 & RIH wi BHA #1.246 jts. 10:00 - 12:00 2.00 CLEAN P DECOMP PJSM. PIU kelly & establish parameters. 147K up wt, 129K down wt, 135K rotating wt. See top of tubing stub 9' in on kelly @ 8118'. Rotate @ 5060 RPM, 3000 - 4000 Wlbs of torque & mill off 2", swallowing 9' of stub, OK. Stand back kelly. 12:00 - 14:30 2.50 CLEAN P DECOMP PJSM. Close bag, line up & reverse circulate Hi Vis sweep around @ 6 bpm I 700 psi, 600 bbls pumped, nothing significant back across shaker. 14:30 - 16:00 1.50 CLEAN P DECOMP PJSM. Slip & cut drilling line. 16:00 - 19:00 3.00 CLEAN P DECOMP PJSM. POOH w/3 1/2" DP & dress off BHA. 19:00 - 21 :00 2.00 CLEAN P DECOMP Stand back 3 stands of DCs. Break out & UD BHA. 21 :00 - 22:00 1.00 CLEAN P DECOMP Clean out junk baskets. Clear & Clean rig floor. 22:00 - 23:00 1.00 CLEAN P DECOMP RID air boots & pull flow riser. Install Shooting flange. 23:00 - 00:00 1.00 EVAL P DECOMP RlU E-line equip. 12/2/2006 00:00 - 01 :00 1.00 EVAL P INTERV Finish RlU E-line equip. Pressure test Pack off to 500 psi, OK. Drain stack 01 :00 - 06:00 5.00 EVAL P INTERV Run USIT log from 8100' to surface. 06:00 - 10:30 4.50 EVAL P INTERV Make repass on USIT log. Top of cement @ 2088'. Collars @ 2070' & 2032'. Rehead & make string shot run, fire string shot across 2026' - 2038'. POOH wi Eline. 10:30 - 15:30 5.00 EV AL P INTERV PJSM. Rig down Eline, N/D shooting flange, repair flow nipple & N/U same. 15:30 - 16:00 0.50 DHB P INTERV PJSM. Pick up Halliburton 9 5/8" retrievable bridge plug. 16:00 - 17:00 1.00 DHB P INTERV RIH wi RBP on 34 stands of 3 1/2" DP. 17:00 - 18:00 1.00 DHB P INTERV Space out & set RBP. Out 25' of stand #34. Middle of element @ 3205' Top of plug @ 3200'. 18:00 - 22:00 4.00 DHB P INTERV Safety stand down wi all hands. Meeting attended by WLS, TPs, crew, 2 - RLG reps, A. Graff, G. Christman, J. Moore. 22:00 - 22:30 0.50 DHB P INTERV RlU test equip. Pressure test RBP to 1000 psi for 10 min. Charted same. Good test. 22:30 - 00:00 1.50 DHB P INTERV Dump 2200# of 20/40 sand on top of RBP. Allow sand to fall. 12/3/2006 00:00 - 02:00 2.00 DHB P INTERV Heat 9.8 ppg brine to 120 degrees. Allow sand to fall over RBP.. 02:00 - 02:30 0.50 DHB P INTERV RIH & tag up on top of sand @ 3167'. (33' of sand above RBP) 02:30 - 04:00 1.50 DHB P INTERV Displace well to 9.8 ppg heated brine. 5 BPM @ 280 psi. Pumped 230 bbls. RID circulating equip. 04:00 - 05:00 1.00 DHB P INTERV POOH & stand back 31/2" DP. 05:00 - 06:00 1.00 CASRE P INTERV P/U & M/U BHA to cut casing. Printed: 12/18/2006 11:26:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: Spud Date: 8/6/1981 End: 12/13/2006 12/1/2006 12/13/2006 Safety stand down with day crew. Attended by welder & electrician, as well as A Graff & (2) RLG reps, day & nite well site leaders, tool pusher & tour pusher. INTERV Finish running collars & RIH wi cutter assembly on 31/2" DP. Kelly up on stand # 18. INTERV PJSM. Establish parameters. 55K up wt, 56K down wt, 57K rotating wt. 60 amps or 1200 Wlbs free spin torque. Bring on pump @ 4 bpm 1450 psi & slack off, taking wt 15' in on kelly @ 1995'. (Collar). Shut down pump & run in another 17' to 2012'. Kick in rotary table @ 50 - 60 RPM & gradually bring up pump rate to 5 bpm 1700 psi. After approximately 10 minutes, observe rotary table stall wi 9000 Wlbs of torque. Shut down pump, let torque out of rotary table & bring on rotary again @ 60 RPM. Bring up pump to 5 bpm / 700 psi & after 5 -10 minutes observe stall again, indicating 9 5/8" probably set in compression and as the cut is made the 9 5/8" casing is setting down on the cutter blades. Shut down rotary & pump. Casing is cut @ 2012'. INTERV PJSM. Close annular preventor and pressure up DP & 9 5/8" annulus to 500 psi, no returns up 133/8" x 9 5/8" annulus. Pressure up to 1000 psi & observe returns to tiger tank. Significant amount of gas in returns, shut down & reroute thru choke. Resume circulating heated 9.8 ppg brine down DP, taking returns up 13 3/8" x 9 5/8" annulus, thru choke to open top tank. 4 bpm 11100 psi. Pump 100 bbls & see 9.8 brine retu rns. INTERV PJSM. Stand back kelly, make up headpin & rig up Little Red. Test lines & pump 50 bbls 120 degree diesel down DP & chase wi 30 bbls of heated 9.8 ppg brine. Let soak in 13318" x 9 5/8" annulus to clean up arctic pack. Crew Change. Check PVT alarms, Inspect derrick. Pump 50 bbls of 120 diesel & diplace wi hot 9.8 ppg brine. Pumped 2 BPM @ 90 psi. Allow diesel to soak in annulus for 1 hr. Circulate out Arctic Pack. Pump 5 BPM @ 1600 psi. Pumped 120 bbls of brine. Getting some Arctic Pack in returns, appears to be cleaning up. Return fluid not very hot. Allow hot brine to loosen & heat up Arctic Pack for 1 1/2 hrs. Circulate out Arctic Pack. Pump 5 BPM @ 1600 psi. Pumped 100 bbls return fluid hot & returns cleaned up. Monitor well, well static. RID circulating equip & Blow down lines. RlU to POOH. POOH & stand back 31/2" DP. POOH & stand back 31/2" DP. UD cutting assy. Pull Wear Bushing UD running tool. N/D BOP & set back stack. N/D tubing spool. Pull pack off. Secure slips to casing. N/U BOPE. Pressure test break on BOP stack to 1000 psi. Ok. PJSM. Service rig & check PVTs & crown 0 matic, derrick inspection. PJSM. Engage spear in 9 5/8" casing, BOLDS. PJSM. Pull 9 518" casing, 94K up wt. Break out spear, recover 10:00 - 13:00 13:00 - 14:00 14:00 - 15:30 1.50 CASRE P 15:30 - 18:00 18:00 - 18:30 INTERV 18:30 - 19:30 INTERV 19:30 - 20:30 INTERV 20:30 - 21 :00 INTERV 21 :00 - 22:30 INTERV 22:30 - 23:00 INTERV 23:00 - 23:30 INTERV 23:30 - 00:00 INTERV 12/4/2006 00:00 - 01 :00 INTERV 01 :00 - 01 :30 INTERV 01 :30 - 02:30 INTERV 02:30 - 03:30 INTERV 03:30 - 05:00 INTERV 05:00 - 06:00 INTERV 06:00 - 07:00 INTERV 07:00 - 08:00 1.00 FISH P INTERV 08:00 - 09:30 1.50 FISH P INTERV Printed: 12/18/2006 11:26:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/4/2006 08:00 - 09:30 1.50 FISH P INTERV slips, UD spear & M/U headpin. 09:30 - 12:30 3.00 FISH P INTERV PJSM. Line up and circulate heated 9.8 ppg brine down 9 5/8" & up 9 5/8" x 13 3/8" annulus while reciprocating pipe to enhance cleaning up arctic pack from well bore. Observing medium amounts of gas breaking out at surface while doing so. Gas still percolating up after one complete bottoms up. Opt to circulate a total of 375 bbls or (3) complete bottoms up, 5 bpm 1125 psi. Monitor well, well stable. 12:30 - 18:00 5.50 FISH P INTERV PJSM. POOH w/9 5/8" casing, hole is taking a bit more than estimated displacement. 18:00 - 18:30 0.50 FISH P INTERV Crew change. Check PVT alarms. Inspect derrick. 18:30 - 21 :00 2.50 FISH P INTERV Con't to POOH & UD 9 5/8" casing. connections taking up to 26k ft-Ibs of torq to break, having to hammer on coupling to break free. Recovered 52 full jts + 16.30' cut off. Cut end was belled wi internal stiations up in jt -2". Confirming idea that casing was in compression. Hole took additional 40 bbls of fill over trip displacement volume. 21 :00 - 23:00 2.00 FISH P INTERV RID casing equip. Clear & clean rig floor. 23:00 - 00:00 1.00 FISH P INTERV P/U 1 st jt wi spear in it. Break out spear from casing & UD same. 12/5/2006 00:00 - 01 :00 1.00 FISH P INTERV PIU & M/U BHA #3 as follows: Bull Nose, Csg Scraper, Boot Basket, BS, XO, Bumper Sub, Jars, XO, 9861/4" DCs, XO. TL= 307.64 01 :00 - 02:00 1.00 FISH P INTERV RIH wi BHA #3 on 3 1/2" DP & scrape casing to 2007'. 02:00 - 05:00 3.00 FISH P INTERV M/U circulating head. Close in annular. Reverse & sweep hole clean. Transfer recovered AP out to aux. tank. Mix & Pump 30 bbl Hi-Vis sweep. 5 BPM @ 500 psi. PIU & SIO Wts = 55K. Had small amount -2% of Arctic Pack in returns. SID monitor well. UD circulating pin. 05:00 - 06:00 1.00 FISH P INTERV POOH & stand back 3 1/2" DP & 3 stands of 6 1/4" DCs. 06:00 - 07:30 1.50 FISH P INTERV PJSM. UD 9 5/8" scraper assembly. 07:30 - 08:00 0.50 FISH P INTERV Service rig, check PVT system, derrick inspection, crown 0 matic, OK. 08:00 - 11 :00 3.00 FISH P INTERV PJSM. Make up washpipe assembly. 11 :00 - 12:00 1.00 FISH P INTERV PJSM. RIH w/3 1/2" DP, 17 stands & (2) singles. 12:00 - 13:30 1.50 FISH P INTERV PJSM. P/U kelly. 55K up wt, 56K down. Torque = 60 amps or 1200 tv Ibs. Tag top of 9 5/8" stump @ 2012'. Kick in rotary table @ 5 RPM & rotate over stump, pumping 5 bpm I 320 psi, see collar @ 2035', no issues there, go to 2043'. Pick up & go over stump without rotating, OK. 13:30 - 14:00 0.50 FISH P INTERV PJSM. CBU, 5 bpm 1325 psi. 14:00 - 15:00 1.00 FISH P INTERV PJSM. POOH. 15:00 - 18:00 3.00 FISH P INTERV PJSM. UD wash pipe BHA. 18:00 - 19:00 1.00 FISH P INTERV Pre-tour safety meeting and pre-tour inspection of Rig. Clear and clean Rig Floor. 19:00 - 21 :00 2.00 FISH P INTERV PU and MU BHA #5 as folllows: Casing Swage, XO, (9) 6 1/4" DCs, XO, Blanking Sub, Lower Anchor Section, Power Section, Upper Anchor Section, XO, XO, Pump Out Sub. OAL = 320.99'. 21 :00 - 23:00 2.00 FISH P INTERV TIH with BHA #5 on 3 1/2" DP from the Derrick. 23:00 - 00:00 1.00 FISH P INTERV In with 21 stands and a single (64 Joints) of DP. Saw top of 9 5/8" Stump @ 2,012'. UW = 60K, DW = 60K. MU Headpin. PU 5' from Rotary Table to place BHA on depth to ensure anchors Printed: 12/18/2006 11 :26:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/5/2006 23:00 - 00:00 1.00 FISH P INTERV are above and below the collar @ 2,034'. Begin back-off process. Pressure up to 1,200 psi to set lower anchor section. Slack off 40K to verify anchors set - OK. Bleed pressure off. Pressure up to 2,500 psi to set upper anchor section. Initiate backing off of Joint by increasing pressure to activate power section. Averaged 1/2 a turn @ 800 psi. Completed a total of 5 turns. 12/6/2006 00:00 - 02:00 2.00 FISH P INTERV Blow down lines. Break off and lay down Headpin. TOH with BHA #5 standing back DP in the Derrick. 02:00 - 03:00 1.00 FISH P INTERV Break down and lay down BHA #5 components. 03:00 - 04:00 1.00 FISH P INTERV Clear and clean Rig Floor and all handling equipment due to Arctic Pack. 04:00 - 04:30 0.50 FISH P INTERV PU and MU BHA #6 as follows: Bull Nose, Bowen ITCO Spear, Spear Extension, Stop Sub, Bumper Sub, XO, (9) 6 1/4" DCs, XO. OAL = 293.74'. 04:30 - 05:30 1.00 FISH P INTERV TIH with BHA #6 on 31/2" DP from the Derrick. 05:30 - 06:00 0.50 FISH P INTERV In the hole with 18 stands (54 Joints) of DP. PU and MU Kelly. UW = 55K , DW = 55K. Tag top of Stump @ 2,012'. Stack 20K on Stop Sub. PU and pull 30K over to verify Spear is engaged. Engage Rotary Table and turn to the left 8 times. POH with an UW = 58K - got the Fish! Blow down and set back Kelly. 06:00 - 06:30 0.50 FISH P INTERV Service rig, check PVT system, derrick inspection & check crown 0 matic, OK. 06:30 - 08:00 1.50 FISH P INTERV PJSM. POOH w/3 1/2" DP & spear assembly. 08:00 - 09:30 1.50 FISH P INTERV PJSM. UD spear BHA, UD recovered 9 5/8" partial, 22.63'. Recovered pin end, threads look very good. 09:30 - 12:30 3.00 CASE P TIEB1 PJSM. Clear I clean rig floor, rig up to run casing. Rig up torque turn equipment. 12:30 - 18:00 5.50 CASE P TIEB1 PJSM. M/U triple connect screw in sub assembly, all connections Baker Locked & made up at Baker Machine shop including baffle plate, ES cementer & xJo. RIH on 9 5/8" 40# L-80 TC-II casing, torque turning to 12,600 Nibs, using Jet Lube Seal Guard pipe dope & filling every 5 jts wi 9.8 ppg brine. (1) free floating centralizer installed per each joint above ES cementer. 18:00 - 21:00 3.00 CASE P TIEB1 Continue RIH with 95/8",40# L-80 TC-II Casing. Tag 9 5/8" Collar 16' in with Jt #51. Lay down Jt #51. PU 19.98' Pup Joint. 21 :00 - 21 :30 0.50 CASE P TIEB1 Establish parameters: UW = 80K, DW = 80K, RW = 80K. Free rotating torque = 800 ft-Ibs. Begin screwing into collar. 12 full turns achieved and began torquing up on 13th turn. Final make up torque = 12,000 ft-Ibs. Pull test to 250K - good. 21 :30 - 22:00 0.50 CASE P TIEB1 RU Test Equipment and Headpin on 9 5/8". 22:00 - 22:30 0.50 CASE P TIEB1 Pressure test the 9 5/8" to 2,000 psi for 30 mins, charted - OK. 22:30 - 00:00 1.50 CASE P TIEB1 Increase pressure to open ES Cementer. At 2,800 psi it opened with no problems. Circulate hot 9.8 ppg brine all the way around to warm up wellbore. Break circulation at a rate of 5 bpm 1130 psi. Pumped a total of 270 bbls. 1217/2006 00:00 - 01 :00 1.00 CASE P TIEB1 PJSM. Split the BOP Stack. Pull 150K tension on the Casing. Set emergency slips with Cameron reps. Energized the slips - OK. RILDS. 01 :00 - 03:00 2.00 CASE P TIEB1 NU BOP Stack. Pressure test break to 1,000 psi. MU Cement Head. RU lines in preparation for cement job. 03:00 - 05:00 2.00 CASE P TIEB1 Circulate hot 9.8 ppg brine to condition wellbore. Break Printed: 12/18/2006 11:26:59 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1 /2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/7/2006 03:00 - 05:00 2.00 CASE P TIEB1 circulation at a rate of 5 bpm I 425 psi. SWS Cementers arrive on location. Circulate until returns are at least 80 degrees. Pumped a total of 525 bbls and achieved returns of 82 degrees. 05:00 - 06:00 1.00 REMCM P TIEB1 RU SWS Cementers. Load closing Plug with Halliburton rep. PJSM with Nabors, Schlumberger, Halliburton and Veco personnel. 06:00 - 06:30 0.50 REMCM P TIEB1 Crew change, pre job meeting with crew coming on. 06:30 - 07:30 1.00 REMCM P TIEB1 Pump 5 bbls water ahead, test lines to 4000 psi, OK. Pump 145 bbls 15.8 ppg class G cement wi Gas Blok down 9 5/8" casing, taking returns thru choke to pits, holding back pressure & increasing back pressure as cement fills 9 5/8" casing to a maximum of 500 psi. wi 145 bbls away, shut down cementers pump & shut in choke, 590 psi on choke. Drop plug & chase wi 4 - 5 bbls cement on top of plug & displace wi 9.8 ppg brine, continuing to hold back pressure on choke, starting wi 500 psi & gradually decreasing as cement comes up 9 5/8" x 133/8" annulus. WI 100 bbls displaced, bypass choke & take returns to outside tank. With 130 bbls displaced, see cement returns to outside tank. Observe plug bump wi 150 bbls displaced & pressure up to 1900 psi to close ES Cementing tool. Bleed off pressure & check for flow back, no flow back, 3/4 bbl back during bleed off. Average rate & pressure while pumping cement = 4.9 bpm I 350 psi. Average rate & pressure while displacing = 5.9 bpm 1600 psi. CIP @ 07:30. 07:30 - 09:00 1.50 REMCM TIEB1 PJSM. Blow down lines, rig down cementers. 09:00 - 10:30 1.50 BOPSU TIEB1 PJSM. NID stack & pick up same, prep for casing cut. 10:30 - 15:30 5.00 BOPSU TIEB1 PJSM. Utilize Wachs cutter & make cut on 95/8" casing, cut off 6.23' of jt #50. Stand stack back. Install 13 5/8" split speedhead w/2 1/16" x 5M annulus valves. Energized "Y" seal in packoff & tested to 2400 psi for 30 minutes, good test witnessed by well site leader. Installed upper test plug. 15:30 - 16:00 TIEB1 Safety meeting wi crew facilitated by Nabors Manager Dave Hebert. 16:00 - 18:00 2.00 BOPSU TIEB1 PJSM. NIU 135/8" x 5M BOPE. RU Test Equipment. 18:00 - 18:30 0.50 BOPSU TIEB1 Pre-tour safety meeting and daily Rig inspection with night crew. 18:30 - 23:30 TIEB1 Test BOPE per BP/AOGCC Regulations to 250 psi low and 3,500 psi high. The state's right to witness the test was waived by Chuck Scheve on 12/7/06 at 17:00 hrs. The test was witnessed by WSL and Tourpusher. At 20:00 hrs, the UCA analysis showed 500 psi compressive strength. At 23:00 hrs, the UCA analysis showed 1,000 psi compressive strength. 23:30 - 00:00 0.50 BOPSU P TIEB1 RD Test Equipment. 12/8/2006 00:00 - 01 :00 1.00 BOPSU P TIEB1 Drain BOP Stack. Pull Test Plug. Set Wear Ring. 01 :00 - 01 :30 0.50 CLEAN P CLEAN PU and MU BHA #7 as follows: 8 1/2" Bit, Boot Basket, Boot Basket, Bit Sub, Bumper Sub, Oil Jar, XO, (9) 6 1/4" DCs, XO. OAL = 305.06'. 01 :30 - 02:30 1.00 CLEAN P CLEAN TIH with BHA #7 on 3 1/2" DP from the Derrick. Tag cement @ 1,937'. PU and MU Kelly. UW = 55K , DW = 55K. 02:30 - 06:00 3.50 CLEAN P CLEAN Mill on cement with BHA #7. Break circulation at a rate of 5 bpm I 250 psi. RW = 55K at -80 RPM with about 1,000 ft-Ibs of torque. Maintaining about 1 OK WOB. Printed: 12/18/2006 11:26:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/8/2006 06:00 - 07:30 1.50 CLEAN P CLEAN Continue milling shoe track, thru shoe track @ 2031'. 07:30 - 08:30 1.00 CLEAN P CLEAN Stand back kelly, run on in hole to top of junk I sand @ 3162'. Make up head pin. 08:30 - 10:00 1.50 CLEAN P CLEAN PJSM. Displace well from 3163' to surface wi seawater, 5 1/2 bpm @ 650 psi. 10:00 - 11:00 1.00 CLEAN P CLEAN POOH wi shoe track milling BHA. 11 :00 - 12:30 1.50 CLEAN P CLEAN PJSM. UD BHA, empty junk subs, nothing significant in junk subs. 12:30 - 13:30 1.00 CLEAN P CLEAN PJSM. Fill hole, close blind rams, pressure 9 5/8" casing from surface to top of junk I sand @ 3162',3500 psi, 30 minutes, charted, good test. Monitored OIA, no indication whatsoever of communication of I/A with O/A. 13:30 - 15:00 1.50 CLEAN P CLEAN PJSM. M/U reverse circulating junk basket BHA. 15:00 - 16:00 1.00 CLEAN P CLEAN PJSM. RIH wi RCJB assembly on 3 1/2" DP. 30 stands. 16:00 - 17:00 1.00 CLEAN P CLEAN PJSM. 74AK up wt, 73K down wt. Pick up kelly & tag up @ 3146',16' high...? Double check figures & attempt to break circulation. Pressure up to 2000 psi w/1 1/2 bbls pumped. Bleed off & break out kelly, verify kelly not plugged. Re kelly up, pressure up to 3000 psi. Bleed off pressure, close bag & reverse circulate @ 4 - 5 bpm @ 1500 - 2000 psi, good returns. Bleed pressure, open bag & circulate down the DP @ 5 bpm I 1800 psi, OK. Slack off & wash down 5' to get rotary bushings in. Rotate @ 20 - 30 RPM & circulate @ 4 - 5 bpm to 3171'. Call it good. Stand back kelly. 17:00 - 18:00 1.00 CLEAN P CLEAN PJSM. POOH (1) stand & observe overpull to 110K 15' out on 2nd stand. Setting down to 50K, junk up around shoe below jars, (see jars working). Work pipe to 130K, no good, slack off & make up head pin to circulate. Establish circulation and work pipe free. Able to move down. PU slowly and observe slight overpull but able to get past stuck point. DP plugged off and reversed clean OK. 18:00 - 18:30 0.50 CLEAN P CLEAN Service Rig and pre-tour checks with new night crew. 18:30 - 20:30 2.00 CLEAN P CLEAN Continue TOH with BHA #8 standing back DP in the Derrick. 20:30 - 22:00 1.50 CLEAN P CLEAN On surface with BHA #8. Inspect and empty out Junk Baskets. Recovered rubber cone and the complete ring plus 8 chunks of cement. The BHA components were plugged off with sand. Break down and clean out each component. Recovered approx. 5 gallons of sand in the baskets and BHA components. Re-make up BHA components (BHA #9) to re-run in the hole. 22:00 - 00:00 2.00 CLEAN P CLEAN TIH with BHA #9 on 3 1/2" DP from the Derrick. At 2,027' stack about 5-10K. Work pipe and fell right through it. Continue TIH. 12/9/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Continue TIH with BHA #9 on 3 1/2" DP. 00:30 - 01 :30 1.00 CLEAN P CLEAN In with 91 Joints of DP. UW = 70 K , DW = 70K. Tag fill/sand @ 3,162'. PU and MU Kelly. Break circulation at a rate of 5.5 bpm 11,775 psi. Work RCJB down to 3,180' with no problems. 01 :30 - 03:00 1.50 CLEAN P CLEAN Pump a 25 bbl hi-vis sweep around to help clean out the well bore. Pump at a rate of 4.5 bpm 11,100 psi. Got rubber, cement and sand across the Shaker. Blow down and set back Kelly. 03:00 - 05:00 2.00 CLEAN P CLEAN TOH with BHA #9 standing back DP in the Derrick. 05:00 - 06:00 1.00 CLEAN P CLEAN Break down and inspect Junk Baskets. Recovered (4) brass shear pins, pieces of rubber and pieces of the aluminum sleeve. Re-make up BHA components as BHA #10. Printed: 12/18/2006 11:26:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/9/2006 06:00 - 07:00 1.00 CLEAN P CLEAN M/U 3rd RCJB BHA. 07:00 - 07:30 0.50 CLEAN P CLEAN Service rig, check PVTs, crown 0 matic, OK. 07:30 - 08:30 1.00 CLEAN P CLEAN PJSM. RIH wi RCJB on 3 1/2" DP, 30 stands. Kelly up & break circulation to verify tool is clear, 4 bpm I 400 psi. 73K up wt, 74K down wt. 08:30 - 10:00 1.50 CLEAN P CLEAN PJSM. Break kelly, drop ball to divert flow to RCJB jets. Ball on seat, pump 5 bpm, 1700 psi to verify jets clear, OK. Rotate wlo pumping f/3180' to 3182', kick on pump @ 5 bpm 11700 psi & vacuum from 3182' - 3186'. 10:00 - 11 :00 1.00 CLEAN P CLEAN PJSM. Pump Hi Vis sweep around, nothing significant back, OK. 11 :00 - 12:30 1.50 CLEAN P CLEAN PJSM. Stand back kelly, POOH. 12:30 - 14:00 1.50 CLEAN P CLEAN PJSM. Stand back collars, break down RCJB, empty junk subs. A few pieces of rubber. Weather is kind of bad, semi low visibility, so call Hallliburton to be here @ 20:00 hrs & opt to make (1) more RCJB run. 14:00 - 15:00 1.00 CLEAN P CLEAN PJSM. Make up RCJB wi extension below fingers, distance from bottom of shoe to bottom fingers = 4.65'. 15:00 - 16:30 1.50 CLEAN P CLEAN PJSM. RIH wi RCJB on 3 1/2" DP, 30 stands & (1) single. Kelly up. 73K up wt, 74K down wt. 16:30 - 17:00 0.50 CLEAN P CLEAN PJSM. Drop ball. Circulate @ 5 bpm, 900 psi, no indication of ball on seat. Slack off 8' in on kelly, tag top of bridge plug @ 3189' DPM. 17:00 - 17:30 0.50 CLEAN P CLEAN PJSM. Circulate Hi vis sweep around, 5 bpm 1900 psi. 17:30 - 20:00 2.50 CLEAN P CLEAN PJSM. POOH w/3 1/2" DP & RCJB. 20:00 - 21 :00 1.00 CLEAN P CLEAN On surface with BHA #11. Break down BHA components and close Blind Rams. Clear and clean Rig Floor and secure well. 21 :00 - 00:00 3.00 CLEAN P CLEAN Safety Standdown held with night crew. The meeting was facilitated by both WSLs, both Toolpushers and RLG representatives. Also in attendance were two Halliburton reps. 12/10/2006 00:00 - 00:30 0.50 CLEAN P CLEAN Continue Safety Standdown. 00:30 - 01 :30 1.00 CLEAN P CLEAN Make up RBP Retrieving Tool Assembly per Halliburton reps. 01 :30 - 03:30 2.00 CLEAN P CLEAN TIH with RBP Retrieving Assembly on 3 1/2" DP from the Derrick. 03:30 - 06:00 2.50 CLEAN P CLEAN In with 92 Joints of DP. PU Joint #93 and MU Headpin. UW = 70K , DW = 70K. Break circulation at a rate of 4 bpm I 270 psi. Tag RBP @ 3,200' DPM. Stack 20K on it and come back up above it. Line up to reverse and close Annular. Reverse at a rate of 4 bpm I 330 psi and RIH on top of Fish Neck. Pressuring up as come down over Fish Neck - plugging off. Pick up off of Fish Neck and pressure relieves. Re-attempt with same results. Pump hi-vis sweep down DP to attempt to clean out any debris/junk. Reverse the sweep out and observe small amount of rubber and aluminum cuttings across the Shaker - nothing significant. Attempt to reverse down on RBP again and still pressuring up. 06:00 - 07:30 1.50 CLEAN P CLEAN PJSM. Release bridge plug, pump Hi Vis sweep, 5 bpm, 450 psi. 07:30 - 08:00 0.50 CLEAN P CLEAN Service rig, check PVTs, crown 0 matic, OK. 08:00 - 10:00 2.00 CLEAN P CLEAN PJSM. POOH wi 3 1/2" DP & Halliburton retrievable bridge plug, (reset (1) time & release to verify still on). 10:00 - 11 :00 1.00 CLEAN P CLEAN PJSM. UD Halliburton bridge plug & running tool. Recovered small piece of aluminum, small piece of brass shear pin & Printed: 12/1812006 11:26:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 12/1/2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 12/10/2006 10:00 - 11 :00 1.00 CLEAN P CLEAN medium size pieces of rubber. Clear 1 clean rig floor & prep to pick up next BHA. 11 :00 - 14:00 3.00 CLEAN P CLEAN PJSM. M/U 4 1/2" HES Fasdrill plug milling BHA. 14:00 - 16:30 2.50 CLEAN P CLEAN PJSM. RIH w/3 1/2" DP. 80 stands. 145K up wt, 120K down wt. Tag up @ 8116', 10' in on 1 st single after stand 80. Unable to shear bushing, set down 25K, no good. Kelly up. 16:30 - 17:30 1.00 CLEAN P CLEAN PJSM. Establish parameters. 124K down wt, 147K up wt. Freespin torque off bottom = 2500 ftIlbs. Set torque limit to stall @ 5500 ftIlbs. Rotate @ 5 RPM & slack off wi pumping 3 1/2 bpm /600 psi. Tag top of stub 10' in, may be some debris there, see bushing shear 12' in, OK. Run on down & pick up & break off kelly. 17:30 - 18:00 0.50 CLEAN P CLEAN PJSM. Single on in to Halliburton Fas drill @ 8194' (+ -). 18:00 - 20:00 2.00 CLEAN P CLEAN In with 242 Joints of DP. PU and MU Kelly. UW = 145K , DW = 125K. Break circulation at a rate of 3.5 bpm I 550 psi. Kick in Rotary Table at 25 RPM with 2,500 ft-Ibs of torque. RW = 135K. RIH and tag top of Fasdrill @ 8,178' DPM. Mill on Fasdrill Plug with 5K WOM. Once we drilled through it, it took 35 bbls to fill. Blow down and set back Kelly. RIH 5 more Joints of DP and stack 15K 6' in on Joint #248 = 8,334' DPM. That puts the Collars @ 8,117' (top of 4 1/2" Tubing). 20:00 - 20:30 0.50 CLEAN P CLEAN MU Headpin. Attempt to fill hole. It took 12 bbls to fill the DP -1,770 ft. Pumped a total of 86 bbls and shut down. Loss rate of 13 bbls 15 mins = 156 bph. 20:30 - 00:00 3.50 CLEAN P CLEAN Break off Headpin. TOH with BHA #12 laying down DP. Double displacing on the way out of the hole. 12/11/2006 00:00 - 03:00 3.00 CLEAN P CLEAN Continue TOH with BHA #12 laying down DP in the Pipe Shed. 03:00 - 05:00 2.00 CLEAN P CLEAN On surface with BHA #12. Break down and lay down components with Baker rep. 05:00 - 06:00 1.00 RUNCO RUNCMP Pull Wear Ring. Clear and clean Rig Floor. 06:00 - 06:30 0.50 RUNCO RUNCMP Rig service, check crown 0 matic, PVTS, OK. 06:30 - 08:30 2.00 RUNCO RUNCMP Rig up rig floor to run completion. 08:30 - 09:00 0.50 RUNCO RUNCMP PJSM regarding running completion string, all associated parties present. 09:00 - 18:00 9.00 RUNCMP M/U completion jewelry as per program. Baker lock all connections below the packer. RIH w/4 1/2" 12.6#, 13cr80, Yam Top completion, using Jet Lube Seal Guard & torque turning connections to 4440 ftIlbs. Constant hole fill while running in hole taking 125 bbls I hr (+ -). 18:00 - 00:00 RUNCMP Continue RIH with 41/2" Completion. Well is still taking about 125 bph. 12/12/2006 00:00 - 02:00 2.00 RUNCMP Continue RIH with 4 1/2" Completion. 02:00 - 04:00 2.00 RUNCMP In with 187 Joints of 41/2" Tubing. PU Joint #188. PUW = 106K , SOW = 95K. PU Joint #189 and RIH to shear and no-go. Shear brass pins with 8K at 32.40' in on Joint #189. Continue RIH to no-go. No-go on 36.20' in on Joint #189. PU and RIH to verify no-go depth - OK. Lay down Joint #189 and Joint #188. Space-out determined to need 5.40'. PU 5.75' Pup Joint. PU Joint #188. PU Landing Joint. PU and MU Tubing Hanger with Cameron reps. 04:00 - 04:30 0.50 RUNCO RUNCMP Land Tubing Hanger with Cameron reps. RILDS. 04:30 - 05:00 0.50 RUNCO P RUNCMP RU to reverse circulate. Pressure test lines to 3,500 psi. 05:00 - 07:30 2.50 RUNCO RUNCMP Reverse circulate 380 bbls of hot inhibited seawater into the Printed: 12/18/2006 11:26:59AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: M-15 M-15 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES 12/1 /2006 12/13/2006 Spud Date: 8/6/1981 End: 12/13/2006 Start: Rig Release: Rig Number: 07:30 - 12:30 12:30 - 13:30 13:30 - 15:30 15:30 - 18:00 18:00 - 22:30 22:30 - 23:00 23:00 - 00:00 12/1312006 00:00 - 00:30 00:30 - 01 :00 01 :00 - 04:00 04:00 - 06:00 1.00 BOPSU P 2.00 BOPSU P 2.50 WHSUR P 4.50 WHSUR P well. Pump at a rate of 3 bpm I 30 psi. Drop ball and rod down the Tubing. Continue pumping remaining 50 bbls of hot inhibited seawater down the IA. RUNCMP PJSM. Fill tubing to ensure all air is out. Pressure tubing to 3500 psi to set packer. Test tubing @ 3500 psi, 30 minutes, charted, good test. Bleed pressure on tubing to 1500 psi & pressure 9 5/8" x 4 1/2" annulus to 3500 psi, 30 minutes, charted, good test. Bled off tubing pressure, observed DCR valve shear, verified by pumping 2 bpm @ 250 psi thru DCR valve both ways, OK. RUNCMP Set and test TWC at 1000 psi from top and bottom. Good test. RUNCMP Nipple down BOP Stack. RUNCMP Nipple up Adaptor Flange and Tree. RUNCMP Continue NU 7" Production Tree. Had to change out studs and bolts due to not being long enough when Tree was delivered. Also had to install Blind Flange that was missing and change out the studs and bolts on it as well. Final make-up was inspected by WSL and Cameron rep - OK. Fill Tree with diesel to test. RUNCMP Pressure test the Tree to 5,000 psi with diesel - OK. Drain tree. RUNCMP PU and RU Lubricator with Drill Site Maintenance Techs. RUNCMP Pull TWC with Lubricator by Drillsite Maintenance Techs. RUNCMP Lay down and RD Lubricator. RU Little Red Hot Oil. RUNCMP PJSM with Little Red. Pressure test lines to 2,500 psi. Break circulation with diesel down the IA being pumped by Little Red. Pumped a total of 150 bbls of diesel at an average rate of 800 psi. Bleed down and RU jumper hose to allow freeze protect to U-tube for 1 hour. Bleed pressure off and monitor well - OK. RUNCMP Set BPV with Cameron representative. Test BPV with Little Red down the IA to 1,000 psi for 10 mins - charted. Bleed off pressure with Little Red. RD Little Red. Secure well and cellar. Released Rig at 06:00 hrs on 12/13/06. 0.50 WHSUR P 1.00 WHSUR P 0.50 WHSUR P 0.50 RUNCO 3.00 RUNCO Printed: 12/1812006 11 :26:59 AM ***CHROME 4-1 12" TBG & SCAB LNR'"h ÆRFORA TION SUMMARY REF LOG: CBL ON 08/27/81 ANGLE AT TOP ÆRF: 25 @ 9012' Note: Refer to Production 08 for historical perf data OPNISQZ DA IE o 07/03/91 S 06/18/91 S 06/18/91 4 S œH~1 4 S 06/18/91 PRUDHOE SAY UNIT WELL: M-15 PËRMIT No: 1810850 API No: SEC 22, 111 N, R14E, BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR AIIASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, Well name M-15 Sundry Number: 306-363 (Ç): he Dear Mr. Reem: Enclosed is the approved Application for SundlY Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thiS~ay of November, 2006 Encl. /"if' -0'8"5 1f \\\ 101~ ~~~!~~~~~~~~;s~~i~;~~~5~~ :;~~:~~; 20 MC 25 280Z¿3¿>f;=~, 'i" ,,¡ ,U)\ '. "\ -<. -'-'.' ;:-" ~.-.;- ~",:;-L~';¡;:;'>; '..:' , 1. Type of Request: 0 Abandon o Suspend o Operation Shutdown o Perforate o Time ExtenslQn o Alter Casing 1181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: ./ 5. Permit To D~Number BP Exploration (Alaska) Inc. ~ Development D Exploratory 181-085 3. Address: D Stratigraphic D Service 6. API Number: ~ P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20612-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU M-15 / Spacing Exception Required? DYes ~No 9. Property Designation: 110. KB Elevation (ft): 11. Field / Pool(s): ADL 028260 51.8' Prudhoe Bay Field / Prudhoe Bay Pool 1?, , « .. .. ,< )" ). <·i. '. ....... eie.;·i ·'''i))';ii).;ii' , <. ...... '" Total Depth MD (ft): Total Depth TVD (ft):IEffective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9657 9309 9460 / 9132 8194 None Casino Lenath Size MC < TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2665' 13-3/8" 2665' 2665' 4930 2670 Intermediate 8845' 9-5/8" 8845' 8577' 6870 4760 Production Liner 1308' 7" 8349' - 9657' 8136' - 9309' 7240 5410 Tieback Scab Liner 1258' 5" 8302' - 9560' 8095' - 9222' 10140 10490 Perforation Depth MD)fI): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9012' - 9050' 8728' - 8762' 4-1/2",12.6# x 5-1/2",17# 13Cr80 8305' Packers and SSSV Type: 9-5/8" x 4-1/2" Baker 'S-3' packer; I Packers and SSSV MD (ft): 8170'; / 9-5/8" x 5-1/2" TIW packer 8244' 13. Attachments: 14. Well Class after proposed work: ./ ~ Description Summary of Proposal D BOP Sketch o Exploratory ~ Development D Service D Detailed Operations Program "- 15. Estimated Date for December/o, 16. Well Status after proposed work: CommencinQ Operations: 006 ~Oil o Gas D Plugged o Abandoned 17. Verbal Approval: Date:Y DWAG OGINJ DWINJ o WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Frank Roach, 564-4373 Printed Nall}é\David Reem Title Drilling Engineer Prepared By NamelNumber: Signature ~¿p~ Phone 564-5743 Date flIT ¡Db Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: 301'n- -:2./_"'2-.. AV - ~ Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity æ'J"BOP Test D Mechanical Integrity Test D Location Clearance Other: Te~t þDPE 1-'0 ~S"OO pk . ¥fÿflt(~J . PwrçL(ØM..+ h 7AJ Mr-L '1<; .O~" l~~fHYtM-te ED Pt- , 1$ Subsequem Form Required: 10 - 4 m APPROVED BY / /-1f/-0-6 Approved By: T / "I COMMISSIONER THE COMMISSION Date Form 10-403 Revised 06/2006 V -~RIG1 Submit In Duplicate RBDMS 8Ft 1 5 2006 \' NAL . . M-15 Rig Workover Scope of Work: Pull 4-W' 13Cr-80 completion, cut and pull 9-5/8" casing above TOC, tie-back w/new 9- 5/8" cas&j'n, g ,eplace 9-5/8" emergency slips and primary pack-off, and run 4-}-2" 13Cr80 completion. ~ '3 T7 " \¡..J 4A-- MASP: psi Well Typ . 'roducer Estimated Start Date: December 10, 2006 Pre-Ri : o 1 S 2 E 3 F 4 o 5 Rhino Line cellar in re aration for RWO cellar will be utilized as second a containment. Pull PXN plug set at -8204' (set 12/15/2005). Drift thru 4-W' tubing for composite bridge plug / chemical cutter down to overshot set at -8225' (reference tubing summary dated OS/29/2000). DON E 10/30/06. Set composite b' ge pi at -8194' (reference tubing summary dated 5/29/00). Chem cut the 4-1/2" 13Cr-80 ' In the middle of the first full joint above the X nipple at -8127' (Reference tubin tall dated OS/29/2000 . Circulate well with seawater and FP w/ diesel through cut. CMIT TxlA to 3500 psi. Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka e check one at a time. PPPOT-Tb & IC. Bleed WHP's to 0 psi. Set a BPV. Remove the well house & flow line. Level the pad as needed for the ri . r" Proposed Procedure 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate ./ well to clean seawater through the cut. 2. Pull and LD 4-Ÿ2" tubing string to the cut. 3. RU wirelinæ"rUn US IT from packer to surface. /' 4. Run 9-5/8" B,Pand set at -1000'md below TOC determined from USIT. PT RBP to 1000 psi to prove up b ,rrier. Stack -50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 2nd full joint above TOC. Circulate out Arctic Pack. Pull casing thru / stack. Back-off 9-5/8" stub and pull same. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (FasDrill plug and RBP) to the reservoir. 6. Screw back in with new 9-5/8", 40#, L-80 casing and land on new emergency slip's with new primary / pack-off. PT 9-5/8" pack-off to 2500 psi. Cement new 9-5/8" casing to surface. 7. Run 4-Ÿ2" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -8030' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. / 10. Set BPV. NO BOPE. NU and test tree. RDMO. TREE = 6" CrN < WELLHEAD = McEVOY ACTUATOR = BAKER KB. ELEV = "51,76' BF. ELEV v.:' 26.46' KOP = 5700' Max Angle = 29 @ 8100' Datum MD = 9150' Datum lVD = 8800' SS . M-15 I S~OTE: CHROME TUBING. 2010' -14-1/2" HSEX LANDING NIP, 10 = 3.813" I 113-3/8" CSG, 72#, L-80, 10 = 12,347" I GAS LIFT MANDRELS ST MD lVD DEV TYÆ VLV LA TCH PORT DATE 6 3037 2986 o MMG DV RK 01/15/01 5 3905 3854 o MMG DOME RK 16 01/15/01 4 5680 5799 6 MMG DOME RK 16 01/15/01 3 6813 6695 21 MMG DV RK 05/00 2 7203 7044 21 MMG DOME RK 16 01/15/01 1 8088 7851 29 MMG SO RK 24 01/15/01 ITBG PUNCH (11/04/06) I 8159' -14-1/2" HES X NIP, 10 = 3,813" I Minimum ID = 3.725" @ 8225' 4-1/2" XN NIPPLE 14-1/2" HES FASDRILL PLUG (11/04/06) j 9-5/8" X 4-1/2" BKR S-3 PKR, 10 = 3.875" -14-1/2" XN NIP, 10 = 3.725" I 14-1/2" TBG, 12,6#, 13-CR-SO, ,0152 bpf, 10 = 3,958" I 15-1/2" TUBING STUB I 8224' -15-1/2" X 4-1/2" XO I 8226' -15-1/2" CUSTOM TBG OVERSHOT I 8244' -19-5/8" X 5-1/2" TrN PKR I 8269' -15-1/2" OTIS X NIP, 10 = 4.562" I 8285' -15-1/2" OTIS XN NIP, 10 = 4.455" I 8305' 15-1/2" TBG, 17#, 13-CR-SO, .0232 bpf, 10 = 4,892" I TOPOF 7" LNR I 19-5/8" CSG, 47#, L-80, 10 = 8.681" I ÆRFORA TION SUMMARY REF LOG: CBL ON 08/27/81 ANGLEATTOPÆRF: 25 @ 9012' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL OPNISQZ DA TE 3-3/8" 0,6 9012 - 9050 0 07/03/91 2-7/8" 4 9048 - 9086 S 06/18/91 2-7/8" 4 9100 - 9157 S 06/18/91 2-7/8" 4 9166 - 9198 S 06/18/91 2-7/8" 4 9220 - 9250 S 06/18/91 5" SCAB LNR, 18#, NT-13-CR·SO, ,0188 bpf, 10 = 4.276" DATE OS/S1 06/30191 05129100 11/04/01 12/15/05 10/30/06 REV BY COMMENTS ORIGINAL COMPLETION RIG WORKOVER RIG WORKOVER RN/TLP CORRECTIONS TWS/PJC SET PXN PLUG @ 8204' CJN/PAG PULL PXN PLUG @ 8204' DA TE REV BY COMMENTS 11/04/06 RLM/TLH TBG PUNCH & FASDRILL PRUDHOE BA Y UNrT WELL: M-15 ÆRMrT No: 1810850 API No: 50-029-20612-00 SEC 22, T11N, R14E, 606' WEL & 1716' SNL BP Exploration (Alaska) GAS LFT MANDR8.S ST MD TYPE VLV 4 3650 4-1/2" 1-1/2" 3 5701 4-1/2" 1-1/2" 2 7087 4-1/2" 1-1/2" 1 7649 4-1/2" 1-1/2" TREE;¡' VV8...LHEAD = ACTUA TOR ;; KB. 8.Ë\I = BF. 8.EV = KOP= Max Angle = Datum MD = Datum lVD = 6"CW McEVOY BAKER 51.76' 26.46' 5700' 29 @ 8100' 9150' 8800'55 M-15 Proposed I 9-5/8" eSG, 40#, L-80, ID = 8.835" I 113-3/8" CSG, 72#, L-80, ID = 12.347" I 14-112" TBG, 12,6#, 13-CR-80, .0152 bpf, ID = 3.958" I Minimum ID = 3.725" @ 8225' 4-1/2" XN NIPPLE 8170' 14-112" TBG, 12.6#, 13-CR-SO, .0152 bpf, ID = 3.958" I 15-112" TUBING STUB I 8204' 8224' 8226' 8244' 8269' 8285' I TOP OF 5" LNR I 8305' 15-112" TBG, 17#, 13-CR-SO, .0232 bpf, ID = 4.892" I TOP OF 7" LNR I 19-518" CSG, 47#, L-80, ID = 8.681" I PERFORA TKJN SU~RY REF LOG: CBL ON 08/27181 ANGLE AT TOP PERF: 25 @ 9012' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OPNIsaz DATE 3-318" 0.6 9012 - 9050 0 07103191 2-718" 4 9048 - 9086 5 06118191 2-718" 4 9100 - 9157 5 06118/91 2-718" 4 9166 - 9198 5 06118191 2-718" 4 9220 - 9250 5 06118191 5" SCAB LNR, 18#, NT-13-CR-SO, .0188 bpf, ID = 4.276" DATE OS1S1 06130191 05129100 11104101 12115105 10130106 REV BY COt-INENTS ORIGINAL COMPLETION RIG WORKOVER RIG WORKOVER RNlTLP CORRECTKJNS TWSIPJC SET PXN PlUG @ 8204' CJNlPAG PULL PXN PlUG @ 8204' DATE 11/03/06 REV BY FVR CO~S RWO PROPOSA L ~~.__ c.~~~ --~~:'''''.'-''':'/''' / -14-1/2" HSEX LANDING NIP,ID= 3,813" -1 UNIQUE MA CHINE OVERSHOT -14-112" HES X NIP, ID = 3.813" I ~9-5/8" X 4-112" BKR 5-3 PKR, ID = 3.875" -15-1/2" CUSTOMTBG OVERSHOT I -19-518" X 5-1/2" TW PKR I -15-112" OTIS X NIP, ID = 4.562" I -15-112" OTIS XN NIP, ID = 4.455" I -15-112" DUt./NY SEAL I PRUDHOE BAY UNIT \NELL: M-15 PERMIT No: '1810850 API No: 50-029-20612-00 SEC 22, T11 N, R14E, 606' \NEL & 1716' SNL BP exploration (Alaska) RECEIVED ) STATE OF ALASKA ') ALASKA OIL AND GAS CONSERVATION COMMI~SION ..IAN 2 4 2006 REPORT OF SUNDRY WELL OPERATIONSAlaska Oil!lJ Gas Cons . .. 1. Operations Abandon D Repair Well D Plug Perforations 0 Stimulate D Other 0 · COnlltdllWø Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension a"charaQI Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ß?,' Exploratory [] 181-0850 3. Address: P.O. Box 196612 Stratigraphic [:1 Service D' 6. API Number: Anchorage, AK 99519-6612 50-029-20612-00-00 7. KB Elevation (ft): 9. Well Name and Number: ," 51.8 KB 8. Property Designation: ADL-028260 11. Present Well Condition Summary: Total Depth measured 9639 true vertical 9293.19 Effective Depth measured 9460 true vertical 9131.91 Casing Conductor Surface Production Liner Scab Liner Length 80 2636 8817 1308 Size 20" x 30" 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 26# L-80 5" 18# NT13CR80 1238 Perforation depth: Measured depth: 9012 - 9050 True Vertical depth: 8727.52 - 8761.87 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 388 x M-15 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool feet feet Plugs (measured) Junk (measured) 8204 PXN None feet feet MD 30 - 110 29 - 2665 28 - 8845 8349 - 9657 8302 - 9540 TVD Burst Collapse 30 - 110 29 - 2664.94 4930 2670 28 - 8577.1 6870 4760 8136 - 9309.4 7240 5410 8094.7 - 9204 10140 10490 Closed Closed 5-1/2" 17# 4-112" 12.6# 13CR80 13CR80 8224 - 8305 26 - 8224 4-1/2" Baker S-3 Perm Packer 5-1/2" TIW Packer 8170 8244 , ,~~~tr'," J (\,N 9- ~. 2D(JÖ SçI\N\\~~~,þ ,11'1 r" I,~I RBDMS 8Ft .JAN .25 2006 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 1403 3410 80 SHUT-IN 15. Well Class after proposed work: Exploratory r Development .r;{ 16. Well Status after proposed work: Oil r;¡ Gas r WAG r Tubing pressure 200 Service r WDSPL r GINJ r WINJ r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal Printed Name Sharmaine Vestal ~ . r, Signat~~ ~..iltt Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Phone 564-4424 Date 1/20/2006 Form 10-404 Revised 04/2004 0 R ¡ G ¡ N A L Submit Original Only ) ) , . M-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY I ACTIVITYDATE I SUMMARY 12/15/2005 *** WELL SI ON ARRIVAL *** (secure well) DRIFTED W/4 1/2" BLB & 3.70 G-RING, BRUSHED XN NIP @ 8187' SLM *** JOB IN PROGRESSI CO NT ON 12-16-05 WSR*** 12/16/2005 *** CONT FROM 12-15-05 WSR *** SET 4 1/2" PXN PLUG BODY & PRONG @ 8187' SLM ( PLUG BODY 26" OAL WI (4) 3/8" PORTS) RAN 4 1/2" CK SET ( GOOD SET), SET PRONG 95" OAL WI 1.75 F.N, HAS 2.75 CENT 3" BELOW F.N. BLED TBG FROM 1120# TO 740#, PLUG HOLDING. RDMO NOTE: PLUG BODY HAS (4)- 3/8" PORTS "USE CAUTION WHEN PULLING PRONG" *** PAD OP NOTIFIED, WELL SECURE *** FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL STATE OF ALASKA ALASKA( .,_ AND GAS CONSERVATION COMI~ REPORT OF SUNDRY WELL OPERATIONS SION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 51.80' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Prudhoe Bay Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number : ................... ~ ........ h~, M-15 1716'SNL, 606'WEL, SEC. 01,T11N, R12E, UM .'-'"': ,~ "r~..~..~';~.:.~',.,.[ ~ At top of productive interval ~,,'":"i; '~ ...... ' · ' ". ..... ~, 9. Permit Number / Approval No. ~, ~,,. ':,,.., , ...... ~; ..;. ,.., .,,~,., ..~, 181-085 466' SNL, 948' WEL, SEC. 01, T11N, R12E, UM 10. APl Number : '"' 20 %' At effective depth '.~ ~ £UvlJ 50-029-20612-00 193' SNL, 1030' WEL, SEC. 01, T11N, R12E, UM 11. Field and Pool ......... ,~ :'"~;! .~i,. ~S~":"~' ';'~"~"':~. ~' '~ "~ ,,.,.L At total depth ..,.~.,:.'~;,~,,c. ,...:. .... ~;'~' "-~"~ ...... Prudhoe Bay Field / Prudhoe Bay "4, ,~', i',' ,,~,1'," 234' SNL, 1018' WEL, SEC. 01, T11N, R12E, UM,'"~' ~. ,~.'.,l~i!,'~'~,...,..,,.: Pool 12. Present well condition summary Total depth: measured 9657 feet Plugs (measured) true vertical 9309 feet ORIGINAL Effective depth: measured 9560 feet Junk (measured) true vertical 9222 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" x 30" 8 cu yds concrete 110' 110' Surface 2639' 13-3/8" 3720 cuff Permafrost II 2665' 2665' Intermediate 8819' 9-5/8" 1202 cuft Class 'G', 130 cuft PF 'C' 8845' 8577' Production Liner 1311' 7" 396 cuft Class 'G' 8349' - 9657' 8136' - 8996' Tieback Liner (Scab) 1258' 5" 230 cu ft Class 'G' 8303' - 9560' 8096' - 9222' Perforation depth: measured Open: 9012' - 9050'; Sqzd: 9050'-9250' (four intervals) true vertical Open: 8728' - 8762'; Sqzd: 8762' - 8943' (four intervals) Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr80 to 8233'; 5-1/2", L-80 from 8225' - 8327' Packers and SSSV (type and measured depth) 4-1/2" HES 'X' nipple at 2010'; Baker 'SABL-3' packer at 8170'; 9-5/8" TIW packer at 8244' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or Iniection D~ta OiI-Bbl ~ias-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: I"1 Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas r"l Suspended Service _ 17. I hereby certify that the fore)going is tract to the best of my knowledge Si!;Ined Terrie Hubble ~'~_~j~_~J_~" ~ Title Technical Assistant III Date 0~' ~'-(~' (~ Prepared By Name/Number: Terrie Hubble, 564-4628 Form 10-404 Rev. 06/15/88 Submit In Duplicate Facility PB M Pad Duration 6-1/2 hr 6-1/2 hr Date/Time 27 May 00 12:00-18:30 12:00-18:30 7hr 1-1/2 hr 18:30 18:30-01:30 18:30-20:00 20:00 2hr 20:00-22:00 22:00 22:00-22:30 22:30 22:30-01:00 28 May 00 01:00 2-1/2 hr 01:00-01:30 01:30 01:30-03:00 01:30-03:00 03:00 03:00-06:00 03:00-04:30 04:30 04:30-06:00 1-1/2 hr 1-1/2 hr 3hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr lhr 1 hr 06:00-07:30 06:00-07:30 07:30 13hr lhr 07:30-08:30 07:30-08:30 08:30 08:30-21:30 08:30-09:30 09:30 Progress Report 09:30-10:30 10:30 10:30-12:00 1 hr 1-1/2 hr Well M-15 Page 1 Rig Nabors 9ES Date 20 June 00 Activity Move rig Rig moved 100.00 % At well location - Slot Level Pad around M-15 RWO. Lay mats and herculite. Spot rig, pits and camp. Berm rig. Hook up electrical system/lines. Rig Accepted @ 1630 hfs 27th May 2000. ( 2 hours to level M-15 ) Wellhead work Rigged up Kill manifold Equipment work completed N/II secondary annulus valve and kill manifold. Take on seawater. Retrieved Hanger plug Equipment work completed R/U DSM and pull BPV. Pressures = zero. R/D DSM. Test lines to manilfold/tree to 3500 psi. Held safety meeting Completed operations Hold Pre-spud meeting and evacuation drill. Circulated at 8219.0 ft Obtained bottoms up (100% annulus volume) Displace diesel from well and circulate bottoms up thru choke. Installed Hanger plug Equipment work completed Install TWC and test to 500 psi f/below. Wellhead work Rigged down Xmas tree Equipment work completed BOP/riser operations - BOP stack Installed BOP stack Equipment work completed Tested BOP stack R/U and test BOPE to 300 psi/3500 psi. BOP/riser operations - BOP stack (cont...) Tested BOP stack Pressure test completed successfully - 3500.000 psi Test BOPE to 250 psi/3000 psi. AOGCC waived witness of test. R/D Test equipment. Wellhead work Retrieved Hanger plug Equipment work completed PJU DSM and pull TWC. Flowcheck. Pull Gas lift completion, 5-1/2in O.D. Retrieved Hanger assembly Completed operations Screw into hanger and pull completion free- no ove~pull. String weight @ 170 Ubs. L/D hanger and Landing joint. Flowcheek. Rigged up Completion string handling equipment Equipment work completed Laid down 2000.0 ft of Tubing JUN 20 Oi~ & G~,, Cons, ,~ :.[) ..... Progress Report Facility PB M Pad Well M-15 Page 2 Rig Nabors 9ES Date 20 June 00 Date/Time 12:00 12:00-14:00 14:00 14:00-20:30 20:30 20:30-21:30 21:30 21:30-00:00 21:30-00:00 29 May 00 00:00 00:00-02:30 00:00-02:30 02:30 02:30-06:00 02:30-06:00 06:00-06:30 06:00-06:30 06:30 06:30-08:30 06:30-08:30 08:30 08:30-10:30 08:30-10:30 10:30 10:30-23:30 10:30-13:30 13:30 13:30-13:45 13:45 13:45-15:00 15:00 Duration 2 hr 6-1/2 hr 1 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 2 hr 2 hr 2hr 2hr 13hr 3hr 1-1/4 hr Activity Stopped- At sub-assembly Lay down 50 joints 5.1/2", Chrome tubing- in good shape. Retrieved SCSSSV nipple assembly Completed operations L/D SSSV, 5 stainless steeel bands and 26 rubber clamps.Clear rigfloor of Camco equipment. Laid down 8219.0 ft of Tubing Completed operations Continue to POOH and L/D 205 joints 5.1/2" Tubing ( total), 5 x GLM and 1 x cut off = 2.34 ft. Stub left = 7.72 ft. Rigged down Completion string handling equipment Equipment work completed BHA run no. 1 Made up BHA no. 1 BI-IA no. 1 made up M/U unique overshot and soaper assembly and hangoff on RTTS 23 ft below tubing spool. Test RTrs to 1000 psi. BOP/riser operations - BOP stack Rigged down BOP stack Equipment work completed Nipple down BOP and Tubing Spool. Stand back BOP. Wellhead work Installed Tubing head spool Preapre 9.5/8" casing stub and remove damaged cap screws rom compression ring. Install New tubing spool and YB seal. Wellhead work (cont...) Tested Tubing head spool Pressure test completed successfully - 3500.000 psi Test packoff to 3500 psi- good. BOP/riser operations - BOP stack Installed BOP stack Equipment work completed Nipple up BOP and test all flanges to 3000 psi against RTTS- good. Perform integrity test Tested Casing Pressure test completed successfully - 3000.000 psi Release RTTS. Test wellbore to 300/3000 psi. 7.5 bbls pumped/returned. Recover RTTS and L/O BHA run no. 1 ~"~:~ ,.~....t., R.I.H. to 8100.0 ft Began precautionary measures RIH on 4" drillpipe. ~.iUN Washed to 8219.0 ft ,~ e ~,~'~,,~ , ",d~' ,~ At Top of fish' 8219.0 ft ..... !~',~:~ Wash down and observe top of tubing stub w/ pressure increase and no go. Repeat to confirm depths. Circulated at 8219.0 ft Obtained bottoms up (100% annulus volume) Sweep hole clean @ 12 BPIVI/1130 psi while working ,0 Facility PB M Pad Date/Time 15:00-21:00 21:00 21:00-23:30 23:30 Duration 6 hr 23:30-06:00 23:30-00:00 30 May O0 00:00 00:00-00:30 00:30 00:30-06:00 2-1/2 hr 06:00-06:00 06:00-11:30 11:30 11:30-12:00 12:00 6-1/2 hr 1/2 hr 1/2 hr 5-1/2 hr 24 hr 5-1/2 hr 12:00-14:00 14:00 14:00-18:00 18:00 2hr 18:00-20:00 20:00 4hr 20:00-21:30 21:30 2 hr 21:30-04:30 31 May O0 04:30 1-1/2 hr 7 hr Progress Report Well M-15 Page 3 Rig Nabors 9ES Date 20 June 00 Activity Laid down 8219.0 ft of 4in OD drill pipe At BHA POOH laying down 4" drillpipe. Leave 3000 ft in pipe shed for rig move. Pulled BHA BHA Laid out Lay down BHA. Inspect overshot- OK. Pull wear ring and clear rigfloor. Run Gas lift completion, 4-1/2in O.D. Rigged up Completion string handling equipment Equipment work completed Held safety meeting Completed operations Ran Tubing to 3200.0 ft (4-1/2in OD) M/U tailpipe assembly. Run 4.1/2", 12.6 lb/ft Chrome completion. 65 joints out of 188 run @ report time. 15 joints/hr. Run Gas lift completion, 4-1/2in O.D. (cont...) Ran Tubing to 8200.0 ft (4-1/2in OD) Began precautionary measures RIh w/4.1/2" Chrome completion @ 20jts/hr. Washed to 8239.0 ft Completed precautionary measures Wash down and observe 50 psi pressure increase 15 ft deeper than pipe tally. Shut pumps off and s/o 3 ft- unable to go futher without light washing ( 1.7 bpm/100 psi). Observe the 5 ft to no go. Repeat with process to confirm tag.. Space out tubulars Completed operations Pull back and pace out tubulars picking up 4 x Pup joints. Remeasure pups and re-drift. Make up hanger. Reverse circulated at 8234.0 ft Hole displaced with Inhibited brine - 100.00 % displaced Reverse circulate @ 3 BPM 565 bbls clean seawater including 345 bbls of inhibited seawater. Ran Tubing on landing string to 8234.0 ft Observed 15.00 klb resistance Attempt to land hanger- stacking weight 2 ff from being landed out. Repeat without pumps several times and rotate string 180 degs- no go. Lightly wash down and land hanger. ( Concern that we need 12" downward movement to set packer) Removed Tubing hanger Equipment work completed Pull back and laydown hanger- seal damaged in vicinity of loekdowns, make up landing string and tag "fill" on depth. Pull Back and wait on fluids. Reverse circulated at 8234.0 ft Hole displaced with Inhibited brine - 200.00 % displaced Reverse Circulate and sweep hole w/40 bbls hi vis @ 4.5 BPM/800 psi working overshot down to no go ,JUN 2 0~1 ,,;~ Gas Col 2000 Facility Date/Time 01 Jun 00 Progress Report PB M Pad Well M-15 Page 4 Rig Nabors 9ES Date 20 June 00 04:30-06:00 06:00-08:30 06:00-06:30 06:30 06:30-08:30 08:30 08:30-15:30 08:30-15:30 15:30 15:30-18:00 15:30-16:30 16:30 16:30-18:00 18:00 18:00-18:30 18:00-18:30 18:30 18:30-21:00 18:30-21:00 21:00 21:00-01:30 21:00-00:30 00:30 00:30-01:30 01:30 01:30-04:00 01:30-04:00 04:00 04:00-06:00 Duration 1-1/2 hr 2-1/2 hr 1/2hr 2hr 7hr 7hr 2-1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 2-1/2 hr 4-1/2 hr 3-1/2 hr lhr 2-1/2 hr 2-1/2 hr 2hr Activity no go-good. Inhibit well. Installed Tubing hanger Dry tag down to no go- OK. repeat after 15 minutes- OK. POOH and prepare to PFLI hanger and land same. Run Gas lift completion, 4-1/2in O.D. (cont...) Tested Tubing hanger Pressure test completed successfully - 1000.000 psi Test tubing hanger from above- good. Tested Permanent packer Suspended test, observed returns from wellbore Drop Ball and rod- attempt to set packer- no go circulating well @ 50 spnd 240 psi. Troubleshoot- attempt to revseres- still no progress to get ball seated. Slickline wireline work Conducted slickline operations on Slickline equipment - Setting mn Completed mn with Gas lift mandrel assembly from 0.0 ft to 3037.0 R/U Slickline and stuffing box/BOP's. RIH and engage Ball on seat @ 8,187'. Pressure- no go. POOH. Replace top RP valve ( RP had sheared). R/D Slickline. Run Gas lift completion, 4-1/2in O.D. Set packer at 8170.0 ft with 3000.0 psi Packer set at 8170.0 ft Drop ball and rod. Pressure up to 3000 psi and set packer. With annulus open leak of 400 psi/30 minutes. Verify below wellhead. 2.4 bbls pumped. Tested Permanent packer - Via annulus Pressure test completed successfully - 3000.000 psi Bleed tubing to 1500 psi. Pressure annulus to 3000 psi. 5.2 bbls. Hold pressure for 50 minutes( no Loss) while verifying forward plan. Shear RP valve. Wellhead work Installed Hanger plug Equipment work completed Install TWC. Test from below to 500 psi, from above to 1000 psi. BOP/riser operations - BOP stack Rigged down BOP stack Equipment work completed Change bottom Rams to 2.3/8" x 5". N/D BOP and secure same on pedestal. Wellhead work Installed Xmas tree Equipment work completed - Install Tree and test same to 5000 psi- good. Retrieved Hanger plug Equipment work completed RFLI DSM and pull TWC. Fluid system Freeze protect well - 150.000 bbl of Diesel Completed operations R/U kill manifold and freeze protect well with HB&R. Allow to U-tube. Wellhead work JUN 20 20¢ Alaska 0~i Anchor .~.e ) Facility PB M Pad Progress Report Well M-15 Page 5 Rig Nabors 9ES Date 20 June 00 Date/Time 04:00-06:00 06:00 Duration 2 hr Activity Rigged down HCR valve Equipment work completed Blow down lines and R/D Same. N/D secondary valve and secure tree. Rig Released to WB-07 @ 0600 hrs on 1 st June 2000 JUN 20 2000 ~a~ka Oi~ a Gas Con,:,. "",,, ' ' LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 24 April 1995 RE: Transmittal of Data Sent by= PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL X-07 (43-08-10-14) DESCRIPTION PLS/STATIC FNL BL+RF CN/GR FINAL BL+RF CN/GR FINAL BL+RF PLS FINAL BL+RF PLS/STATIC FNL BL+RF ECC No. Run # i 4046.05 Run ~ 1 Run # I Run $ 1 R~,.n...,# ....... 1 5694.04 5751.05 57'58.02 6035.03 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Please stun and x~e~ut'Ix ~ petroteehnioaL' Data Cente~." BP Explor~tion (Klaska) Ino 900 EaSt Benson Boulevar~ ~ohor~, ~ask~ 99508 AJaska Oil & Gas Cons. CommissiOn Anchorage LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 April 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below= WELL 8',5 - 51 85 .-",, DESCRIPTION i PiS FINAL BL+RF i PLS FINAL BL+RF I PLS FINAL BL+RF i PLS FINAL BL+RF 1 PLS FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run ~ i 2385.02 Run # i 4880.O5 Run ~ i 5643.O3 Run ~ i 5758.O1 'Run ~ i 5797.O1 Run ~ i 6105.O3 Please sign and return to= Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Received by: Date: Please sign and return Petroteehnieal Data Cente~ R E C E IV E D BP Exploration (Alaska) In~ 900 East Benson Boulevard Anchor_age, Alasim. 99,~0~ APR 2 0 1995 ]~eeelved bit " - BP EXPLORATION RECEIVED BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 11/16/92 T# 84059 BP LOGS Endlosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-12 j..!l~ PRODUCTION LOG 11/07/92 ~1/' 8750.00- 9250.00 ATLAS 5 " A-18~l-fo8 CCL(~e~ ¢~~1/10/92 #1v~ 8100.00- 9270.00 ATLAS 5 " B-21~Z-I~ PFC/~(~4~F) 11/_Q9/92 ~1-' 9400.00- 9824.00 ATLAS 5 " M-15~I-~J~CCL (P~,~/~,~4~/~f~8/92 #1~ 8500.00- 9330.00 ~TLAS 5 " R-297~-L/./ PFC/~ (~) 11/10/92 9lv/ 10140.00-10320.00 ATLAS 5 " R-30~/~ PRODUCTION LOG .,11/08/92 91 v/ 11100.00-11550.00 ATLAS 5 " ........... (~$]11/11/92 #1~/ 9620 00- 9720 00 ATLAS 5 " Information Control Well Records ' " STATE OF ALASKA ," ,- __ .~..iA OIL AND GAS CONSERVATION COMMI~ .N 0 ~ I '~ REPOR OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. Stimulate X Plugging Perforate X Alter casing Repair well Other 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1716'$NL, 606' WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 466' SNL, 573' WEL, SEC. 01, T11N, R12E, UPM At effective depth 4261SNL, 234'WEL, SEC. 01, T11N, R12E, UMI At total depth 193' SNL, 491' WEL, SEC. 01, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical 9657feet BKB 9309feet 5. Type of Well: Development X Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE-- 51.76 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-15 (21-06-11-13) PBU 9. Permit number/approval number 81-85/ 10. APl number 50- 029-20612 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured true vertical 9560feet Junk (measured) BKB 9170feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 110 2639 8819 1311 measured Size Cemented Measured depth 20x30 8 c.y. 136 13 3/8 3720 c.f. 2665 9 5/8 1332 c.f. 8845 7 396 c.f. 8346-9657 9012'-9032', 9048'-9086', 9100'-9151', 9166'-9198', 9220'-9250' True vertical depth BKB 136 2665 8577 8133-9309 true vertical subsea 8676'-8891' (five intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8302' with 5 1/2" tailpipe to 8327' Packers and SSSV (type and measured depth) 9 5/8" TlWpacker at 8302'; 5 1/2" SSSV at 2012' 13. Stimulation or cement squeeze summary See Attachment 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Subsequent to operation SEP 2' ,5 1992 Alaska 0il & Gas Cons. Commission Re0resentative Daily Average Production or In!action Data OiI-Bbl /'Gas-Md Water-Bbl Casing Pressure 2690 ..../ 5916 45530 12510 5760 / 5284 1092 0 Tubing Pressure 300 2273 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 hereb, b~y c~,,y tha~'~/.~ fore~j.l~, is true.~~o, the best of my knowledge. Signed ~/(~;)-/~[~-/-4'3 ~.7/---' Title Senior TechnicalAssistant Form 10-404 Rev 06/15/88 r SUBMIT IN DIJPLIC/ATE WELLM-1 5(21 -06-1 1-13)PBU NRWO/Reperf/HydraulicFracturinaO_~erations 6/08/91 7/03/91 7/06/91 A NRWO was performed using the fluids: Batch #1 4 3 6 bbls 2 0 bbls 2 3 bbls 5 4 bbls 6 3 bbls 5 bbls 3 5 bbls 1 0 bbls 234 bbls Batch #2 5 bbls 2 2 bbls 1 0 bbls 4 3 bbls PW to load well ACID PW ACID PW EW(Preflush) Cement EW(Spacer) PW 7 1 bbls PW EW(Preflush) Cement EW(Spacer) PW 148 bbls PW(Reverse Out) Well Cleaned Out to 8410' 712 bbls load fluid behind pipe ACID: 15% HCL W/ .5% LS-300, .3% HAl-85 CEMENT: 15% PPG Class G Cement Containing, ,2% CFR-3,.12% HR-12, .16 GAL/SK HALAD-344L The following interval were reperforated using 3 3/8" gun diameter, 6 SPF random orientation and 60 degree phasing. 901 2' 9O5O' MD Performed hydraulic fracture using the fluids: Total of 186,000# 16/20 Carbolite Pumped 183100# behind pipe of which 2900# sand left in casing. Fluids Pumped: 30 262 205 60 50 837 bbl SW 6 0 bbl 15% HCL bbl 20# Gel 30 bbl 50# Gel bbl 50# Gel X-linked 198 bbl 20# Gel bblacid 725 bblSW bbl 50# Gel 241 bbl 50# Gel X-linked bbl 50# Gel X-linked 198 bbl 10# Gel fjh 9/14/92 Alaska 0it & Gas Cons. AnChOrage A ~,KA OIL AND GAS CONSERVATION COMMI ,oN ,~.'~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing X Alter casing Repair well Other 2. Name of Operator ~ 5. Type of Well: 6. Datum elevation (DF or KB) . BP Exploration I Development X KBE = 51.76 AMSL feet Exploratory 3. Address Strafigraphic 7. Unit or Property name P. O. Box 196612, Anchorage, Alaska 99519-6612 seneca Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1716'SNL, 606'WEL, SEC. 01, T11N, R12E, UPM M-15 (21-06-11-13)PBU At top of productive interval 9. Permit number/approval number 466'SN1., 573' WEL, SEC. 01, T11N, R12E, UPM 81-85 At effective depth 10. APl number 211' SNL, 496' WEL, SEC. 01, T11N, R12E, UPM 50- 029-20612 At total depth 11. Field/Pool 193' SNL, 491' WEL, SEC. 01, T11N, R12E, UPM Prudhoe Oil Pool 12. Present well condition summary Total depth: measured 9657 feet Plugs (measured) true vertical 9309 feet BKB Effective depth: measured 9560 feet Junk (measured) true vertical 9222 feet BKB Casing Length Size Cemented Measured depth True vertical depth Structural ............ BKB Conductor 110' 20"x30" 8 cu. yds. 136' 136' Surface 2639' 13-3/8" 3720 cu. ft. 2665' 2665' Intermediate 8819' 9-5/8" 1332 cu. ft. 8845' 8577' Production 1311 7" 396 cu. ft. 8346'-9657' 9309' Liner 1258 5" 230 cu. ft. 8303'-9560' 8022'-9214' Perforation depth: measured 9012'- 9250' (five intervals) true vertical 8675'- 8890' Tubing (size, grade, and measured depth) 5-1/2"L-80 to 8300' with tailpipe to 8327' Packers and SSSV (type and measured depth) 9-5/8" TIW packer at8244'; 5-1/2" SSS V at 2003' RECEIVED 13. Stimulation or cement squeeze summary FEB - 6 992 Intervals treated (measured) Alaska 0ii & Gas Cons. C0mmissl Anchorage Treatment description including volumes used and final pressure 14. Reoresentative Daily Averaqe Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended Service 17. I hereby cert~ that the foregoing is true and correct to the best of my knowledge. Signed ~ ~` ~c.~.~~~ TRIo Senior TechnicalAssistant Date,=~/ Form 10T4~)4 Rev 06/15/88 SUBMIT IN DUPLICATE BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday. June 17. 1991 WELL: M-15 (21-06-11-13) PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: ~ 3 Expense AFE Number: Expense AFE Amount -- , 14506t~ Current Field Costs = Estimated Final Cost = Current Operation: Summary_' of Last 72 Hours Accept rig 1530 hours 6-15-91. Circulate diesel from well. ND tree. NU & test BOP to 5000 psi. Unable to pull tubing. Recut tubing. Circulate well. Pull 5-1/2" tubing. RIH to fish stub. Hang off on storm packer. ND BOP and tubing spool..Replacing 9-5/8" packoff. RECEIVED FEB - 6 t992 Alaska 0il & ,Sas Cons. Reviewed By: , d~,~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday. June 18. 1991 - WELL: M-15 (21-06-11-13). PRUDHOE BAY UNIT Rig: Nab0rs Rig #3-S Day: 4 Expense AFE Number: Expense AFE Amount = 145O66 Current Field Costs = Estimated Final Cost = Current Operation: Circulating detergent and diesel sweep. Summary of Last 24 Hours Replace packoff. NU & test BOP. Recover storm packer. Circulate. Recover cutoff and latch. RIH to mill packer. Circulate. Reviewed By:/~' BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDHOE BAY UNIT As of 0600 Hrs. Wednesday. June 19. 1991 WELL: M-15 (21-06-11-1~') Rig: Nab0r$ Rig #3-S Day: .5. Expense AFE Number: . Expense AFE Amount -- 145O66 Current Field Costs = Estimated Final Cost = Current OperatiQn' RIH w/6" bit. Summary of Last 24 Hours Mill & recover packer tailpipe assembly. RIH with 6" bit to clean out liner. BP EXPLORATION (ALASKA), INC. DALLY WORKOVER REPORT: As of 0600 Hrs. Thursday. June 20. 1991 WELL: .M-15 (21-06-11-13) PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: 6 Expense AFE Number: Expense AFE Amount = 145066 Current Field Costs = Estimated Final Cost = Current Operation: Cleaning out liner. Summary_ of Last 24Hours RIH 6" bit cleaning out cement at 9260'. Reviewed By' ~,~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Fdde, y. June 21. 1991 WELL: M-I$ (21-06-11-13~ PRUDHOE BAY UNIT Rig: Nabors Ria #3-S -- Day: 7 Expense AFE Number: Expense AFE Amount -- 145066 Current Field Costs = Estimated Final Cost = Current Ooeration' Running 5" concentric liner. Summary of Last 24 Hours Clean out liner to 9560'. Reverse circulate. Running 5" 13 Cr liner. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Monday. June 24. 1991 WELL: M-15 (2Z-06-Z1-1~), PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: Expense AFE Number: Expense AFE Amount = 145066' Current Field Costs = Estimated Final Cost = Current Ooeration: Cleaning cement from liner. Summary of Last 72 Hours Ran and cemented 5" liner. Unable to release from hanger, POH. Lost liner at 1960'. RIH. Fished and recovered liner. RIH. Cleaning out cement to 9484'. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Tuesday. June 2,5. 1991 WELL: M-I$ (21-06-11-13) PRUDHOE BAY UNIT Rig: Nabors Rig #3-$ Day: .11 Expense AFE Number: Expense AFE Amount = 145066 Current Field Costs = Estimated Final Cost = Current Operation: Running 5" concentric liner. Summary_ of Last 24 Hours Clean out cement to 9560'. Ran 7" casing scraper. Running 5" 18# liner. Reviewed By: ~:~J BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: PRUDItOE BAY UNIT As of 0600 Hrs. Wednesday. June 26. 1991 WELL: M-I~ (21-06-11-13~ Rig: Nabor8 Rig #3-S Day: 12 Expense AFE Number: Expense_~AFE Amount -- 145066 Current Field Costs = Estimated Final Cost = (~urrent Operation: POH. Summary of Last 24 Hours RIH with 5" liner. Pipe plugged. POH & lay down liner. PU 120'2" pipe. Wash out to float equipment. Ran and cemented liner. Released from liner hanger. Reviewed By:~ BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. Th~r,~day. June 27. 1991 WELL: M-15 (21-0~-11-13~ PRUDHOE BAY UNIT Rig: Nabor,~ Rig #3-S Day: 1,3 Expense AFE Number: Expense AFE Amount -- 145066 Currant Field Costs Estimated Final Cost Current Operation: RIH. Summary_ of Last 24 Hours RIH with 8-1/2" bit and 9-5/8" scraper and clean out to liner top at 8302'. Circulate and test lap to 3000 psi. Ok. RIH with 4-1/~" bit. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: · As of 0600 Hrs. FHdav. June 28. 1991 WELL: M-I~ (21-0(~-11-13~ PRUDHOE BAY UNIT Rig: Na, bor~ Rig #3-S Day: 1 4 Expense AFE Number: Expense AFE Amount = 145066 Current Field Costs = Estimated Final Cost = Current Operation: Reverse circulating at 9460'. Summary_ of Last 24 Hours Clean out cement to 8837'. POH for new bit. RIH. Clean out cement to 9410'. ReVerse circulate. BP EXPLORATION (ALASKA), INC. DAILY WORKOVER REPORT: As of 0600 Hrs. M(~nday. July 1. 1991 WELL: M-15 (21-06-11-1~) PRUDHOE BAY UNIT Rig: Nabors Rig #3-S Day: 17 Expense AFE Number: Expense AFE Amount = 14~066 Current Field Costs = Estimated Final Cost = Current Ooeration: Rig released 2200 6-30-91 Summary of Last 48 Hours .. Polish tieback receptacle. Changeover to inhibited brine. Ran 4-1/2" 13% Cr tubing. ND BOP. NU and test tree to 5000 psi. Set packer. Freeze protect with 146 bbl diesel. Install BPV. Release rig 2200 6-30-91. Reviewed By: ~,~, BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :07/11/91 T#:82579 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-~?.~.5. A-26 R-01 M-15 M-15 O"'~1 - ~,,~_- P-10 W-38 Z-14 Production Log 07/07/91 #1 10300-10999 Sch 5" Perf 07/03/91 #1 8800-9132 Sch 5" Perf 07/03/91 #1 8150-9456 Sch 5" CCL PostWorkover 07/03/91 #1 8150-9456 Sch ' 5" Perf 07/06/91 #1 8814-9488 Sch 5" Perf 07~04/91 #2 13680-14710 Sch 5" CNL 07/02/91 #3 9450-10230 Sch 5" .Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:06/17/91 T#:82519 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. D-06 CCL 06/14/91 #1 9180-9435 Atlas 5" D-27 CCL 06/13/91 # 1 9350-9630 Atlas 5" M-15. CCL 06/15/91 # 1 8000-8240 Atlas 5" M-15 CL 06/09/91 #1 8026-8316 Atlas 5" N-14 CL 06/09/91 #1 9428-9718 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED JUN Z 5 1991 N~llka 011 & Ga~ Cons. Commission Anchorage ., co a ss,o. REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate x Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519.6612 4. Location of well at surface 1716' SNL, 606'WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 466' SNL, 573' WEL, SEC. 01, T11N, R12E, UPM At effective depth 4261 SNL, 234' WEL, SEC. 01, T11N, R12E, UMI At total depth 193' SNL, 491' WEL, SEC,. 01, T11N, R12E, UPM "'12~ Present well condiiion summary Total depth: measured true vertical 5. Type of Well: Developmen~ ..,Y._ Exploratory StratJgraphic Service RECEIVED APR 2 6 ]991 Nask.~ 0il & Gas Cons. Commission Anchorage 9657feet BKB 9309feet Plugs (measured) 6. Datum elevation (DF or KB) KBE - 51. 76 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-15 (21-06-11-13) PBU 9. Permit number/approval number 81-85/ 10. APl number 50- O29-20612 11. Field/Pool Prudhoe Oil Pool Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 9560feet Junk (measured) true vertical BKB 9170feet Length Size Cemented .. 110 20x30 8 c.y. 2639 13 3/8 3720 c.f. 8819 9 5/8 1332 c.f. measured Measured depth 136 2665 8845 .. 1311 7 396 c.f. 8346-9657 9012~9032~ 9048~9086~ 9100~9151~ 9166~9198~ 9220~9250' True vertical depth BKB 136 2665 8577 8133-9309 true vertical subsea 8676'-8891' (five intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8302' with 5 1/2" tailpipe to 8327' Packers and SSSV (type and measured depth) 9 5/8" TIWpacker at 8302'; 5 1/2' SSSV at 2012' 13. Stimulation or cement squeeze summary HCL Acid Wash 2/20/9! Intewals treated (measured) 8350'-9300' 14. Treatment description including volumes used and final pressure 35 BBL 15% HCL with 0.4% 01-25, 0.5% NE41, 0.2% MS-lO, 38fl Ferrotro1210, Displaced with 32 BBI. s meth. Rooresentative Dail_~ Average Production or Iniection 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 Daily Report of Well Operations 2490 5781 4691 3O30 6543 5506 16. Status ofwellclass~icationas: Oil X Gas Suspended 1341 311 1326 240 Service 17. I hereby c.ertify that the foregoing is true and correct to the best of my knowledge. Sign. ed '~~ A~ Title SupervisorWaterflood/MiscibleFIood Form 10-404 Rev 06/15/88 ~/ SUBMIT IN DUPLICATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevam P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date:04105/91 T#:82277 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. Well Records at (907) 564-4445. E-02 Gl{ 04/03/91 #1 E-02 Gl{ 04-02/91 #1 F-18 CCL 04/29/91 #1 M-15 PLS 04/28/91 #1 M-25 PLS 03/26/91 #1 Y-19 PLS 03/31/91 #1 Z-20 CCL 03/30/91 #1 If you have any questions, please contact BP 9700-9909 Atlas 5" 9674-9910 Atlas 5" 11280-11450 Atlas 5" 8000-9389 Atlas 5" 10700-11300 Atlas 5" 9270-9598 Atlas 5" 11200-11420 Atlas 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES RECEIVED Alaska 0~.~ & gas Cons BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 10/04/89 Transmittal: 80438 From: Information Control Well Records LR2-1 Subject: BP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. M-15 PROD-F 09/28/89 %1 8900-9399 Sch 5" A-01 PROD-F 09/27/89 %1 8600-9149 Sch 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS RESFa~~---~. ARCHIVES £ ~Naska Oil & Gas Cons. CommissiQO Anchorage BP EXPLORATION V' BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: DISTRIBUTION Date :07/11/91 T#:82579 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below, if you have any questions, please contact BP Well Records at (907) 564-d~.~.5. A-26 R-01 M-15 M-15 ~"~1- ~.~-..- P-10 W-38 Z-14 Production Log 07/07191 #1 10300-10999 Sch 5" Perf 07/03/91 # 1 8800-9132 Sch 5" Perf 07/03/91 #1 8150-9456 Sch 5" CCL Post Workover 07/03/91 #1 8150-9456 Sch ' 5" Perf 07~06~91 #1 8814-9488 Sch 5" Perf 07/04/91 #2 13680-14710 Sch 5" CNL 07/02/91 #3 9450-10230 $ch 5" .Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 To: Distribution From: Subject: Information Control Well Records LR2-1 ~P CASED HOLE FINAL LOGS Date: 05-AUG-89 Transmittal: 80232 Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907)564-4445. C-10 Temp 07/22/89 #1 11500-11800 E-07 PITS 07/22/89 41 9100-9438 E-28 GR 07/21/89 41 8800-10613 H-05 Prod-F 07/19/89 41 11200-11558 H-21 GR/Caliper 07/21/89 41 8700-9897 H-29 Prod-F 07/14/89 41 9100-9639 J-05 Prod-F 07/12/89 41 9850-10338 N-03 Prod-F 07/15/89 41 2900-11620 M-15 Temp 07/16/89 41 Surf-9560 R-08 Prod-F 07/18/89 41 10800-11180 R-20 Inj 07/20/89 41 10850-12024 Camco Camco Camco Camco Camco 5" Camco Camco 5' Camco 1"/5" Camco 1"/5' Camco 5' Camco Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 TO: HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS ARCHIVES DATE: 08-08-89 Tg: 80246 BP FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office A-20 Static Gradient 07/25/89 Camco A-25 Static Gradient 07-25-89 Camco M-15 Flowing Gradient 07-16-89 Camco R-18 Static Gradient 07-23-89 Camco GC-1E Static Gradient 07-27-89 Camco G-17 Static Gradient 07-23~89 Camco Received: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 10, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Attention' Mr. C. V. Chatterton Gentlemen' ..Well M-15 (21-06-13_} PBU Enclosed, in duplicate, is form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of pulling tubing. Yours very truly, Workover/Completions Supervisor RVS/KTH Enclosures (4) CC: J. Bragg (MB9-4) Well Records (LR2-1) w/10 Well File STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing X Alter casing 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1716' SNL, 606' WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 466' SNL, 573' WEL, SEC. 01, T11N, R12E, UPM At effective depth 211'SNL, 496' WEL, SEC. 01, T11N, R12E, UPM At total depth 193' SNL, 491' WEL, SEC. 01, T11N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Length 110' 2639' 8819' Repair well 5. Type of Well: Development X Exploratory Strafigraphic 1311' measured Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9657 feet Plugs (measured) 9309 feet BKB 9614 feet Junk (measured) 9270 feet BKB Size Cemented 20" x 30" 8 cu. yds. 13-3/8" 3720 cu. ft. 9-5/8" 1332 cu. ft. 7" 396 cu. ft. 9012'- 9250' (five intervals) Perforate Other 6. Datum elevation (DF or KB) KBE = 51.76 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number M-15 (21-06-11-13) PBU 9. Permit number/approval number 81-85/9-012 10. APl number 5O- 029-20612 11. Field/Pool Prudhoe Oil Pool Measured depth True vertical depth --- BKB 136' 136' 2665' 2665' 8845' 8577' 8346'-9657' 8133'-9309' true vertical 8675'. 8890' Tubing (size, grade, and measured depth) 5-1/2" L-80 to 8303' with tailpipe to 8327' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. 9-5/8" TlW packer at 8303'; 4-1/2" SSSV at 2012' ~'~ ~t'~ .... ~ Intervals treated (measured) .~ ~.~, ~.;;,. ~. ~ ,;,..~,.. ~., ,/ ~;' .:.. ,:~'.;.,'"": Treatment description including volumes used and final pressure .... ,,~,~,,.~ .~1 & Gss Cons. C0mmissior~ , r Reorese~ative Daily Averao~ ~~ or Inie~ion Dat~ OiI-Bbl Gas-Md W~er-Bbl Casing Pressure Prior to well operation 3430 4080 2459 1770 Subsequent to operation 1760 1755 936 2990 Tubing Pressure 304 psig 862 psig 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereb~_'fy t.~,the foregoing~)tru.~nd cor~ to the best of my knowledge. Signed ~r....~~__~,~/~../.~~/_ Title Completion Engineering Supervisor Form 10-404 Rev 06/1,,~ SUBMIT IN DUPLICATE ATTACHMENT I M-15 RIG WORKOVER Procedure; · 2. 3. 4. 5. 6. . 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. MIRU workover rig. Accepted rig at 0300 hours on 01/07/89. Circulated diesel from well. Set 2-way check valve. ND tree. NU and tested BOP's to 5000 psi. Pulled 4-1/2" tubing. RIH fishing tools and 9-5/8" storm packer. Set storm packer. ND BOP's. Installed 9-5/8" packoff. NU and tested BOP's to 5000 psi. RIH and recovered PBR. Milled and recovered 9-5/8" packer-tailpipe assembly. RIH with 8-1/2" bit and cleaned out to 8344'. RIH with 6" bit and 7" casing scraper to 9614'. Reverse circulated. RIH with 8.5" gauge ring/junk basket to 8355'. RIH with 5-1/2" completion with 5 GLM's. ND BOP's. NU and tested tree to 5000 psi, OK. Set plug in tailpipe. Set 9-5/8" permanent packer. Tested tubing X easing annulus to 2500 psi-OK. Opened sliding sleeve and displaced annulus to brine and freeze protected with diesel, and displaced tubing to diesel. Closed sliding sleeve. Pulled plug from tailpipe. Set plug in BVN. Released rig at 2400 hours on 01/14/89. STANDARD ALASKA PRODUCTION Rig: Nabors 18E Well: M-15 (21-06-11-13) Daily Drilling Report -- PBU -- Workover January 9, 1989 at 0600 hrs AFE# 160487 (Expense) ~ # ~90000 (Capital) AFE Amount: AFE Amount: "Currant Amount: 0600 Depth: 9,614' Day: 2 Current Operation: RIH for PBR. MIRU. Accept rig at 0300 on lf7/89. Circulate diesel from well Install 2way check. ND tree. NU BOP and test to 5000 psi. Pull 2way check. Pull tubing. RIH fishing tools & storm packer. Set storm packer. ND BOP. Install 9-5/8" packoff. NU BOP & test to 5000 psi. Recover storm packer. RIH m recover PBR. STANDARD ALASKA PRODUCTION Daily Drilling Report .. PBU -- Workover January 10, 1989 at 0600 hrs Rig: Nabors 1SE AFE # 160487 AFE Amount: ~xpense) Well: M-15 (21-06-11-13) AFE # 29000O (Capital) AFE Amount: Current Amount: 0600 Depth: 9,653' Day: 3 Current Operation: RIH to recover packer. Recover PBR. RIH mill packer and push to 8,306'. Circulate. RH-I with spear. STANDARD ALASKA PRODUCTION Daily Drilling Report .- PBU -- Workover January 11, 1989 at 0600 hrs Rig: Nabors 1SE Well: M-15 (21-06-11-13) AFE# 160487 (Expense) AFE # 290000 (Capital) AFE Amount: AFE Amount: Current Amount: 0600 Depth: 7,400' Day: 4 Current Operation: POH with RTTS. Recover packer. Spot LCM pill. RIH 7" RTTS test casing and lap to 2500 psi. OK. STANDARD ALASKA PRODUCTION Daily Drilling Report .- PBU -- Workover January 12, 1989 at 0600 hrs Rig: Nabors 1SE Well: M-15 (21-06-11-13) AFE# 160487 (Expense) APE # 120871 (Capital) AFE Amount: AFE Amount: Cun'ent Amount: 0600 Depth: 9,653' Day: 5 Current Operation: POH. RIH 8-1f2" bit. Clean out to liner top 8,344'. Reverse circulate. RIH 6" bit, 7" scraper. Clean out to 9,614'. Reverse circulate. POH. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU-- Workover January 13, 1989 at 0600 hrs Rig: Nabors 1SE Well: M-15 (21-06-11-13) AFE# 160487 (Expense) AFE # 120871 (Capital) AFE Amount: AFE Amount: Current Amount: 0600 Depth: 9,653' Day: 6 Current Operation: Made 8.5" gauge ring mn to 8,355'. Ran 5-1/2" tubing. ND BOP. N.U. and test tree to 5,000 psi. OK. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Workover January 15, 1989 at 0600 hrs Rig: Nabors 18E Well: M-15 (21-06-11-13) AFE# 160487 (Expense) AFE # 120871 (Capital) AFE Amount: AFE Amount: Current Amount: 0600 Depth: 9,653' Day: s Current Operation: Released rig 2400 hrs. 1/14/89. Pull dummy B.V. Set plug in tailpipe. Set packer. Shift sliding sleeve. Displace tubing to diesel Close sliding sleeve. Pull plug from tailpipe. Set BV' No test. Set plug in BVN. Release rig. Standard Alaska Ptocluction Companl~' 900 Eos~ 8enson BQuI~ J P.O. ~s 19~12 Anchorage. Alaska ~ i 9-~J ? (~7) 564-5 ! I I REFERENCE: HOUSTON ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Date: 01-10-89 TI: 79716 The following materlai'ls being submitted herevith. Please acknowledge receipt by signing a copy of ?his lette~ and returning it to thls office:, H-22 Yrod-F 01-06-89 #1 9450-9933 Sch 5" M-15 CCL 01-05-89 #1 8180-8420 Sch 5" X-09 Perf 01-07-89 #1 11900-12244 Sch 5" Race i ved wl~'-' ,_ ~ Date .AlasA Oil & Gas Cons. Commission A.(;horags A uni! oJ the original Standard ~i Company Founded m Cleveland. ~o. ,n 1810 Shirley R. McCurry INFORMATION CONTROL Well Records LR2-1 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown __ Re-enter suspended well__ Alter casing Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program __ Pull tubing X Variance__ Perforate__ Other __ 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1716'SNL, 606' WEL, SEC. 01, T11N, R12E, UPM At top of productive interval 466' SNL, 573°WEL, SEC. 01, T11N, R12E, UPM At effective depth 211'SNL, 496'WEL, SEC. 01, T11N, R12E, UPM At total depth 193' SNL, 491' WEL, SEC. 01, T11N, R12E, UPM 12. Present well condition summary Total depth: measured 9657 feet Plugs (measured) true vertical 9309 feet BKB Effective depth: measured 9614 feet Junk (measured) true vertical 9270 feet BKB Casing Length Size Cemented Structural ......... Conductor 110' 20"x 30" 8 cu. yds. S u dace 2639' 13-3/8" 3720 cu. ft. Intermediate 8819' 9-5/8" 1332 cu. ft. Production ......... Liner 1311' 7" 396 cu. ft. Perforation depth: measured 9012'- 9250' (five intervals) 6. Datum elevation (DF or KB) KBE = 51.76 AMSL feet 7. Unit or Property name Prudhoe Bay Unit Measured depth 136' 2665' 8845' ... 8346'-9657' 8. Well number M-15 (41-01-11-12) PBU 9. Permit number 81-85 10. APl number 50- 029-20612 11. Field/Pool Prudhoe Oil Pool True vertical depth BKB 136' 2665' 8577' 8133'-9309' true vertical 8675'- 8890' R'ECEi,VED Tubing (size, grade, and measured depth) 4-1/2" L-80 to 8272' with 4-1/2" tailpipe to 8412' JAN o 6 t989' Packers and SSSV (type and measured depth) 9-5/8" BOTpacker at 8272'; 4-1/2" SSSV at 19~j~[g~ ~|J '.~ .~as ~Coll~J, '"'" ~"~h'~ ~.~_h0ra.q~'" 13. Attachments Description summary of proposal Z Detailed operations program i BOP sketch 14. Estimated date for commencing operation 16. If proposal was verbally approved Name of approver Lonnie Smith 01-04-89 Date approved 15. Status of well classification as: Oil 3; Gas~ Suspended ~ Service 17. I hereby~t.~,the forego~ iTe and correct to the best of my knowledge. Signed /~,~..~.alt-.~~~ Title Completion Engineering Supervisor .'~No - FOR COMMISSION USE ONLY Conditions of approv tify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission m J ~'~m~m' J ~ ~ ~ ~ ~ ~ T' Form 10-403 Rev 06/15/88 Date . I Approval No. ~,,.,~/~ Commissioner ~,porov~,a ~upy Returned _ ./- Date SUBMIT IN TRIPLICATE ATTACHMENT I PROPOSED M-15 RIG WORKOVER procedure: · 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. MIRU workover rig. Pull BPV. Circulate well. Set 2-way check valve. ND tree. NU and test BOP's to 5000 psi. Pull 4-1/2" tubing. Test 9-5/8" casing to 2500 psi. Replace 9-5/8" packoff. RIH and recover PBR. Mill and recover 9-5/8" packer-tailpipe assembly. RIH with 6" bit and 7" easing scraper to 9614' RIH with 9-5/8" scraper to 8340'. Reverse circulate. RIH with 8.5" gauge ring/junk basket to 8340' RIH with 5-1/2" completion with 5 GLM's. Land tubing. Set 2-way check valve. ND BOP's. NU and test tree to 5000 psi. Set plug in tailpipe. Set 9-5/8" permanent packer. Open sliding sleeve and displace annulus to brine and freeze protect with diesel. Close and test sliding sleeve. Set BPV. Release rig. WORKOVER §.O.P. STACK CONFIGURATION 13-S/8 IN. TRIPLE RAM STACK 5000 PSI WP ATTACHMENT II DRILLIN6 ANNULAR PREVENTER ! 2 IN. KILL LINE CHECK HAND HAND GATE GATE PIPE RAMS 1 1 I I 'PIPE RAMS DRILLING SPOOL 4 IN. CHOKE LINE GATE GATE I I BLIND RAMS ! I Slanda,d Alaska floduclion Company 900 Eo~,I Ben*,on 8oulevo,d P.O. Bo, 196612 Ancho~'ocje. AIo%I.o 995 !9.66 {9071 564.5111 HOUSTON ARCO CHEVRON E,~ON TEXACO TO: MOBIL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Da te: Ti: 11-29-88 79590 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returning it to this office: '[-I-23 ',R-02 'M-15 Gas Life Survey 11-19-88 #1 100-9157 Camco 2" Temp 11-14-88 f/1 surface-2500 Camco Leak Dat. Prod-F 11-19-88 #1 100-9526 Camco 2"/5" Received INDEXED DA~AS ,,~co STANDARD C~EWO~ ALASKA PRODUCTION EXXON Da*e: 01/07/88 TEXACO TO: T~: 78398 MOBIL · PHILLIPS STATE OF ALASKA REFEREHCE: SAPC FINAL DATA - PRESSURE SURV~ DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: E-28 "-a E_28 ~ F-24 "'" J-22 '"~J-24 '"'* J-26 "' M-4 '"" '"" M-9 '"'~N-15 "~ 1{-16 '" 1{-19 '""'I{-23 ~ 1{-26A '"' S-4 ~ S-13 Received Dote Multirate Test 12/10/87 GO PBU 12/13/87 GO Static Gradient 12/04/87 Camco " " 12/19/87 Camco " " 12/17/87 Camco Static Gradient 12/20/87 Camco ". " 12/16/87 ~amco " " 12/21/87 " " " 12/22/87 " " " 12/13/87 " " " 12/22/87 " " " 12/06/87 " "' 12/13/87 GO " " 12/24/87 Camco " " 12/05/87 Camco Pressure FallOff 11/20/87 " BHP 12/24/87 OTIS Static 12/12/87 GO Static 12/10/87 Camco ~ Naska 0il & Gas Cons. Commission Anch0mge Victoria Aldridge I NFORMAT I ON CONTROL Wel I Records LR2-1 A umt ot fhe Or,§,-ol S"ondo,d CM Founded ,n Clevelond. Oh,o. ,fl 1870 Standard Alaska .. Production Comp~ 900 East Benson Boo. ,ord P.O. Box 196612 Anchorage, Alaska 99519-6612 (9071 561-5111 STANDARD ALASKA PRODUCTION December 16, 1987 Alaska 0il & Gas Conservation Cor~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-15 (41-01-11-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of stimulating the well. Yours very truly, JAB: JAM ~ . A. Bragg ~M'anager Production Engineering Enclosures (4) cc: J. L. Haas (MB12-1) Well Records (LR2-1) w/10 M-15 Well File ~a~ 0il & Gas Cons. commissiou ~chorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA AL~'."~ XA OIL AND GAS CONSERVATION C(J'''~' JIISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~x Plugging [] Perforate [] Pull tubing [] Alter Casing r~ Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 51.76 AMSL Feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 7. 4. Location of well at surface 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, OPM At top of productive interval 466' SNL, 573' WEL, Sec. 01, TllN, R12E, OPM At effective depth 211' SNL, 496' WEL, Sec. 01, TllN, R12E, UPM At total depth 193' SNL, 491' WEL, Sec. 01, TllN, R12E, OPM Well number M-15 (41-01-11-12) PBU Approval number 7-822 9. APl number 50--029-20612 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured 9657 feet true vertical 9309 feet BKB Plugs (measured) Effective depth: measured 9614 feet Junk (measured) true vertical 9270 feet BKB Casing Length Size Structural -- Conductor 110' 20"x30" Surface 2639 ' 13 3/8" Intermediate 8819 ' 9 5/8" Production -- Liner 1311' 7" Perforation depth: measured 9012' - 9250' true vertical (ss) 8675' - 8890' Cemented 8 cu. yds. 3720 c.f. 1332 c.f. 396 c.f. (five intervals) Measured depth 136' 2665' 8845' 8346'-9657' True Vertical depth BKB 136' 2665' 8577' 8133'-9309' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8272' with 4 1/2" tailpipe to 8412' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8272'; 4 1/2" SSSV at 1997' 12. Stimulation or cement squeeze summary See attachment Intervals treated (measured) RECEIVED DEC 1 7 1987 Alaska 0il & Gas Cons. C0mmissi~ Anchorage Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 3910 3521 1890 1476 275 Subsequent to operation 3440 3220 2860 1600 248 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Form 10~¢ Rev. 12-1-85 ~/d Title Manager Production Engineering Date/~ ·/~": {~; Submit in Duplica{~ Well M-15 (41-01-11-12) PBU STIMULATION OPERATIONS A combination EDTA/scale inhibition treatment via coiled tubing was per- formed November 2, 1987 on the following perforated intervals: 9012' - 90 32' MD BKB 9048' - 9086' MD BKB 9100' - 9151' MD BKB 9166' - 9198' MD BKB 9220' - 9250' MD BKB A coiled tubing ~onveyed inflatable packer was set between 9151' and 9166' MD BKB to ensure stimulation of both.'~interval zones. The treat- ment was pumped in two stages as follows: 1st stage down coiled tubing 20 bbls. diesel 2000 gal. EDTA 50 bbls. scale inhibitor 300 bbls. overflush 20 bbls. diesel Treatment fluids were displaced to 'the perforations with diesel. 2nd stage down coiled tubing/tubing annulus 30.bbls. diesel 3000 gal. EDTA 95 bbls. scale inhibitor 500 bbls. overflush 30 bbls. diesel Stage 2 treatment.fluids were displaced to top.of perforations with dead crude. The well was left shut'infor 24 hours fOllOWing the treatment, the packer was retrieved; and the'well put back'on.'production and tested~ jm 12/9/87 Standard Alaska Production Company,' 900 East Benson Boule~ P.O. Box 196612 Anchorage, Ak~ska 99519-6612 (907) $64-5111 STANDARD ALASKA PRODUCTION October 16, 1987 Alaska 011 & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-15 (41-01-11-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to stimulate the well. Yours very truly, JAB: JAM "'~ Enclosures (9) cc: J. L. Haas (MB12-1) M-15 Well File pervisor Production Operations ~l~.s~:.~ 0il & Gas ConS. commisslott ~ct~orage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA " ALA[..A OIL AND GAS CONSERVATION COI~,,.,,SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator 5. Datum elevation (DF or KB) STANDARD ALASKA PRODUCTION COMPANY KBE = 51.76 feet 3. Address 6. Unit or Property name P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 Prudhoe Bay Unit 4. Location of well at surface 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM At top of productive interval (top Ivishak/Sadlerochit) 466' SNL, 573' WEL, Sec. 01, TllN, R12R, UPM At effective depth 211' SNL, 496' WEL, Sec. 01, TllN, R12E, UPM At total depth 193' SNL, 491' WEL, Sec. 01, TllN, R12E, OPM 7. Well number M-15 (41-01-11-12) PBU 8. Permit number 81-85 9. APl number 50-- 029-20612 10. Pool i~rudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical 9657 feet Plugs (measured) 9309' feet BKB Effective depth: measured 9614 feet Junk (measured) true vertical 9270 feet BKB Casing Length Size Cemented Structural -- Conductor 84' 20"x30" 8 cu.yds. Surface 2639' 13 3/8" 3720 c.f Intermediate 8819' 9 5/8" 1332 c.f. Production -- Liner 1311' 7" 396 c.f. Perforation depth: measured 9012' - 9250' (five intervals) true vertical (ss) 8675' - 8890' Tubing (size, grade and measured depth) 4 1/2" L-80 to 8272' with 4 1/2" tailpipe to 8412.' Packers and SSSV (type and measured depth) 9 5/8" BOT packer at 8272'; 4 1/2" SSSV at 1997' Measured depth 110' 2665' 8845' 8346''9657' True Vertical depth BKB 110 ' 2665' 8577' 8133, -9309' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation October 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge · Sig~ed ~'~,//~,/~,_~ /~~ Title Supervisor Production O~3erationsDate/0'/~:~7 /~ A-.' Bragg ~ Commission Use Only Conditio~ of approval Notify' commission so representative may witness I. Approval No. ,7 --- c,, c~ ¢~- ~) -'~-' [] Plug integrity [] BOP Test [] Location clearanceI ...... , I [i',~,;:.,i;{[. L ~'{. Commissioner the commission Date/~ '"~'70 "~ '~1' Approved by ~ "";~"" :~: ~ .................................. Dy oroer o~ . .... .,~ j. Form 10-403 Rev 12-1-85 Submit in triplicate Well M-15 (41-01-11-12) PBU STIMULATION PROPOSAL A combination EDTA/scale inhibitor treatment via coiled tubing is pro- posed for the following perforated intervals in Well M-15. 9012' - 9032' MD BKB 9048' - 9086' MD BKB 9100' - 9151' MD BKB 9166' - 9198' MD BKB 9220' - 9250' MD BKB A coiled tubing conveyed inflatable packer will be set between 9151' - 9166' MD BKB to ensure stimulation of both interval zones. The treat- ment will be pumped in two stages as follows: 1st stage down coiled tubing 20 bbls. diesel preflush w/mutual solvent 2000 gal. EDTA 50 bbls. scale inhibitor solution 300 bbls. overflush 20 bbls. diesel overflush w/mutual solvent Treatment fluids will be displaced to perforations with diesel. 2nd stage down coiled tubing/tubing annulus 30 bbls. diesel preflush w/mutual solvent 3000 gal. EDTA Remainder of scale inhibitor solution 500 bbls. overflush 30 bbls. diesel overflush w/mutual solvent Stage 2 treatment fluids will be displaced to top of perforations with dead crude. The well will be left shut in for 24 hours following the treatment, then returned to production and tested. jm 10/15/87 Coiled Tubing Blow-Out-Preventers Coiled Tubing Pack-Off' Blind Rams ~ ] Cutter Rams ( 2" Chicksan (Kill Line) Pipe Rams Pump-In Sub (C ircula te/R e turns) W ell Head Swab Valve P~odvctiofl Compony 900 [oqt ~c-~o- Boule-o,d PO Go. ,~07~ 564 ~11 I INDEXED DALI,AS ARCO CHEVRO,~ STANDARD , AI./'.~,%I'/. !~P(')[;I ~' li~ .~l',J EXXO~ TEXACO Date: 09/14/87 TO: MOBIL X#: 78171 PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-34A B-3B B-3B C-3 F-8 J-19 J-22 J-24 J-25 J-26 J-26 M-15 M-15 - 5 ¥-2 CN 09/06/87 #1 8700-9260 Sch 5" CRT 08/31/87 #1 8633-9872 ' Sch 5" CNL/GR 09/01/87 #1 9000-9893 Sch 5" Temp. 08/15/87 #1 Surf-960 GO 5" Perf. Record 09/03/87 #1 11000-11233 Sch 5" CCL/Perf. 07/15/87 #1 9120-10209 GO 5" CCL/Pe~f. 07/14/87 #1&2 9300-10500 GO 5" CCL/Perf. 07/18/87 #1 11195-11470 GO 5" CET 09/04/87 #1 8200-9600 Sch 5" CBT 08/28/87 #1 9200-10661 Sch 5" CRT 08/28/87 #1 9550-10665 Sch 5" GR 08/05/87 #1 8900-9500 GO 5" Hydro 08/05/87 #1 8900-9300 GO 5" Temp. 08/05/87 #1 ,8900-9300 GO 5" CFS 08/05/87 #1 8900-9300 GO 5" CCL/Perf. 08/16/87 #1 91;0-10944 GO 5" R 'IV." Rece i ved /"'-'~'~,, hi, ~,. Cons. C0mmlssl0n ~SR~A~. Aclo~rR%dL ge (k /~ Aneh0rage Date Anohorage Wel I Records LR2-1 u,~! ul the. (.t(i,,wjl ,~h)~l Fhu,,(fed ,,, ('.l,..ve.l.,.,(f SOHIO ALASKA PETROLEUM COMPANY S FO ARCO CIIEVRON EXXON ,o SFO/UNIT/STATE: TE:OkCO (-Marathon) MOBIL PHILLIPS ~,:,,;;~,...,,-,,--..,;.,,,.,.,.,.,.,.,.,~..rL-.~,,- , .. . ~STATE-~ 'OF AI~ .,.,:.~.~.~11';~, ~'~ - v. .... BPAE 31 ! I "C"SIREET ANCHORAGE, ALASKA [ELEPHONE 19071 265-0000 MAIL: POUCH 6-6 ! 2 ANCHORAGE. ALASKA 99502 Date: 4/8/85 T#: 76107 REFERENCE: . IO CASED HOLE FINAL LO. GS """"copy of this letter and returning it to this office:-- H-12~/ CFS 3/03/85 10500-11000 GO #1 5" K-2A(,~ CFS 3/06/85 11200-11540 GO #1 S" M-11~ CFS 3/05/85 9000-9400 GO #1 5" ,i~~?'~ c~s 3/07/85 8800-9300 co #1 5- R-4 / CFS 3/06/85 9500-9800 GO #1 5" R-16~/ Spinner 3/09/85 11250-11600 Camco #1 5" 0111%11~" ;'- · / · ^ .~.. GaS ConS. C Development Ceo 1 ogy SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO TO: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS STATE BPAE (Transmittal Only) 3111 "C" STREET ANCt~ORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-61 2 ANCHORAGE. ALASKA 99502 Date: 4/03/85 T#: 76100 REFER~~'' Sgl~TO FINAL DATA - PRESSURE SURVEY DATA ~The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- M-15 R-4 PBU & BHPD 3/09/85 GO PBU & BHPD 3/09/85 GO RECEIVED DATE ~, .Cathy Perkins LR 2-1 Alaska 0i~ & Gas Cor~s. L;ommtsslon, ueve~opmen t .Geology A~,~hora§e Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAG E, ALASKA 99502-0612 February 12, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well M-15 (41-01-11-12) PBU Enclosed, in duplicate, are the following forms for the above-named well. 1. Form 10-407, Completion Report 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. JAB.~jmw Enclosures cc: A. E. Leske Well Records (LR2-1) Drilling Well File #17 Yours very truly, oistrict ~ Engineer (Acting) RECEIVED 91985 4taska Oil & Gas Cons. Comrnissiolt Anchorage ALASKA(. .L AND GAS CONSERVATION C , .MISSION 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 Sohio Alaska Petroleum Company 81-85 ~ 3. Address S. APl Number ~ P. O. Box 6612, Anchorage, Alaska 99502 50-029-20612 4. Location of well at surface 9. Unit or Lease Name " 1716' SNL, 606' WEL, Sec. 1, TllN, R12E, UPM Prudhoe Ba~z Unit At Top Producing Interval Top of Sag. R. SST. 10. Well Number 525' SNL, 593' WEL, Sec. 1, TllN, R12E, U?M M-15 (41-01-11-12) At Total Depth 11. Field and Pool 193' SNL, 491' WEL, Sec. l, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay KBE = 51.76' AMSLI ADL 28260 Prudhoe Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore [ 16. No. of Completions 8/6/81 8/22/81 8/28/81 feet MSLI Ol3.e 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 9657'MD 9309'TVD 9614'MD 9270'TVD YES~ NO~] 1997 feetMDI 1877' 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR~ FDC/CNL/GR~Cal~ RFT~ CBL~ §7roscopic survey. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulate~.Conductoz Surface 110' 36" 8 cu'vds, concrete 13 3/8" 72~ L-80 Surface 2665' 17~." 3720 cu,ft. Perm~fr¢,st II 9 5/8" 47~ L-80 Surface 8845' 12~" 1202 cu.ft. Class G: 130 cu.ft. Permmfr¢,st C 7" 26# L-80 8349' 9657' 8~" 396 cu.ft. C.];ass G ~,/18% salt 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ' 'TUBING RECORD" interval, size and number) MD TVDss SIZE ~)EPTH SET (MD) PACKER SET (MD) Prudhoe Oil Pool Top: 9012' 8675' ' 4~" 8412' 8272' Bottom: 9250' 8890' .. 9012'-9032' BKB (8675'-869'4' TVDs's) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9048'-9086' BKB (8708'-8742'. TVDss) DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9100'-9151' BKB (8755'-8801' TVDss) 9166'-9198' BKB (8815'-8844' TVDss) ' ' 9220'-9250' BKB (8863'-8890' TVDss) ~ . 27. '. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) August 1, 1982I Flowin~ Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I1~ 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 lith°logy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. REC'EIVED FEB ! 9 1 85 Alaska 0il & Gas Cons. Commissio~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Sag River SST. Shubl ik Ivishak 31. LIST OF ATTACHMENTS GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH BKB 8853' 8897' 8997' Subsea 8532' 8572' 8662' 30. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Title Acting District Petroleum Enginee~ate___ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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 { STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address P. O. Box 6612, Anchorage, Alaska 4. Location of Well At Surface: 99502 7. Permit No. 8] -85 8. APl Number 50- n~-~06] ? 9, Unit or Lease Name Prudhoe Bay Unit 10. Well Number 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 11. Field and Pool 5. ElevationKBE _-in 51.feet (indicate76 ' AMsLKB' DF, etc.)ti 6. LeaseADT. Designation28260 and Serial No. PrudhoePrUdh°e OilBaY ;Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) M-15 (41-01-11-12) PBU SUBSEQUENT REPORT OF: (Submit in Duplicate) r-~ Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). .... The following additional intervals were perforated February 9, 1985 using Schlumberger 2-7/8" Hyperdomes at 4 s.p.f. A lubricator was installed and tested to 3500 psi on all well work.. ., 9012'-9032' BKB (R..ef. BHcS/GR, 8-22-81) 9048'-9086' .,,BKB ( " ) 9100'-9151' BKB ( " ) An SSSV was set and tested in the ball valve nipple at 1997'. RECE 'VED 9 ]985 Alaska 0il & Gas Cons. CommJssio~ Anchorage hereby certify that the foregoing is true and correct t° the best of my knowledge. ' ~~ ~ Acting District d ~ Title Petroleum Engineer J ~he spacyb~low ,or Commission use UU By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA (~ ~-~ · -. ' t ALASKA(' .L AND GAS CONSERVATION C~" ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERA'rlONS 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-~5 3. Address 8. APl Number P. O. Box 6612, Anchorage~ Alaska 99502 50-029-20612 4. Location of Well 9. Unit or Lease Name at surface 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 51.76' AMSL 6. Lease Designation and Serial No. ADL 28260 For the Month of February ,19 85 Prudhoe Bay Unit 10. Well No. M-15 (41-01-11-12) ?BU 11. Field and Pool Prudhoe Bay Prudhnm ~i~ Pon] 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressur~. tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data See Attached. RECEIVED Alaska 0il & Gas Cons. CommJssior~ Anchorage -17,~ I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SI~E~ /,?,vVU~,J [ It,//,~. TITLE Petroleum Engineer DATE . ' NO"l'E--I~ort on this form is require,d .~.~/e~ach 'calendar month, regardless of the status of'operations, and must be ,.J~d ,,~uplicate with the Alaska 'Oil and~ Conservation Commission by t~e 15th of the succeeding month, unless otherwise directed. ..Form 1~04 Submit in duplicate Rev. 7-1-80 PERFORATING DATA - WELL M-15 (41-01-11-12) PBU February 9, 1985: Rigged up Schlumberger and perforated the following additional intervals using 2-7/8" Hyperdomes at 4 spf: 9012'-9032' BKB (Ref. BHCS/GR, 8/22/81) 9048'-9086' BKB ( " ) 9100'-9151' BKB ( " ) Put well on production. February 11, 1985: Set and tested SSSV in ball valve nipple at 1997'. Well on production. RECEIVED Alaska 0it & SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 January 15, 1985 Alaska Oil & Gas Conservation Comission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention- · Gentlemen: Mr. C. V. Chatterton Wells M-4~ M-6~ M-10~ M-15~ M-16 Enclosed, in triplicate," is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate additional intervals in these wells. J~/~pjw Enclosures /4.~mes.A. Bragg ~/~' /)~istrict Petroleum Engineer (Acting) CC: A. E. Leske Geology Well File #17 RECEIVED JAN 2 4 1985 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ~-,'._ AND GAS CONSERVATION CO(, JlISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address P.O. Box 6612, Anchorage, Alaska 99502 4. Location of Well At Surface: 1716' SRL, 606' WEB, Sec. 01, TiIN, I~12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I6. Lease Designation and Serial No. KBE = 51.76' AMSL I ADL 28260 12. 7. Permit No. R]-R~ 8. APl Number 5o- 029-20612 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number M-15 (41-01-11-12) PBU 11. Field and Pool Prudb~e Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate I-~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change P~ans [] Repairs Made [] Other [] Pull Tubing [] Other ' [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional intervals will. be perforated' in February, 1985 us'.~ng Schlumberger 3 3/8" Scallop quns at 6 spf. A lubricator will be installed and tested to 3500 psi for all well work. 9012'-9032' BKB (Ref. BHCS/GR, 8'22-81) 9048'-9086' BKB ( " ) 9100'-9151' BKB (. " ) An SSSV will be set and tested in the ball val~ nipple at 1997'. ~ [ C E I V [. D JAN 2 1985 Subsequent W'ork B. epot'ted.' oa Yo~ No~-'~0~ Da~ ~~~ Alaska 0il hAnCh0rage~aS Cons. C0mmissi0 1~4. I hereby cert. j~ ~~-Eelow fo r Com__m issio n use Cond/ticlths of Approval, if any: that the foregoing is true and correct to the best of my knowledge. Title District Petroleum Enqineer ' Approved by Date Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1.80 Submit ".1 ntentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCH CRAG E, ALASKA 99502-0612 August 15, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well M-.i5 (.41-01-11-12)PBU Gentlemen: Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-mamed well. This contains our subsequent to . performing a scale inhibitor matrix stimulation treatment on this well. Yours very truly, JAB/~pjw Enclosures cc: J. D. Hartz Geology Well File #17 J. A. Bragg District Petroleum Engineer (.Acting) R£CE[VF.D AUG ! 6 !98 Alaska Oil & Gas Cons. commission Anchorage STATE OF ALASKA ALASI ' OIL AND GAS CONSERVATION[, 3MMISSION SUNDR NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-85 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50t)29-20612 4. Location of Well At Surface: 9. Unit or Lease Name Prudhoe Bay Unit 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 51.76' AMSL I ADL 28260 12. Check AppropriateBoxTolndicate NatureofNotice, Report, orOtherData 10. Well Number M-15 (41-01-11-12) PBU 11. Field and Pool Prudhoe Bay . Prudhoe Oil Pool [] [] NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [~ Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe' Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A 44 barrel scale inhibitor matrix squeeze was per.formed over the following intervals on July 20, 1984. The well was shut-in for 24 hours after the treatment. 9166'-9198' BKB (Ref. BHCS/GR, 8/22/81) 9220'-9250' BKB ( " ) An SSSV was set and testsd in the ball valve nipple at 1997'. RECEIVED AUG 1 619B Alaska 0ii & Gas Cons. Commission Anchorage TitleDiStrict Petroleum Engineer space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission . Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 6, 1984 Alaska Oil & Gas Conservation Co~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention~ Mr. C. V. Chatterton Wells M-9 ,..M-Il and. M-15 PBU Gentlemen: " ....~. Enclosed, in triplicate, are Forms 10-403, Sundry Notices and Reports on' Wells, for the above-named wells. These contain our proposals to perform scale inhibitor matrix stimulation treatments on these wells. Enclosures CC: J. D. Hartz Geology Well File #17 Yours very truly, istrict Petroleum Engineer RECEIVED Alaska 0ii & Gas Cons. commissio~ Anchorage STATE OF ALASKA ALASKA q_' AND GAS CONSERVATION CO["'llSSION SUNDRY NUTICES AND REPORTS' N WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, AK 4. Location of Well At Sar face: 99502 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 51.76' AMRT. ' 12. I 6. Lease Designation and Serial No. _ADT_. 28260 7. Permit No. 81-R5 8. APl Number 50- 0~9-206!2 9. Unit or Lease Name 10. Well Number 11-.'F~e~-d ar~d-~'ooT-. .... ' ""'"' Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate X~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). A 44 Bbl. scale inhibitor matrix squeeze will be performed during August/September, 1984. The well will be shut-in for 24 hours after the treatment. The SSSV will be removed prior to stimulation and reset after the job at 1997'. 9166 '-9198' BKB (Ref. BHCS/GR, 8/22/81) 9220'-9250' BKB ( " ) Subseqocnt on Form RECEIVED JUL 1 01984 Alaska Oil & Gas Cons. Commission Anchorage l~.]/~reby~ce/~. ~ that the foregoing is true and correct to the best of my knowledge. S~ned ~_,~///////,~- ~' u%/~/'-~ ~ Title mis~ic~ Pe~le~ mq~e~ ~e spac~lew for Comm~s;,o; use ~ ~ ' //' ' Condit~f Approval, if any: -- APProved COPY Returned --' By Order of Approved by COMMISSIONER the Commission Date Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO " CHEVRON 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907} 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 9~502 ~o: SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS ." .7, ~:' ",? :""~' ' STAT. E :::" OF ?" AK'" BPAE (Transmittal Only) CENTRAL FILE$(CC~' s-Transmittal Only)_ Date: 11/1/82 Trans.#: 2802 CC#: 55802 REFERENCE: · ~' CASED HOLE_ FINAL LOGS. ~'~he following material is being submitted herewith. Please acknowledge receipt by signing a copy ,of this letter and returning it to this office:-- E-17 M-15' G-l,8 G-3 Y'13 A-'12 Spinner 9/27/82 #1 10.650-11160, Otis 5" Spinner 9/1/82 #1 9050-9300 GO 5". Spinner 9/25/82 #1' 10000-t,0350 GO 5" Spinner 9/23/82 #1 88'50-9230 GO 5" Spinner 9/19/82 #1 10350-10700 GO 5" Temp. Survey 10/19./82 #1 8800~9600 Camco 5" (4/82) .'. nEC[~VED ....................... Victoria Aldridge Alaska 0il & Gas Cons. C0mmissi0P, ev elopmen t Geo logy DA"~E ' ' ............................ AR~h~ag9---- Well Records' TP1-5 SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON 3111 "C" S1AEET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 GETTY SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) CENTRAL FILES (CC~'s - Transmittal Only) Dace: 10-20-82 Trans.~: 2753 CC#: 557~ REFERENCE: ' ,. Z ~HIO~ FINAL DATA - PRESSURE SURVEY DATA · The following material is being submitted he~'ewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- E-18'" E-17-~ G-18-- G-3 '- Y-13j C-lO" Y-3 '~ A-5 N-7,./ M-5 Pressure .Survey 9-22-82 Camco Pressure Survey'& BHPD 9-1-82 GO Pressure Survey 9-4-82 GO Pressure Survey 9-17-82 GO Pressure Survey & BHPD 9-24-82 Otis Pressure Survey & BHPD 9-25~82 GO Pressure Survey & BHPD 9~23-82 GO Pressure Survey. & BHPD 9-20-82 · GO 'Pressure Survey & BHPD 9-14~.82 Camco ' Pressure Survey 9.-9~82 Camco Pressure Survey & BHPD 10~8~82 GO Pressure Survey & BHPD 10-11~82 Camco Pressure Survey & BHPD 10~11-82 Camco . :4182) RECEIVED ,DATE Karen Mestas Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON 31 1 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 26S-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: SFO/UNIT/STATE: (-Marathon) EXXON GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmittal Only)_ Date: 10/6/82 Trans. #: 2703 55703 · CC#: REFERENCE: HID CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- A-12./ DDNLL, 7/27/82 A-14 --', DDNLL 8/10/82 A-15" Spinner 8/27/82 A-18-' Spinner 8/29/82 G-12~ DDNLL 7/20/82 G-13'-' DDNT,T, 7/23/82 M-15 -~ TDT-M 8/15/82 N-12~' DDNT,T, ' 7/30/82 N-12 --- Spinner 8/18/82 N-14 Spinner 8/16/82 N-14 DDNLL 8/3/82 N-15--' TDT-M, 8/14/82 R-7 J TDT-M 8/12/82 R-8-~ TDT-M 8/13/82 #1 Dres 8800-9714 5" #1 Dres 9300-10135 5" #1 GO 10600-11000 5" #1 GO 9900-10250 5" #1 Dres 9750-10686 5" ,#1 DRes 8600-9418 5" #1 Sch 8750-9596 5" #1 Dres 9200-9997 5" #1 GO' 9550'9800 5" #1 GO 94'59-9800 5" #1 Dres 9250-10146 ,, 5" #1 Sch 9300-10329 5" #1 Sch 9450-10426 5" ,#1' 'Sch 10850-11455 5'" ',/82) RECEIVED DATE ............................. .--' ............... 19 Victoria Aldridge Development Geology Well Records TP1-5 SOHIO ALASI;A PET;']OLEUM CO;'..':PANY SFO ARCO 311 1 "C" STR£ET ANCHORAGE, ALASKA TELEPHONE 1907l 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502. EXXON 1'0: PHI LLIP S CENTRAL FILES(CC#'s-Transmittal Only Date:. 9~29-87 Trans.#: 2676 CC#: 55676 REFERENCE: SOHIO MAGNETIC LIS TAPES & LISTINGS ~ , The following material is being submitted herewith.-Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- '" ' Tape Pos. OH/DIL/BHC/FDC/CNL/LDT/NGT #1,2 8/15/82. ACC 65510. SHOULD BE DESTROYED. A REPLACEMENT TAPE HAS BEEN ISSUED AND IS IN THIS' BATCH. OF TAPES. / *'* S-8 Sch ** THIS TAPE INCLUDED * - / Sch' OH/Replacement Tape 91,2 8/15/82 ACC 65510 01948 *~G-18/ Sch CH/TDT #1 9/11/82 ACC 65610 01942 ~'"E-17" Sch CH/TDT #1 9/10/82 ACC 65611 01943 *~B-6-~ Sch CH/TDT ., #'1 11/9/.78 'ACC 65576 01944 *'-E-11'~ Sch CH/TDT #1 8/6/82 ACC 65450 01945 *~--B-6-''~ Sch CH/TDT 94 9/2/82' ACC'65561 0'1946. *~M-15~' .Sch CH/TDT #1 8/15/82. ACC 65463 01'~47 *~R-7-~ Sch CH/TDT #1 8/12/82 ACC 6'5453 01949. *~-G-9-" Sch CH'/TDT ". 91 3/9/82 ACC 65~33 01950 RECEIVED #1 .. ~/27/82 ACC 65'370 01951 *~-R-3--- Sch CH/TDT .#2 8/6/82 ACC 65451 01952 * --R-8-- Sch CH/TDT #1 8/13/82 ACC 65452 01953 * -'=M-~6 Sch CH/TDT OCT 1 1982 ~ 9.1 8/31/82 ACC 65543 01954 *---S-9~ Sch CH/TDT 7/ ACC *---A-11~"'Sch CH/T. DT ~3B~a0i;& G~sC°"$'Ccl~s]i~zi('#i2 18/82 65424 01955 . Anch0ra~ .... ~1 7/31/82 ACC 65405 019.56 *~A-16'-'"Sch CH/TDT #1 7/26/82 ACC 65420 01957 *--'A-19'" Sch CH/TDT #1 . 8/28/82 ACC 65545 01958 *--A-25-- Sch 0H/DIL/BHC/FDC/CNL 91 8/18/82 ACC 65546 01959.. *,-~N-15/ Sch CH/TDT 9i 9/1~/82 ACC 65504' 01960 *SFO & EXXON: An A'sterisk:(*) next to a listing ab0~...e . means you should have received the Tape(s) and Listing(s) directly from the respective service company. confirm th~s~ --. ~,,~'/ ,~/). P 1 e.a s e .~~./,/j~,.,.~, ~ Development Geology OATE [ ~~~~ ,9 __ Well Records , SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHEVRON EXXON GETTY ~o: SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS BPAE (Transmittal Only) . 3111 "C"SIREET ANCHORAGE. ALASKA TELEPHONE 19071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Trans. cc,,: CENTRAL FILES (CC#'s - Transmittal Only) REFERENCE: ' 0 FINAL DATA - PRESSURE SURVEY DATA . The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to' this office:-- A'12/ Pressure Survey & BHPD A_iO/ ,, ,, A-ii/ " " A-16 ~" " " A-17/' " " B-16 '/ " " H-8 x' " '" j_.10.z' . ,, Y-6 '/' " " N-15" Pressure Survey R-3 "'"' " E-7."" Pressure Survey & BHPD '"M-15'/ Pressure Survey & BHPD' A-18 .'-' " '" M-16 ~°''' " " R_7/ ,, ,, R-8 '/ " " Y-11/' " " '7/25/82 7/31/82 7/24/82 7/24/82 7/28/82 7/27/82 814/82 8/13/82 8111182 8110182 8/6/82 7/23/82 8/13/82 8/14/82 8/15/82 8/7/82 8111182 7/27/82 Dr es. GO GO GO 'GO' GO GO Sch Sch Camco Camco Camco Camco Camco Camco ,2) RECEI'VED DATE 0it g' (~;;:n C,~r'!.?. n.. ....... Karen Mestas Anc~i0;'age~'~'''''"~[~ Development Geology ~s Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA · TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 August 17, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gent 1 emen: Wells A-18, A-19,'M-15,and M-16 PBU Enclosed, in duplicate, are the following forms for the above- named wells. e 3~ Form 10-407, Completion Report; Form 10-403, Sundry Notice and Reports on Wells; Form 10-404, Monthly Report of Drilling and Workovers. Y~ very truly, District. Field Engineer GJP/JLH/pj s Encl&sures cc: J.' D. Hartz Geology Well File #17 '~ STATE OF ALASKA (' /'i)/~ .... ALASKA(' ,L AND GAS CONSERVATION CO,~,MlSSlON WELL COMPLETION OR RECOMPLETION REPORT AND 1. Status of Well Classification of Service Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 81-85 3. Address 8. APl Number Pouch 6-612 Anchoraoe. Alaska 99502 50-029-2~612 4. Location of well at surface 9. Unit or Lease Name 1716' SNL, 606' WEL, Sec. 1, TllN, R12E, UPM Prudho~ R~v Unit At Top Producing ~nterva~ top of Sag R. SST. 10. Well Number 525' SNL, 593' WEL, Sec. 1, TllN, R12E, UPM M-15 (41-01-11-12) At Total Depth 11. Field and Pool 193' SNL, 491' WEL, Sec. 1, TllN, R12E, Up~ Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 51.76' AMSLI ADL 28260 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 8/6/81 8/22/81 8/28/81I feet MSLI one .17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 9657."MD 9309'TVD 9614'MD 9270'TVD YES ~ NO []I 1997 feetMD 1877' 22. Type Electric or Other Logs Run DIL/BHCS/SP/GR, FDC/CNL/GR/Cal, RFT., CBL, qyrosopic survey. 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED , 20"x30" rh.su.lated Conducto:- Surface 110' 36" 8 ~u.vd.~. ~ , 13 3/8" 72~ L-80 Surface 2665' 17 1/2" 3720 cu.ft. T~_rm~fro:~t IT . 9 5/8" 479 L-80 Szzrface .... 8845.'.' 1.2. 1/4- i202 ~u.ft". Clas'~ ~: .... ,. , 130 cu.ft. Permafro~' C 7" 26~ L-80 8349" 9657' 8 1/2" 396 cu.ft. Class Gw'i8% 24. Perforations open to Production (MD+TVD of Top and Bottom and... 25. TUBING RECORD .interval, size and number) ' ' "" [VID ...... ~V~ss - SIZE DEPTH SET ('MD) PACKER SET (MD) · ,.. Prudhoe Bay Oil Pool top:' 9166' . 8815' 4 1/2" 84~2' 8272' Bottom:.. 9250 ' 8890 '..' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9166' - 9198' :B:[~ (18815!, - 8844.'. ~/Dss) .... DEPTH INTERYAL (MD) AMOUNT& KINDOF MATERIAL UsED 9220,'~.-79250' BK~ (18863' _ 8890' ~v-DSs) '.- . ., , . · .. ,. 27. PRODUCTION TEST . Date .F~rst.Production . . .. .] Method of. Operation (Fl°wl..n,g, gas.lift, etq..) ..... August 1, 1982I' Flowing ' ' .... " ' ",, .... ,. , '" ' Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-'Mcl~' ' 'WA'r:ER-BBL CHOKE SIZE I GAS-OIL RATI6 ', ,. ,. TEST, PERIOD I~ :. '.. ', I . · , , Flow Tub!ng Casing Pressure, ' . CALCU,,LATED OIL-BBL... GAS-MCF wATER-BBL OIL GRAVITY-ApI"(corr) · Press.. ,.. 2~-HOUR RATE I~ ' . . 28. CORE DATA . ~. Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. .... None ": '. '.'. ", ...... AUG 2 0 1982 Ahska Oil & Gas Cons. Commissio~ ,., :. ' ... :, .. .. .,, ... :: ...... ... Anch0rag~ . ,. · .,. ,.. , ., Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. NAME Sag River SST. Shublik Ivishak GEOLOGIC MARKERS MEAS. DEPTH 8853' 8897' 8997' TRUE VERT. DEPTH Subsea 8532' 8572' 8662 ' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase, 31. LIST OF ATTACHMENTS 32. ~ t,,~C,ferego~,g~ ,is true and correct to the best of my knowledge I herebycertif tgatth ' t t., .. . ,.)/ -L....G ....... ', i ,a U ........ : ................ ~--r.. Engineer 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 well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 ALASKA IL AND GAS CONSERVATION C ,MISSION SUNDRY NOTICES AND REPORTS ON WELLS I 1. DRILLING WELL [] COMPLETED WELL I~ OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-85 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20612 4. Location of Well 9. Unit or Lease Name At Surface: Prudhoe Bay Unit 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM 10. Well Number M-15 (41-01-11-12) 11. Field and Pool Prudhoe Bay S. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool _ KBE = 51.76' AMSL ADL 2826~ 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completior~.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals were perforated August 1, 1982 using Schlumberger 2 7/8" hyperdome guns at .4 spf. A lubricator was 'installed and tested to 4000 psi on all well work. 9166' -9198' BKB (Ref. BHCS/GR, 8/22/81) 9220' - 9250' BKB (' " ) An SSSV was set and' tested in the BVN at 1997'. ~ ..,!?'~'" ,~ . AUG 2 1981 14, I he tify oing is true and correct to the best of my knowledge. Signed /f~' '~r~..~_ J , .~,.,~ ~ Title District Field Engineer Date ~/~~ The spa~r,e below fc~,_~omm issio~ use U Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ' , STATE OF ALASKA AL/~SKA (.,- AND GAS CONSERVATION C~' .MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ,,4' 1. Drilling well [] Workover operation [] r~ 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 81-85 3. Address 8, APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20612 4. Location of Well at surface 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, OPM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 51.76' AMSL ADL 28260 9. Unit or Lease Name Prudhoe Bay Unit. 10. Well No. M-15 (41-01-11-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of August ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests '14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data See Attachment AUG 2 A,!;.~.sk9 Oil & Ga~:~ Cons. Commission her fy ng is true and correct to the best of my knowledge. NOTE--~ort on ~orm is require~or each calendar mOnth, regardless of the status of operations, andmust be fi /in ~cate with ~he Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate PERFORATING DATA - Well M-15 (41-01-11-12) July 31, 1981: August 1, 1982: August 11, 1982: August 13, 1982: August 14, 1982: Pressure tested tubing and inner annulus. Rigged up Schlumberger and perforated the following intervals using 2 7/8" carrier guns at 4 spf: 9166' - 9198' BKB (Ref. BHCS/GR, 8/22/81) 9220' - 9250' BKB ( " ) Put well on production. Shut well in to prepare for static pressure survey. Ran static pressure/temperature survey at 8800' TVDss. Set and tested SSSV in ball valve nipple at 1997'. Well. on production. AUG 2 A!aska Oil & Gas Cons. .ailchorag~ SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 1~, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V..Chatterton WELLS R-8, Y-10, Y-13, A-!5, A-18, A-19, E-10, E-15, E-17, E-18, E-20, E-21, G-18, Mml5., M-16, M-17 Gent lemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. This contains' our ~o~o~a~ ~o ~o~a~ ~ w~s~'~ . . · . · Engineer GJP:JLH:ybr Enclosnres cc: J.D. Hartz Geology Well File #17 '" (' STATE OF ALASKA "' ALASKA OIL AND GAS CONSERVATION C(~,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS I 1. DRILLING WELL~ COMPLETED WELL [] OTHER [] ' 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 81-85 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20612 4. Location of Well 9. Unit or Lease Name At surface: Prudhoe Bay Unit 1716' SNL, 606' WEL, Sec. 01, TllN, R12E, UPM lO. Well Number- M-15 (41-01-11-12) 11. Field and Pool Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool _ KBE = 51.76' AMSLI ADL 28260 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ' NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] ". Perforations [] Altering Casing [~] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] RePairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly State all pertinent details and give pertinent dates, including estimated date-of starting anY"' proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated during July/August 1982 using Schlumberger 2 7/8" Hyperdome guns at 4 spf. A lubricator will be installed and tested to 3500 psi on all well work. 9166' -9198' BKB (Ref. BHCS/GR, 8/22/81) 9220' -9250' BKB (Ref. BHCS/GR, 8/22/81) · An SSSV will be set and tested in the ball valve nipple ca. 2000'. Subsequent Worl~ Ptepm~ed .ii.ti O' :P" '~.' :",',~'~ ' ' . ....... : . .,;...~', u. (";i~ &. L~;~'.~ .'..,o~'~S. .'"..,'?~:.~:~v;~:.~.; fYi, /'t ]~ is true and correct to the best of my knowledge. 14. I hereby Signed ~q,~~,[,~/~ ' Title.District Field Engineer Date Thespal~belowfo~mission us; ~.~J. Plis§a I -' ' "' " , Conditions of Approval, if any: A~provecl Copy k ~turned f,, '", I/ ~,1 ' IHI ~ I ' Approved by '~ COMMISSIONER· the Commission Date · Form 10403 Rev. 7-1-80 Submit "lntentions"'irt Triplicate and "Subsequent Reports" irt Duplicate SOHIO ALASKA PETROLEUM COMPANY September 17, 1981 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Ccmmission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well M-15 (41-01-11-12) Enclosed, in duplicate, is Form 10-407, ~letion Report, for the above-namedwell together with the Well History, Well Logs, and Directional Surveys. This well has been suspended pending perforating operations. Yours very truly, RHR:ja Enclosures cc: Well File 917 Geology R. H. Reiley District Drilling Engineer RECEIVED SEP 1 8 1981 Alaska 0il & Gas Cons, Commission Anchorage · STATE OF ALASKA 0 R I G I ~ ~ [ ' ALASKA ~'~',.._ AN D GAS CONSERVATION COl.....~ISSION 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 Sohio Alaska Petroleum ODmpany 81-85 3. Address 8. APl Number Pouch 6-612, Anc---horaqe, Alaska 99502 50~]29-20612 4. Location of well at surface -~CAT~OF4S 9. Unit or Lease Name 1716' SNL, 606' WEL, Sec. 1, TllN, R12E, UPM yF;','IF;9D Prudhoe Bay Unit At Top Producing Interval top of Sag R. SST. Surf..~____~__________~_- 10. Well Number 525' sh-~, 593' WEb, Sec. 1, T11N, Z~12~., ~ .s.~.~ N-15 (41-01-11-12) At Total Depth -_ , -- 11. Fiel~l a'nd Pool 193' SNL, 491' WEL, Sec. 1, TllN, R12E, UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 51.76' AMSL ADL 28260 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 8/6/81 8/22/81 8/28/81I feet MSLI one 17. Total Depth (MD+TVD) 18.PlugBackDepth(MD+TvD) 19. DirectionalSurvey I 20. Depth where SSSV set [ 21.Thickness of Permafrost 9657'MD 9309'TVD 9614'MD 9270'TVD YES ~ NO [] 1997 feet MD 1877' 22. Type Electric or Other Logs Run . DIL/BHCS/SP/GR, FDC/CNL/GR/Cal, RPT, CBL, gyroscopic survey 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insu!at~ Co_nd_ucto:' Surface 110' 36" 8 cu.yds, concrete 13 3/8" 729 L-80 Surface 2665' 17 1/2" 3720. cu.ft. Permafr¢,st II 9 5/8" 479 L-80 Surface 8845' 12 1/4" 1202 . cu. ft. Class G;. 130 cu. ft. Permafr¢,st C 7" 269 L-80 8349' 9657' 8 1/2" 396 cu. ft. Class G w/18% salt 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) 4 1/2" 8412' R272' None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. " .. '. DEPTH I. NTERVAL(MD) AMOUNT & KIND OF MATERIAL USED . .. . · . ,, . : 27. PRODUCTION '~EST ~Date First P~'6duction ' "' I MethOd of Operatio.n (Flowing, gas lift, etc.) I Date of Te'st Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO :':' " .... TEST.PERIOD I ; ' :~1;3w Tubing.'" Casing Pressure ~ CALCULATED OIL-BBL ~AS-MCF WATER-BBL OIL GRAVITY-APl (corr) ":Pres;.' " · . 24-HOUR RATE I~. ' ' · . 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dip.~ and presence of oil, gas or water. Submit core chips. " '"' '" "' -,' l tEIv . · . .. ,. . ., . . ,, ., .' '-'" SEP 1 8 198 , ?., , , Alaska Oil & Gas Cons. Com~issio~ '" · ..... .. , , Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Sag River SST. Shublik Ivishak GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH BKB Subsea I 8853' 8532' 8897' 8572' 8662' 30. 8997' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 31. LIST OF ATTACHMENTS Well Histg..r~fz Well L~s, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title District Drillinq Date ... Enqlneer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 (' WELL M-15 (41-01-11-12) WELL HISTORY Spudded well at 1800 hours, AugUst 6, 1981. Drilled 17 1/2" hole to 2665'. Ran 69 jts. 13 3/8" 729 L-80 Buttress casing to 2665'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2623'; tested-casing.to 3000 psi, okay. Drilled out to 2704', ran leak-off test to 0.67 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8880'. Ran 231 jts. 9 5/8" 479 L-80 Buttress casing to 8845'. Cemented in two stages: First stage with 1202 cu. ft. Class G cement; second stage through D.V. packer at 2562' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out D.V.; tested casing to 3000 psi, okay. Cleaned OUt float equipment and directionally drilled 8 1/2" hole to 9657'.. Ran open hole logs. Ran 33 jts. 7" 269 L-80 IJ4S liner to 9657'. Cemented with 396 cu. ft. Class G cement. Cleaned out to 9614', 'tested casing to 3000 psi, okay. Tested 7": liner lap to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 202 its. 4 1/2" 12.69 L-80 A/B mod. Buttress IPC tubing to 8412'. Landed tubing' with ball valve at 1997'. Installed and tested tree. Displaced tubing to diesel.; set packer at 8272'. Tested tubing to 3500 psi, okay. Released rig at 1200 hours', August 28, 1981. SEP 1 8 ]981 Alaska Oil & Gas Cons. Commisslon ,/~chorage ,{' Controlled Dr ling Consultants ,. ,. P,O. BOX 1189 PALMER, ALASKA. 99645 I" '. ... .: . . . PHONE 376-5423 ' ' "' ' " ' ,.' , . . , ,. ,,, , .,. ,.; ...':,. :".~',., ,. '.,' ' ' ' ' " ' ':' ' ' '" "~ "' ""' ';' ~ ' '" ':'i" ":'5"'::':'""" ' ,.. · . .. . . . . , ,:..:,:.: ,:~..:.,,:.., :. ~, .,.,~ .-.,-..'.......~,:.:,,...i:':-,.k..,,~ ,. :., ...,.. ,, · · .... '.' · ' : · . .' :,.': .'.:.> "'.'.~":" ":i:'."'.:'",;':i:.-.:'"'..' . .'..i.. · . ,' . . . ..... ,,. ... . ' . ;, . .,,: ...: .. ,. ~..~li~L~ll~,.'., .,.,.,.~ %~.]~:,'~.,¢ ;,:;' :.,' ~ ' · : ', ' .....~ , .' · '..'. , '.' , · I. ,V '' ";'"~ '.~ ~' ..-" ~ ...... "· .... 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" ' ,.-. ,.,~ . ,' ,. ,',' '.~' ' :', . ,' ,' · ..'.'.'' .', ' '. ':"..'.....,''~-, .... ', '...';.h'>. :. '.' '~2.'~,'!~,'',,4.:.. " ':', , ',' , ,.'~ :., ..; 't..~ ,,', .v,..,' ,.' 'i: ', ,'.",' f' ,'¥..,~..-: ',' ':"~ ".' " . . "., '~ ? ". :.' ' ~ ' ' , ' ' ,'."% ':."q ;..,' ~ "':~, ,'~'t.,:',M ~ ',"i; ~";'" ' ' '" : , , ..,,, ,. .. . ,.,. ~ .... ;.,. ",',.".. ·.. -.-. ,',.,~-,;,~..,.~,.~ .~.*.~,,' ,',,.. .' ,. ". ,:' ' ' . . .'.'. ,',,.' ".'.'. '.. ,.. '." .:..., :...f., :....,L...'",.','* .-...'.~',..:!'.;.,',,,..:..,!>.~..;......:.-'., .':.' . ...: . ' ,-'. .... ' ~ , . .. ,'. , ' . ,, . ' ',,.', ,' ;,,, "'. ~ .* ,¥ ,;'.. ~'~.. L.,'q .... . '. ,..'" ' ' ' ',' ' "': , . . '" '" '. '. ';'. . 4',',',~'~ '(~'".'),".c.' :,,,:,..~ ,,..., i , . COMPLETION REPORT · .%GH.LG_ALA SIC~L P. E_T_R O t-_ t4AGNET]C SZNGLE SHOT SURVEY RADIUS OF CURVATURE METHOD OF COHPUTATZON COMPUTED Fc~.__CD~'.._,B.Y = FM 28 AUG. 81 WELL_,M-1.5 K, B ELEV .51.76 'RECORD OF SURVEY ~ . :,..: .~. · . :., at ." ~ ' ~, . .. · MEAS. DRIFT VERTICAL ", ..... 'SUB !~.*?*.:."~;DRIFT . T_0__T_.A_L COORO.ZNA_T.E$ DEPTH ANGLE DEPTH .SEA DIREC D M DEG, .'. , .. C,_..L,--0~_~_U_R_E_& DISTANCE ANGLE D M S DOG LEG SEVERITY ..... DEG//OOFT DI~STANCE . 0 0 0 0,00 -5'1,7& S O*OOE OeO0 S 0,00 W '0,00 S 0 0 0 W 0*000 0o00 ASSUMED VERTICAL,TO ~O. .' .'::::,".': ....... '!..:::...':'.':'~'...: ..... ' ... 5300 0 0 5300,00 .52~8,2~ S O,OOE' 0,00 S 'o,0o w 0ko0 $ 0 0 0 w 0,000 0.00 ' S~04.~ 0 ~0. ~_~0__~99...,~.~.~..2.S:.: ~1.7..~E:.. 0.~__.$ ............. O..,06....E ...... '.O.~_~.8_.~..~_Pg_.E ,.0...~81 ............ ~0,.~_ ~.".:~5511 I 45 5510.97. 545g,2~ $86..50~:.~-...'.. ~e94 S 0.96 ~ 2.17 $ 26 ~8 52 ~ i1.172 -1.98 ?""~603 5 '0 5602,80 '5551eO~!!~'.i':;'...N71,50~:::?':'":.iZ,2~ S 6,30 W ':..." 6,~2 S 78 ~8 1W . ~,537 '~_5665 . 7 ~.0 ..... 5.~6~.~3 ..561~7.'"..N6.~0~'.'.:'.':" ' ~.~_~ ......... ~2.~66_..W 12.70 N' 85 27 37 W ~.033 0.50 5T2T 10 15 5725.68 5673..92 NG~.00~ ~,TT N 21~ ~ ' 21,97,N 77'26 12 ~ a.~ 3.93'-- .. 5820 13 45 5816,63 5764,87 N51,50~ 15,07 N 37,76 W '.- .40,66 .~ 68 14 19 W .3,839 ..... 595g.1~ O. 5951,58 ..... 5~8~0_,..0.0~ ....... ~..__.~0..,_~ ..... 59.,.39__~ ..... ". ......... ..71.,.~.0.~.~__~..~~~ ....... 0,923 "608~ ~8 0 6071,7~ 60Zg*95:':~;."N2~eSON'.'"'.~'..' 70,79 N' ' ' 75,~6 ~ "~:'"';.".Z03,25 N ~6 ~2 ~ N . :3*227 67,78 '"6213 22 '0 6~92.,90' 6'1~X'1~':~;:~'~?N2'3'eSOW'-;?.~"?111,OS'N' 93,~0'N ".?'.'.'~,9~ N 39'57 58 ~' 3,~03 ;~'&a&7 2] ~0 ' '&~27,1~ ' ..6375,387::.;;~?N...~.2,~'50~O..6~25~lS..e.O.7_~~.6e..Z8~_Z9 ' 9~.e_W.....Z.e~Z_~g01 7010 20 30 6930,5k 6878,T8 N ~,50~ ~09,52 N ~22,17 N ~27,35 N ~6 36 &l ~ :0,553 ~0~,~0 7391 23 0 728k,39 7232,63 N 6,50E 550,~ N ~6,02 ~ .562,53 N ~ 5~ 8 ~ 0,730 5~5,~6 ..8088 29 0 79~1,78' 7860,02.'"'..N2.0,OOE ' '8k5,32 N 50,~0 ~ ..S&6'e81. N 3 23 30 ~. '~,~2 ".'8638 28. 0' B395,~3. '83~,~T'.~:'N21,SOE'"":'.1090,73'N ~2,87 E .'"~09~,57 N*' 2 ~5 3 ~. '0,~9~ ~09~,57 .. .,....~ .. . , SOHIO ~IELL M-1.5 SINGLE SHOT SURVEY __M~ASURE~ ~£P T H_~T_HER_DA~EvERY_EV E N. _100 28 AUG, 81 TRUE HEASURED VERTZCAL SUB MD-TVD VERTZCAL DEPTH DEPTH SEA DZFFERENCE CORRECTZON TOTAL COORDINATES 152 152, 100 0 0 0,00 & 0,00 14 :~_~2 252.e .. 20.0. .. o 0 O_,O0_.,S 0.,.00__.~ ~'... 352 .. 352, .300 0 0 0,00 6 0,00 W i:':.'.:: 452 4.52, .4.00 '0 0 0.00 `5 0,00 14 ~.:.:' . 552 5,~.~._, ' :i ."' 500 · ' ..... "0 . .0___ · O_,.O0,_,S 0_,.0.0_14. 652 652, 600 0 0 0,00 ,5 0,00 14 752 752, 700 0 0 0,00 _ asp_ R52., sOO o 0 0., O0._,,S ~,... . .. ;.:._: .... .-~ .- . . =- . . , i.:~ ....... · .... 952. .....:...: ,i '952,...,~ :"900.' .'. 0': .... · 0 " ','0,00 ?':":~'""'" .' 1052 '* 1052,'''':!'. ':.::''' ~: '1.000"":'"':~":L/':.~:O'" ".:" ' '0 '. "' '" 0,00 ~:: ., ,: · .. . :?..'. 11r~_ · ' ..... 1152,, '""" 110~ :~.i ~"0 .. ' 0 , O.e..O0._~ O_e.OO_W . 1252 1.252, '1.200 0" 0 0,00 1.352 1352, 1.300 0 0 0,00 ~ ..... ...~ ...... ! ~5 ~_ ..~ ~ .~.SZ, ~_ .~ 1~00 . : o ' __ 0 .......... O.,..O.Q_,5 O..,_O.O._W ""..::'":iii:/."i '';' ?' :' '.' ' ''::' ':' , ' :'.' ?~.,,~'.'. 3.652 i' "1.652,,.:?ii!i?:??i.,1..'600';.i~?'.0:'?'?:~[:..ii'~:!i,:...:.....'..' 0 · :"'""0 O0 S'' 0.00 14 " .3,752 ~ ..... .,......,,.: . .~ :.~.,~.:..:~ . .~:.~.,~..~..,:~:.~!!..,.:i...... ,:.....:::.......~,. ..... .,. '::..' . ': · ' .. !752,'.!"'i?.!:'1 ?(10'?~'!:~'?..~.?:,'~??,i. 0 ;.:;".!?_:::':'_._:' :". · ":" ..... O__: ....;- .'~-..-'"';"' ' "LO..e.O0_,S O.,_O0_W' 1852 1852, 1.800 0 0 , 0,00 · 1952 1952e 1'900 0" 0 .. 0.,00 2052 ' 20 52 ,_.....~.0 ... 0 ............. 0 0.,.0.0.._$_ . ..... 0..,_0,0_.~ " ,.:,.' a25 a..5 :2.2 ., ~' - · i"2~52 "'.':'"":'".::"-ii:'."'?'i~!i;::'2352'e:':~""i"'!"?.23.0-0:I'I'.':I'??:'~:':'0 '.".'" ?"'? ' " "' :'; '"' :::':" '"~""'""' 0 .... ' ""' ' :.':":-':"O,o0.__.S . 0_..0.0,__~ _ ' 24,52 2~52~ 2400 0 0 0,00 S 0,00 2552 2552, 2500 0 0 0,00 !::- i :.i:: ....... . .............. : .... ,...-. -.,:.,: ~..~.; ........... ;... ,...:.. ,. ..... .-: ..- ,..-. .............. . ..... .':.. 2752 . '.".'.'.':.'".'.2752, "2700."~""'";":?'"'.' 0 '"'"" '". '.' "':"'. 0 '.'. 0,00 `5 0,00 14 ;'. ':'".; 2852 ..' '~ .:.iiii..:.:....! 2852, .... ' 28 O0 .~.i...:....~.. 0 '..i. ..~....:: '.. ! .;.... .. :. '. '. . " 2952 "'"!:'"i ~.9_,52,_e ?..,9.0.0~.0 ' ::'.'"' ." '"' "' ':O__ ... ".i~ '0_,.00.._,5 'O..~.O.O._W ..... I 3052 3052, 3000 .0 0 0,00 31.52 315;~* 3100 0 0 0,00 S 0,00 _:~25'2 .... :. =. ~ ~,5. 2 ,___.t200_...;: 3352 .. ':'..3352, 3300 '. 0. 0 0,00 . .. . 3452 '. .34.52,'" 3~00 0'. 0 " 0,00 _..... :~5~2 ~.5.52.~_._......35.Q 0 SOI. IIO WELL M-15 SINGLE .SHOT, .SURVEY ,. ~£ASUREI~ _rtEP_.TH_~ND_O_THE_R DATA FOR Ev£RYEVEN__iOO_EEETOF_.SUB__~EA_DEP__Tj.j, 28 AUG, 81 TRUE MEASURED VERT ! CAL 'SUB HD'TVD VERT Z'CAL DEPTH DEPTH 'SEA DZFFERENCE CORRECT!ON TOTAL COORD!NATES 3652 3852 3952 "___~E~?'_._ '* 4152 4252 4452 "'""' 4552 4752 ~':,, 4852 3652e 3852, -'.' .... 3952, ..... !.'-'~.~('~05~, .. 4152, 4252, · .__.4352~ . 3600 0 3800 0 3900 0 .:. 4100 ..'0 4200 fO~ .4~QO .......... 0~. ........ 0 O_ 0 0 0 0 0 0,00 .5 0,00 N ,. 0.,_00_.5 ___Q,.QO_~ 0,00 .5 0,00 W '.0,00 ...5 ' 0,00 0 ~LO.O '--,S--_~O_.,.O.O__W. 0,00 .5' 0,00 W 0,00 .5. 0,00 W .. O.,_O0_S_' .... O.,.OO.- W, "'"""'" " ""0,00 '".$ "' '.' O,OO W -.."' '":":'"'.'0,00' .5 ' ":.' ". 0,00' ~ " :"('O,_.O.O_~ i_._, . . "0_o.0.0_:_~ 0,00 S 0,00 W 4800 5452 . '.,.:. :.'. ,~5452, . 5400 , 0 ' '. ' .: 0 sss2,. ,:ii,5 sz, .'5 _o.o .: .... 'o ' o z ' ....... '"'"".' "": ,' .5'7.54 ..... ...,~.'.:,;'.;~.~'.;:;? · ..,..',,..' .~ '. '....'....,.::~.;.:.:;:?:...:...~......'~,,r.~..:...~.... ':. :. ..... .... .... ..,~'~,,.,~'.'.:~,:.~..,.,~5752 ~,.'.~,'..,,~, ~.5.7.00 ...' ~,.,~.:'..:..:~.~,2.~.::'~..'.,?-,'~ ....... ' ' .': '...,~- :'.,.'". 2 58.56 C.'.' "''::''~' ':~ ''''~'~''' '':'¥ :" ' ' "" ': ""' ":": '"" ''''~ "'" '"'""';'" :"'""' ":' ~.ii .'Y ...:'.... ' ':'.: "' -' ..... ",'.'.,'.'.,:.'.~ .~..;,".'"',~".5852, :'~ ""5 ':....,..r,~...~ .:.,'..,..~?....:..,. ...... :........ ... .............................. ~.,.. ,8.~4~....~..,:.,,,,. ........ -., .'. '. ..... "."'.", '.~" '., 2. 5959 ., ".'" · '. ,5952e, . ' 5900 ,. i , , ~. 6063 · :,~.;!,~ ...-". 6)69 .... """' "~ ,, .? 't.i 6'27.7 :'"'":"':'"'"'. ,.~..,";'" ~...'~' ":,' :'. 63.8 5 t.'-~ ' ,. · ' ' 649~ .- 6603 . 6711' ...... 68!8 6926 '..,' ....... 7140. ..... :"' ...'7. ' 3 ":'"~':'"~ .6052* 6000 '. '.11 4 :".'".,',.." .:6152, 6100_ . ' ;17 . . . '.:':.: .':.i",:~::~ ::~; "' . : ~'";...'"' ,'. ' .'.' i'.i;.(,.:~'~'":':k ' .["'".!~,.['f[~!i:;";:L:.:';':'i:..~...': . .".."...":...:." '::,~! ....~' ~'....". 'i ,;.. ,6.352 ·'... ,.~':. ..... .'..' 6:300.".'.~ ..,,',~;;...',,:.33 ;.!."~:~.' :~..::,...:.: ~. ~,:.. .':. ;.:"'. :' ..?', '........:....'. '"' "~ .'i.' 6q..~ ,'"... 6400 '.'"'~/".'..'~42 :?"?.:.'.:~"..;!'.'.'.'." .'. 6552, ' 6500 51,' , 9 6652. 6600. 59 8 .6752,_. .... 6.?00: . '66 7.__ 6852. 6800 7/+ '" 8 ' . 6952, .,' .6900 ':~'"....'81.' .... :'":' ' ' ... 7 ' .,70~2,.j,[ i' .7000, '..i .... 8_8 "" :'": . '...' ,., .7.. 40,1,7 .N ' '59,39 65,08 N 72,35 96_*.5.~_.N...'.~__ 86_*..~.5_W. 1'33'58'.N:"~..v.. 101,45 .'. 1,74',25 ..N "'." 1,1,l,O't ..~L6....e.~_!_N _'_ ~1_!..5_,~_~ 259,45 N 1`16,81 300,77 N 118,00 . .. 379,77 N .. 1.19,85 .... 417,48 N':' SOHIO ~IEI~. H-15 SIN6I,E SHOT SUR~f 28 AUGe 81 _MEASLIREI~ r~EI~_TH__~U~ID_D.T~~~~LF.~LY_EV. EN._I.O.O_. EEE.T_OF__SUB_SI:.A_DEP_TJ-I., TRU£ HEASURED VERT I CAI.. SUB MD-TVD VERT I CAI. DEPTH DEPTH SEA DIFFERENCE CORRECTION . , TOTAL' COORDINATES T2~7 ~ .... 7~56 ,." 7464 .... 757~ 7795 7907 .'~':... 813k ::,;'4 '.. 82~8 .,.[,. ' '...~ ,~" .. ' 8~T~ 8589 7852 "7952 8052 · 8152 8252 8352 7152, 7100 95 ?252L..__Y.2~O . ~0~ '7352, 7300 112' '. 7452~ ~7400. i.:.122'-'".:..' 7652, 7600 142 7752, 7700 ,. ? 9 O0 "~'"'?/!;.~i::': 182~ ?'...: i('..:... :'; ' .' '. ':: :"'.' 8ooo':i';~f'!::i!!ii!!'~ 9 6",,:::i?';:"'""'"":'. .... .. '. "'. ~ 4.." 8200 223 8300 237 7 9 8 10 10 15...'. 495,64 N 120,38 ~_6_,_'7.6_J~j 579~ 09 N 112,73 623.29 N 106,6z~ __6_68_t_6_e_N. · ... 715,~49 N 88.60 764.25 N 76, ~'8 81/*.,_6.6.._.~. ' 61 ' 866,10 'N .' ,";' 917'73. N " 23.53 1019,46 N 1~.49 , 1.069.56 N 33.5,3 SOHIO blELL M-15 SINGLE SHOT SURVEY Z8 AUG~ 8~ T.F[UE. MEASURED VERT ! CAL SUB DEPTH DEPTH SEA TOTAL. COORD Z'NATES 1000 lO00e 948, 2000 20008 19/+88 4000 ~O00e 3948~ 5000 5000~ ,. ~9~8, 6000 5~_~,_ '~ 5939, 7000 6921~ 6869~ 8000 783~ 7782, 0,00 S 0,00 0800 S 0,00 . , .OsO0_S ..... 0,0.0_.~ 0800 S 0800 .. 0,00 S 0800 ,',, 49~2.~__N .... 6~,4Z._W 406,06 N 120833 805865 N 64826 ~..~ , . , ,.: . , , ~ .. L.'~[.]. T' ........ , . ', : . , - _ I .--, . . ~ !, September 3, 1981 Mr. Gary Plisga Sohio Alaska Petroleum Company 3111C. Street Anchorage, Alaska 99502 Re: Our Boss Gyroscopic Survey Job No. Boss-16882 Well No. M-15 (SEC1TllN R12E) Prudhoe Bay Field North Slope, Alaska Date of Survey: September 1, 1981 Operator: Blaine Baertsch Dear Mr. Plisga: Please find enclosed the "Original" and seventeen (17) copies of our Boss Gyroscopic Multishot Directional Survey on the_above well. Thank you for giving Us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Ken Broussard District Manager KB/pr Enclosures CONFIDEIVTIAL STATE OF ALASKA _ . 8 SPERRY-SUN WELL SURVEYING COMPANY ................ ANCHORAOE_ALASKA_. SOHIO ALASKA PETROLEUM coMPANY' WELL NO. M-15 ¢$EC 01TllN R12E) COMPUTATION DATE PRUDHOE BAy ................................. SEP_~._2, .....1981 .... ALASKA ..... · .. ........................... TRui~ .................. SUB-SEA ............ MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 0.00 -51.76 100 100.00 48.24 200 200.00 148.24 300 300.00 248.24 400 ..... 399.99 ......... 348.23 500 49~.99 448.23 600" 599.99 548.23 700 ........... 699,9.9 ............. 648.23 800 799.99 748.23 PAGE I DATE OF SURVEY SEPT. 1, 1981 BOSS GYROSCOPIC SURVEY OOB._NUMBER_BOSS=16882__ KELLY BUSHING ELEV..= 51.76 FT. OPERATOR- BLAINE. BAERTSCH COU SE ........ INCLINATION DIRECTION SEVERITY RECTANGULAR · DES_._. M..IN ........ DEGREES ............ DEG/..IOO NORIH./_SOUT_H 0 ":0.... .N O. 0 W 0.00' :.::...:' ' :' 0 00' .......... _0 '"" 1_3. i..... S.-..:~'1._4:..69.. E ~0.._2.3; ?:':....'/' . 0 24 0 15 N 34.&9 W 0.64 0.90 S ..0__27. ....... _S ....... 1 ...... 0 E ................... 0...69 ' 1.. 1.1_S ......... ' 0 :.. 27..........'...:i::' 0 .":i'i'::'.15::..'i'./:...:"/.:.;'::.'i!S'::67. 0 E ." "" 0~'23'"i?::':':i:'?:!!:'::':''':''':''' 2.12 8 0 ':' 24"':.?:'.".s ',eo.-...o_.E.- ..... 0 18 N 50.39 W 0.32 2.15 S TOTAL COORDINATES . E~S_TZWES_T O. 00'.. ' '" '_O_._0.5,E ".:.':"' 0.14 E 0.05 E .... O...PS__W .. .i.:.':...:.i ~0,'23"..:'E' ' ',: z21.?, E :' .... : ::~..'-'.:~"':!;:~::.;:1!.;~ .~.~E:~':.I :'::'" 1.84 E VERTICAJ''I' ' ..... - _SECTION ..... O. O0 -.0.._1.9_ ....... -0.72 -0.89 -1 .... 11 ....... -1.75 -2.06 =2..16 .............. -2.01 900 899.98 848. 1000 ............ 999...98 ........... 94.8. 1100 1099.98. 1048. 1200 1199.98.'. 1148. 1300 .............. 1299.97 .......... i ....... 1248. 1400 1399.97 1348. 1500 1499.97 1448. 1600 ............. 1599, 96 ............ 1548.20 ............ 0 ...... ,.43 ......... S_40.,.6~_,E ......... 1_...1..4... 1700 1699.95 1800 ' 1799.95 1900 ........ i' L. 1899, 95 22 0 21 S 23.89 E 0.53 2.26 S 2.17 E 22 .............. 0 ...... 18 ....... N _56.10. W ................ 0...51 ................... 2..39....S ...................... 2..52_E. 22 ' 0... '9 .:. ':.'.'.;.S.25.39 E ' 0.,':37..;::"...' 2.36 S "..::.:.. "'.: 2.80:ii.E.':::....'.' . 22 0...'~."47.'??!'.'N':;:. 8.30 W .' . '. '.'/ '":'"i :' 0'i:.93.:.:':..':' .:.' . 1.81 S'":i'""i.'::."ii.:':::/:: 2..'V&:'~:E..~'i::.:'.:?'.. 21 ........... * O-'~:'_..i.3'"-":~:.i'!,'~N'.::);~'i.-'.:'l-.'_80_W~ ':. i: ::'i:'ii:~':i.'i'.:':~0~!(~58:"~.':?":~-'~- .... 0..93 :_S:~.!:'. :'iJL?!-'''.': ./?:i-3'D5 ii'i=Ei'.: ~:..'.'. - ' 21 0 3 N 22. I'9 W 0.18 0.70 S 3.06 E 21 0 40 N 29.39 W 0.62 0.15 $ 3.37 E -2.09 =2.19 .......... -2.15 -0.47 0.10 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 '.. 1648.19 " 0 :'.':33 ..'.:~..:."..':'..'":S...60.'SO .E :":' 1748.19 ' 0':'.i:.."'i'36':'::~:,i:;':'~i':~::~:?S':.:i;~?'&6~:~..10.: E":"::~:?.i!:'!.'i!i:,?.!O~?08 :'.'/ ' .i...:~i ....... 1848,19 ....................... ' :.'..." 1999.94 1948.18 0 34 N 25.69 W 0.41 0.86 S 7.05 E .2099.94 2048.18 0 27 N 32.10 W 0.1 ..... 21.9.9, 93 ....... 21.48..17 ........................ 0 .... 3% .......N_.&.O..._I_O__W ........0._31 ......... 0.,..54__N_ 8.,..1~_E____ 2299.93 .' . 2248.17 . .0 . ' 33:1":.,'~:,.:::./.N ':51, .19 W .'...i .?::::.; ':..:.:....~';;.':0;.;:13 ?;!;:i../.;i:: .; ..:..:'.':-:" .1...1'1 "':.N ':,. '.... '.:..i.;'.-;.'~:.'.9,.02...E" "' "" 2399.92 .. 2348..16 ' 0.'"... '311'.:::":'? ........... 2499,.92 ............ 2448....161 ............ ~. ................. _0 ' ~:'"~: 8 :'.'::':".' '"::.:' N'"'$ I~ 39' ::' ~ :.:i:i.. :i'. 'i:::"::/'..i.:::?':.:i.':.,0.~i...40 2'~.:..i~:..!..N:::i':?"";:':'.:..? "':'-'.1'0 i'1.0--E" · 2599.92 2548.16 0 12 S 30.80 E 0.25 2.08 N ........ 10.30 E 2699.92 2648.16 0 5 S 53.10 W 0.22 1.87 N 10.33 E 2799.92 2748.,16 0 .... 20 2899.92 2848.16 0 30 2999.91 2948.15 0 20 -0,84 -0.33 O. 49 ..... I_..15 ........... 1.79 2.49 ____.2..93 .............. 2.85 2.64 .......... N... 11.60 W ................ 0..3~. ................. 2..12...N ............... 10.21 E ............... 2.88 ....... N 22.69 W 0.19 2.82 N 9.98 E 3.56 N 8.60 W 0.28 " 3.52 N 9..85 E 4.25 .. MEASURED DEPTH 3100 3200 3300 3400 SPERRY-SUN WELL SURVEYING COMPANY'.".. PAGE 2 ~OHI0 ALAeKA' P~ROLEUM COMPANY ..................... ANCHORAOE_ALA$~. . DATE OF SURVEY SEPT. WELL NO. M-15 (SEC O1 TI lN R12E) COMPUTATION DATE BOSS GYROSCOPIC SURVEY PRUDHOE.. BAY .............................................. SEP__T.,.__2, .... 198:1 _dOB~..NUMBER_BOSB-.l&882. ALASKA ." · '~"-' '-' ~' KELLY BUSHING ELEV. = 51.7~ FT. ' ' .... "'" '"" OPERATOR- BLAINE BAERTSCH '. ·. .." · "2 .:.. "f ". ' .; . .... . · " ' '. ' ;,' ' ?'" ,' ' . · L:~- '.. V~RTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANOULAR COORDINATES ....... DEPTH ............. DEPTH ........... DEO MIN~ DE~REES .......... ~EG/1 O0 NOB~.~.S~U~H EAST_~WE~_T ,' . : .: '..:. · :... .... . ,.....::.~.?. ~..:~ i .:.'.:.~.'..':.....,.. 3099,91 3048.15 0 .20 ''N" 1.80 W .': .. 0'~ 07 ....': :'::.:.'" :.. ~'~'4.11 N '9.89 E: : ' .............. si ~., ~ ............ 3~ 4e...15 ...................... o_i.:~.2~.~..~'._..~.....e.l.,_eg. ~ ':~:../O.~i.3e_'.:??:"..?~':.,' 4..~ ~ ........ ~.o,:0~_~.. ......... 3299.91 3248.15 0 11 N 19.19 W 0.21 4.62 N 10.30 E 3399.91 3348.15 0 6 S 34.89 E . 0.28 4.71 N 10.41 E VERTICAL __ SEC_],. I ON_ 4.84 ._5..18 .... 5.48 410'0 4200 4300 4400 4500 4600 4700 4800 4~00 ............. 5000 .... 3500 ...... 3499.9..1 .......... 3.448.15 .......... 0 .5 ..........N...20,67.. W ....... 0._18____.__~4...70_N ..... 1.O.._.4.~_E _5...48 ...... 3600 ~599.91 ~548.15 0~'., 13. :." ,... N .69.89 W. .' ,~ ,,:'.."~.:"0."18:;:::'-~.:...¥.~.~'?/.. '.' 4.84 N ' ' 10.70 E"."'.. , 5.64 ~700 3699. ~1' · 3648. 3800 ~799.91'.'"'. ~748.15 . ....................................................................................................... 6.._08 ...... ~900 389~. 91 ~848.15 0 7 G 80.50 W O. ~2 5.22 N 11 . 58 E 6.08 4000 3999. 40ee.~o 404~.~4 0 ~0 s ~7.~e u ~ 0.~ 4.~ ~ ~o.eo ~ ~.7~ ....... 4299.90': ". ~:"' "4248.14 .: . ..~."."0~"~.'~.~'~:./28"'.~:":.'."," S.~.'43,.~80E: ~i ~ ~:.?0."51::~"::~..'''' "'?: ~. '"~:':' 4.'7~ .:N ~ ~. ~:;~: ~.~ :.~l:"~li:.~?~'~3'i::'E.~ '..::.:~ ~ :'~:."~ ."/... 5.5T ....... 4~..~?.i....:. 44~. 8e 4448. l~ 0 5~ s 44. ~'0 ~ o. 2~ '~. 07 N l~. ~0 ~ 4. O~ ....... 459~.87 4548..11 0 30 S 75. 0 E' 0.57 2.~7 N 14.29 E 3.44 .~ .:o ................... ~ ................ ,.. . .......... 46~....87 ......... 4648..11 ............. 25 ~ 81.50 E _ . ~..10 . 2.~_2_1_.N ....... 1.5.~e_~ . ~.._3~ ....... 4799. 489~.86' .. '.4848"10 '.' .'.'....";~"./.:~0 '.'.;;.~':29 ' '.S.' 18,."O~';"~'W.'??;?~'.:;:~. 0',4i. ::' .': :~:..;.: ?.. ~1'~'~3';~ N'~'~?...?:;?~:~;1~'.8'0' ~.,.?~..;~ ./"' i: "'2"&2 4~..~.~ ......... ~ 47~, 1.o ..~..:: :.:.'~../.0.;~;; ~.~.z_~'~ ._S.... 15~?.;~:.'.Z',?::,i:,~.'~,.~..~o,L~.L.L~'~I..~i::'_~~,/.'~.~ :.,:;~,.; 1.~:~2.:..'E~. ,~:, 2._~2 ....... 5100 5099.86 5200 5199.85 5300 5299.85 ~4oo ...... 5500 5499,'82:':..'.'... 5600 5700 5698.56 5800 5796.33 5900 ....... 5893..50 ......... 6000 5990.20 6100 6085.41 5048.09 0 35 S 15.19 W 0.51 0.46 N 15.60 E 1.64 5148.09 0 33 $ 22.50 E' 0.37 , 0.48 S 15.65 E 0.70 .52.48..0~ ...................... 0.__.3...4. ...... S ........ 1...80,...W .............. 0_..2.,4__ __1,...42...S. .1_5...82_E ~ __-_O. 22 _. 5348.08 . '" ':"0' :";'::27:~ ":: 'i"~;2 S""' :'64 ;: '19:i:!: E:;!i;ili::i:;~i!i:;i::iiii:.'iiii:;i'O~57": :. 'iii:;;i;i:;'i::i.::i!"i~'::!2'~:'09-:.S:':"iii'i::'.i'?i!i'!;;."16',il'iS:. E'ii:"':::;!!":~;::'!",'::'i. -0.87 '' 5448 ' 06 ' ..... ":'"" :..2 '.?... 1:6 :i::: ..: ::~i !. ;.S .89 ~:5'0:.i: W:' ,:.; ~ :i; ii ;:, :::::i i; i'2";': 69 ;::.'~:: ;'~ i i ?:;;::; :'!i: '2:;':: 28:;." Si, ;:: ':.i '.': ::.! :':';ii: ! ~;:1'14','54 '.: E"'. '::'~:.: :..:;:. ?"" '.':' '- 1.18 5547. ,'so'. :.' ".. '; .i .i ". ' i .-:i : ~;~',,'::.~::__4e.::.::!~:..::~ii:i_~.:i;!:!!:"'_'N'~:..:Z.~;::~l?':;,W...!~ ,i, i~; i !i :i3:.;;:;6.6:~;:!!~::,~:: S646. eo zo ~2 N ~7. ~0 U 4.5~ 5744.57 14 I N 56. 0 W 4.50 13.85 N 23.65 W 12.03. 5841.74... 13 30 ........ N 38. 0 W 4,3.0 ..... 29.84._N .............40.,_8~_.W_ 5938.43 16 2 N":31.:iii'"'O;iw'i:!i:..?:.~;~3.. iO':."'i..'..,:.:..'.. '.;:~'~':~.50.'88' N..' .'. '. '55.20 W '":' '':'' ':' 46.58 6033.65 19, 30 N 29~19~W:~i:;?~i:;~??i:~i~?:~3a5~?~;:~:i;~:.:~77~3~ N :. ':":.: 70',46'W.'.' ' " 71.78 . :: . , . ,, .,, ,, ....... ,:....... .. .., · .., . . , . , SPERRY-SUN WELL SURVEYING COMPANY PAGE ................ ANCHOrAGE_ALaSkA $OHIO~ALASKA-~ETROLEUM COMPANY D-~-~URVEV~EPT. 1, 1981 WELL NO. M-I~ (SEC 01 TIlN R12E) COMPUTATION DATE BOSS GYROSCOPIC SURVEY PRUDHO~.BAY .................................... BEe_T_ ..... 2~ .... 1~81 dOB_ NUMBER.BOS~,.l~882 ALASKA KELLY BUSHING ELEV. = 51.7~ FT. OPERATOR- BLAINE BAERTBOH ... :. .......................... Y~U~ .............. SUSzSZA ............ ~60RSZ COURSZ~ DOG-LZO TOTAL MEASUR~ VERTICAL V~RTICAL INCLINATION ~I~EOTION S~V~RITY ~CTANGULA~ COORDINATES VERTICAL .DEPTH ........ ~EPTH ...... ~EPTH ..... ~EO ..... ~.~.~ .....~E.G~.EE~ ....... ~E~/_~_00 NO~T~/~.0U,~_H ..... ~A~Z~T SEO~_I.ON .......... . . · . . . ", .. ... . ~.'..'~.:..'.J:'..... . ... . ... 6200 .&178.53 6126.77 23 11'"'~:',..'' N 28.30 W ..3,71' '.i.~:.~??.:.~'.'10~.22 N 87,'~5 W' ... 102.2~ ..... · 300 ~2~, 7~ ................ ~218. oo ............... 2~._.~!.~ ~' N 22.39 W 3.12"?:~.:"":.'~'?' ~&....24_N I~_~,.W ......" .: '' !37~..~0 &350 ............... &'315.24 62~3.47 23 58 N 16.1~ W 5.&~ 165.83 N 112.2~ W 6400 6361.05 6309.2~ 23 18 N 8.3~ W 6.3~ 185.38 N 116.56 W 176.08 ......... &500 ......&453.05 ......... &401 . 29 ._ 22 ...... 51 ......... N ......... &. 39. W ................ 0.,. ~0 ................. 224,.24...N ................ 1.2i....&2_W ............ 21..4,..45 ........ &&O0 &54~. 30 &493.54 22..'.. 33". "" N .. &. 89 W .... O. ~7=.=..':::~.<~:"..:.:...262.58 N 12&. 09' W . 252. &700" &&37.81 &58&.04 .22 '.: " :. .5:".."> ..' :. .,..' N .' ~.~ W '.' .'~...:0',:4'~:i.:.':':../::..~':">.~"~300.2~' N : · 130.58"~W:.''.''>'' :' 289.&1 ............. ~800 .............. &730..88 ........... &~79._! 1 2o":::~?.48'~.~':"':.'"'.~'".'."N':,'',. .&. 8~ W" ...'. ?.:.-'.'. :'".~"=.l';..2~:'~:~:~:=:.?~i~::~..'.ii::':~=~'~3&. 59 N ' 134~.:91.'~.:'W.?:i. i~"'." '"' 325.49 __ ................ ~ .... · . , ..................................... ~,... ............. · ,00 20 w z2.02 1 .01 w 7000 6917.99 68&&.23 1~ ~ .N ~.10 W 1.17 406.78 N 142.4~ W 3~4.~0 .... 7100 7012.02 6~&P.g& 1~ 5~ N 4.60 W O. 17 440.71 N 14~.37 W ~28.52 7200 ............. 71 bs. ~7 .... 70~3. ~1 .......... .'~ i':~J~'~.~6:"~'.:.:"'~:N~ ~i ,i ~'~'U '?. :? :?.~.~:."~1:.:.&'8~:~ ~:.~7~,:'6~' N~:'.'~'".':7'-I~'F~ 1F~.~'463 ."27 .......... 7300 71~8.5& 7146.80 ' ' 22'~'~:?~.20.'?:;?~,.?N "'..~':..::1.10 "W ':":'.".~':~'~:~':'.:.'~1':?,50 ~:~? :~:~:'.'512. 70"N ':: ':"." "147:~ 1'2: W '."':"':.. "': 500. 7400 7290.56 7238.80 23'::~'.'.:.:...4&~':~:.;:::???.N..'.:::'' 3,60 W ' '"':.:'~" "":" :;~::'.'1"~: 74'::~=:~ ". ~::':~:~ ~.?' 551.82 N: ' :.:" '145'~':.:4~'~W'::::~ '~:." '::":: "': 539.3I _ __ ..................... , .................................... ~. .~,~.~_ . ~ .... ~ .......................................... 7500 7381.83 7330.06 24 28 N 5.1'0 W 0.~3 5~2.58 N .... 142.38 W ..... 580. 7600 7472.60 7420.84 2~ 7 N S. 50 W O. 66 634.35 N 138.51 W 622.12 7700 7562'. ~ 7511.23 2S 31 N 7.8~ W ............ 1.11 &7&. 82..N_. 133~51_W .............................. ,. ........................ ~ ................... _ ................................................. 780'0 .... ;:~ 7653.07.. 7&01.31 2~:'.'..~::~.~5~"...::.'.':.'.:.:.'/.' N...".'iO. 1~. W .. ": 1 .. 08:1:.?;.~..;:::~'~ 7i~. 70. N ...' '.'.'12&, &8"'W ~:..::' .::~/.:;' ~./.. 708.12 7~00 "7742.47. ...7&~0,71 27.' '".:"...i~'::;;'.;?:~.;..'.;';":;N :.:i2.."3~ W. i'." .1,:'~':;~?~ ';::~"T&~.'&O.:iN ;. ".:'..ii7~'88"~.:.W . .: :.; '! > :.;~:' '::'7~2.57 ' ............. ~000. . ~0.~ ......' .777~.~ 2~. :.'..."::.':~;.,.:~:::::.':;,~;'.."?N:.::.;:~'..14,.~. ~ · '..."2.;~.i'0:: ~ !~: ~;:~;:.~0~..~:. N":'~. '.'; :~~-Z~iW~ ~ :~:'::~:."~. ~...~2~ ....................... . .............~ ....... . ........... ~. , ~ ._., .... ~ .... 8100 7~17.84 78&&.08 2~ 20 N 17. 0 W 1.2~ 85~.57 N ~3.&~ W 847.0~ 8200 e005.14 .7~53.38 2~ 3 N 18.1~ U O. ~S ~03.07 N 78. ~4 ~ ~4. 8400 8180, 73 "8128. ~7. ........ 27~::~`~:~58~.:~:~?~:::~:~:~N~:~17~?~:~:i::~W~:~:::~:~:~:~1: ~..~! ;"?.'"'~4;.'27~:'N:. ;:: ~:~.'. :.:~;~74~';83'".W'. "":~::'~...":: · P87.70 8500 8268, 88 "8217.>12 ' '.'"':'~28'?~:' 21~:~:~:~:;~?:~::N:~::~:;i~~;w~;~;;~:~:~???::::~::~::~;~:~;:~;~~ :~. ~i"03~";'.':44:'":N;: ':?: ~:; ~::.'3&~;.;.iO.'.:W';'?~.~.":'~.'.: .'.". 1033.78 ............... ........... ............. ..... ?:;. :.:.: ' 8700 844&.~& 83~4.80 2& 22 N 18. 0 W 1.00 1127.13 N 8.~8 W 1123.2~ ..... 8800 853~. 34 8484.58 2~ 51 N 1~. 30 W O. 77 11~8.84 N ~. 10 E 1165. ............ 8~00 ............... 8626..2& ............. 8574.4~ .............. 2~ .3 .......... N ... !.~...i.~W ........... Q...22 ....... 1.21.~.._1.8_ N. .......... 1.~.._4~.._E ....... 1.Z08._21 ......... ~000 871&,38 8&&4.&2. 25' 17 ~ '18.'30.~':'W"~:":::::'.:'"':;:.'".:' .' 0.: 84 '~" .... ' '1251.21":N.:~:...~'.";~.';::.~:'....~'33.3~ E:' .1250.18 ~100 880&. 7& . 875~. O0 2~ 23 ' ""' .i':..7."~O:="?W'::'{;";':::~~:.;:;;'',.?;' O. ~ 12~1:., ~4:'"'"'N i'.".::?~;i;;.'.C',.::':;':,"'4~. ~4 E 12~1 78 ' .';,, : ', ' :'.., '.."i~ ?.':'...."," ". :: ':'"' ,, . ". . .,' .... , SPERRY-SUN WELL SURVEYING COMPANY. __.ANCHQRAGEiAL~SKA .... SOHI0"AE~KA-~£~Eu~""C0M~ANY ........ WELL NO. M-15 (SEC O1TllN R12E) COMPUTATION DATE PRUDHOE BAY ....................................................... ~E~T .... 2,_._1~81 .......... ALASKA PAGE 4' DATE OF SURVEY SEPT. 1, 1981 BOSS GYROSCOPIC SURVEY .__d. OB_NUMBER..BOSS, 16882 ................ · .'. KELLY BUSHING ELEV. = 51.76 FT. '. ....... :OPERATOR- BLAINE BAERTSCH .. .: ... ..................... TRUe' ............ SUi~-'SEA .............. -~'~'~-~-~- ...... --C~-oF~$E-----~'O-~-LEG TOTAL MEASURED VERTICAL VERTICAL INCLINATION DIRECTION SEVERITY RECTANGULAR COORDINATES VERTICAL .. DEPTH _.. DEPTH ............DEP...T...H ............. DEG ....BIN. ........ DEGREE~. .... D. EO./._I..O.ONOBTH~.S. OU_TH E~S~.ZWE.S_T SEC_T.I_ON ....... · .. ' '.'.': .:'. · i : ' ' ':':' ' :'" ' ' ' 9200 8897.08. '....'.' 8845.'32 '" .' '25 :':.".:~:i:26'~".t:.':". '.. :. N :"'! 6.89' W: :": :::¥":::.?:~'.ii.i'::. ":'.' ~":: :~?:i:'.!:':'i'??....'..-i.: . :. . .... "... ::...: :. """ .. .'.:: i :i:'??::'i!'i'::::':O'.;26'".:?.~::.:,:':..:.:.:.::~i:.:~.'i~'1332~ 94' N':" .::': ..' :' :-5~,:.:23:..:'?E'i:ii'..::' .:"i'...'.. 13:33.61 ........... 9300_ .......... .8~. 87.....3~ ......... ", 8735,163._,,-_2~.'"':~'i:"'i'_~'!25' ."£"'::-'--N._1_6%801 '_W :i:i~!!!'::i?:ili!:: ?iiO.,:_O_.4'i~':!?.:~:iii:'~:ii'!?'ii:l.1317_4.~..O.4"_N± . . 7__1_~'_68&F ". '.~ .":" 1.3.7.5_..5.4 .... 9400 9077.56 9025.80 25 48 N 16.30 W O. 44 141.5. z~9 N 84. O0 E 1417.80 9500 9167.63 9115.86 25 41 N 16.50 W 0.14 14~7.17 N 96.26 E 1460.29 _ 9575 .. 9235.20 . _ ~183.43 _ 25__44 ........... N__I.~..6P.W ........ .0....~7 1...488...~_N .... 1.05.2~_E 1~_~2...15 ........... "i'~ ..... .'-9600 ............ 9257"'72 .....7...".i."~20'5.'95 ............... ~25::. .':..: :: 44.'..? . . N .. 15.69. 'W...i'?:?~.:~.i.:i'i,i:.':iO;'O0'~'.::'.~ii! i:ii:,i'.~:'.':A 49~. 9O N :.:.. :..:' .... 10~, 23..: E' .' i...'.: :. i,: 1 ~02.79 96~7 9509"06.. ". 9257.30 ' ' i" 25 :"::::?.44 :'i..!?'.'"":':'. N" 1:5.69: W':!?:?~?,ii!i!:?i'::':,:0'.~:00...'~'.i!!?::~!!'?.ii::ii;1~22~':73:' N :~.' .... 114:..93..'E. :':::i:'"'?."':?:::::'1~27.06 HORIZONTAL DISPLACEMENT --- 15s~7.06 FEET AT NORTH ~ DEG. 1~ MIN. EAST AT MD = 9657 ...... THE .CAL~.ULAT..! ON_. P. ROCEDURES. ARE.. BASED.._ ON._T. HE_ _USE .. O.F._ .,E .H .~E_D.I~EN~.I ON~L_~AD I. U.$.._OF.._CUE~..V.~L~UE~E_BET..I~.OD.. ........... ....................................'' ..... ...... SPERRY-SUN 14ELL SURVEYING COMPANY~ SOHIO ALASKA PETRO~£uM COMPANY WELL NO. M-~5 ¢SEC O~ T~IN RI2E) PRUDHOE BAY ALASKA ................................... _A _N..C. HO_R. ~OE_ ALASKA COMPUTATION DATE s~P_T_:--_2_.,. _ ~ .~.8_1 .i. :: '.. ': ' '·: PAGE 5 DATE OF SURVEY SEPT. 1, 1981 ................................ *ZNTERPOi'ATED-VA~UE~'-~-OR EVEN ,1. ooo-'F:EE~--'~F I"IE~'~ED DEPTH d. Oa_ _..NU~.BER. BOSS-_168.8..2 KELLY BUSHING EL£V. = 51,76 F'T. OPERATOR- BLAINE-I~AERTSCH 1000 999.98 948.22 2000 1.9.99.94 1948. :~ 8 ...... ....... ~o0o'"'"'.-. "~9"_' ~i ~'-~.':'. -"'~e. 1 ~ 4000 "~, ~0 ":'"".'..'~48. ~4 ' ............ s000.._:.~'_4~_~..86....'...~..;~.~.~48.'.~ o. ~000 ~9~0.2o ~8.4~ 7000 6917.99 6866.23 TRUE SUB-SEA TOTAL 'MEASURED .........VERYICAI, ..... VERTICAL'. .....RE6'¥Afii30£A-~"~C~-b~'NA~E~-.----MD-TVD ..:..:....... (~ER'~'i~AL .'.':::::.'.,.'.:'....:.:'.:~:..' DEPTH DEPTH DEPTH NORTH/SOUTH'./;.......::' EAST/14EST '.. DiF'FERENCE'i':i~:':,. .................. 0 .................. 0;. 0'0 .................. -:5~ ';.'~'6 .......... o. oo o. oo o. oo """ '"":::'": '":':' '"':" 2.39 S 2.52 E 0.02 0.02 ............ 0.,_~6_S 7.0,5 E O. 06 O. 04 :. ::::.':,: 3, 52:; N:..'.~ .... ~' ' ..... 9"85-"E-::':'::::':~:ii:::';'!::'.'~'~:'::!.':::.i'.o,'o9' "':' '"""'.' ' "'0"'63":. ":'. ~':'::::.-':.'.'.. ' .: '. '.':::':::.~,~!'.?:;;;:~';i~i;N::::i'.:.':::~.::'....~:'::".;~ l' ~. ':t 6 :;.:. E:.? ?i ~i~i:. ii !?!!iii!!?!! ii~!O~;.~ :t o";;; .~. :.i:... .. .. . : ".'..:..;, : .. ?'; .o':,::.'o0~ ?: i; ' :!;': ~'~':~;:~"' "' "'.'" 50.88 N 55.20 14 9.80 9.66 406.78 N 142.49 W 82.01 72.20 8000 7830.59 7778.83 809.56 N ZO6.9.t 14 Z69.4! 87.4! ............. 90'00 ............ 87:1.6:.~8' .............. 8664.62 ............... ~28~.-2'ii..:'N' .," .... ' · 9657 ' 9;309.06 '" 9257. ;30 ' .1. ~22~"7;3'."N,....' :'..' ,' .1.14.9;3 ;:;'E.':"?;!:?!?i:iii!:! i!!.:i';347.: 94' .: .." :.':,;;;::;.,',;1:64.;'$2, .'~.!.!/.'if.:(...,.; :."..'. '.' .', '. , ...::...'..." :" . ,% ................................... 7 .... :':':-,'": ..... "":":T;';T': ........... . ...................................... .".": .::./::!'::~':::!!i?:':! ~;! i::,;: ?;' :: i:iiiiii!i?:?:~;:.::i::!;:,'!i!: :;:::....::::.::.::,.i.;: ....................................................... . ...... ; ..................... :..~_** .............. '. '. · , , , ,..,.. SPERRY-SUN WELL SURVEYING COMPANY.· ......................................................... ANCHORAGE_ALASKA SOHIO ALASKA PETROLEUM COMPANY WELL NO. M-15 (SEC 01 TllN R12E) COMPUTATION DATE PRUDHOE BAY ................................................... SEPT .... 2.:..198! ALASKA .. PAGE DATE Of SURVEY SEPT· 1, dOB.NUMBER..BOSS~.l&882 ...... KELLY BUSHING ELEV. = 1981 51.7~ FT. .:...i!.'..,'...:.:. ... . OPERATOR- BLAINE. BAERTSCH, (" · . · ------'"'-----------------------INTERPOLATED'-'VALUES'-'FOR-"EVEN'-'IOO-FEET OF SUB-SEA DEPTH ................. TRUE ........SUB-SEA ............................ TOTAL .................... ' MEASURED VERTICAL . VERTICAL RECTANGULAR COORDINATES· ' · MD-TVD DEPTH DEPTH DEPTH . NORTH/SOUTH ' EAST/WEST '.:~'"::.. DIFFERENCE ' 0 251 251 351 351 ........... 451 .... 451 551 551 651 651 ............ 751 ........ 751 851 851 951 951 ............... 1051 ......... 1051 1151 1151 1251 1251 ...1351 1351 1451 1451 · 1551 1551 .............. 1651 ............. 1651. 1751 1751 VERTICAL".:' CORRECTION'"" · . ., . . . 0.00 -51.76 0.00 0.00 0.00' 51.76 0.00 0.02 S 0.01 E 0.00 0.00 .76 ........... 100..00 .................O. 41. S....?_:..,~ ........ O,~.iO....E ..0..00 ...... 0...00 ....................... .76 200.00'. . · 1.03 S.:......./:i.;::O...::i!::;O.:16" E':.....:....i '.i....?.i~!:.0.00 .'... . i .'. 0,00".';...."::::.:,:::'.:.'.':"..::i::i.:i .... ..::.:': ':.. .76 '." ' 300.'00".".:".:" O. 77"S ..'76:....;_.' ....... ;.400 ,.O0.:J ............1' 51':...S . 76 50.0. O0 2.02 S O. 52 E O. 0.1. O. O0 . 76 600. O0 2.20 S O. 95 E O. 01 O. O0 . 76 ............ 700. O0 ............................. 2. :30..S ........ 1 . .62._E ............. O..Ol ....................... 0..,.00.._ .76 .'. ' ' ... 800. O0 . · 2.03. .76 ·' '900.00' . ' . ': 2.50 S·'.::')'i;'::::i;;~i;i;?;;;:.!?j'?/.i:2.:31';'·:'; E?'?.~!i:;i;::?.;ii;~:!?.i!i;i);i?~©, 02. ',' ·:': ;. "~.'.;..":'?~:!:~:.:.O·~.O0:: ;:..'!:~.!i?i;~ ;;: ;i;i '::?.% ...... ·. '.·...' .. ' ..76..'...';;:..i......1000,.00.,'..~.: ........... ".i..i ....... ;,.2.27...~.-s~.~!;?!:!!!!~2.--73.:~.E~!.;!!:?!!:i::iii?:~/;`:.!:~.?.!:.;~:~2-.j. ........... ,~'?::;;i;:;':O.;:;O0!?.?:iiiiii:?!::~;~'~.i.;',i..:.:L';:, :.' .. .76 1100.00 2.40 S 2.87 E 0.02 0.00 .76 1200. O0 1.16 S 3.05 E O. 03 O. O0 ...76 ............... 1:300. O0 . ...................... 0,.75.,_S .............. 3...05_E .................... 0...0.3 0..00___ .76'.": ,'., 1400.00 . . 0.60 S .76 :"." 1500.00" .:' 0.26' N · 76 1700. O0 1 · 07 S 5. :3:3 E 0.05 O. O0 ( SPERRY-SUN WELL SURVEYING COMPANY ............................. ANCHORAgE_ALASKA . SOHIO ALASKA'PE~ROLEUM'~coMPANY WELL NO. M-15 (SEC 01T11N R12E) COMPUTATION DATE PRUDHOE BAY .......................................... SEP. T._~,_1981 ALASKA DATE OF SURVEY SEPT· PAGE 1981 7 ,dOB_.NUMBER.BOSSml&882 __ KELLY BUSHING ELEV. = 51.76 FT. '.OPERATOR- BLAINE BAERTSCH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ....... TRUE ........ SUB~.SEA ........................ T.O~AL .............. MEASUSED" VERTICAL VERTICAL RECTANGULAR COORDINATES "'" MD'TVD DEPTH DEPTH .. DEPTH NORTH/SOUTH' EAST/WEST"DIFFERENCE ..... . .................... ~ ........... : ................. ~ ............... ~...' . ,~ .'. ".. __ ' 1851 1851.76 1800.00 1.47 S 6.28 E 0.~5 1951 1951.76 1900.00 1.27 S 6.83 E 0.06 0.01 O. O0 2051 2051. ...... 2151 2151'. 2251 2251. 2351 2351. 2451 2451. 2551 2551. .............. 2651 2651 2751 ' 2751 2851 2851 .............. 2951 ...... 2951 .76 .............. 2000. oo 76 .. 2100.00 ... .... . O, 76 ' 2200. O0 .. .... '. '...'. 0. 76._.- ....... ._.23.00...00 ..:_.- ..... ':..'_.i.& 1. 76 2400· O0 2. 76 2500. O0 2. 76 2600. O0 76 '...:i' 2700. O0 "i'.:'"i::.: '. "-"1, 76.'"""' 2800~00 ..: ..'::' "'. . 'i ::. :2. 76'. _' i.'i~'.~ 2~O.O..OO_.L-_'.i L...:.'.-'.-_:':.":._.'....~. ....................... 0..~.1...S 27 N 83 N .4~...N .......... 10 N 21N .............. 7_._2?_ E. .o..o6.- ..... o...oo · · 7,.73.. E;'.:' i..' · O. 06 '. '.".;..':~'".'..':"...~::'...'"'.. O. 00..:'::.'-:..:::.:..'"...':..... .. ': .'.'"' 8,'65'..E:.'~:'? ." .: 0.07' ....:'.:..::i.'r:!~.::.'::?.:ir..:i.i::.!i.::..':. 0,i01.17'i..:;...:.i..?:i.: ;'.' ..'::':..:.?... ...":"~]_~:;;t~O~E.'.: ':':'.'.:::' ~-_.,-'_.0..08. ': :.' :'~:'::i:'..!:'i7~ ':;~::~: .: :".!::.i. ',:.i'.:ii i/!'i'O..,.O.O :':: !'.ii:.'~::..:.:?.":':::~ :...'.. ' 9.98 E 0·08 0.00 10.21 E 0.08 0.00 93 N 10..:38 E _. 0._08.. _,0_._0.0_ 86'-'"N":'~"~?~r':I.':O:~':i27~E'~7-.'7;i-~~' ;"0:08. .':f:~i; :. :~?': ;!:::..'::.'.0.00 :':');: i~;::i.';:':!, :'::'." . 43"N '"".' "i.':':i':......;?.:..!!'.;'.iO';:'.;il..3:'i~.~:.:E.'..;:'; :..: .'.. :'"i:.'"' ""' 0, 08'i..i; ii ~;i! :.I ': i~.! i. ':i:; ;:;::::.:: :.: :~i;i'.;i; 0 ~':00 :"i :..::.'. ": .::i;~ :...':::::"::.::' i :': ".... "' 2,3. N .'::..':.::.?:;!~?::i::.~_;.~ie3~E'', '..:.:.:'i~.:":' .' '." ... O. LO~'..~i'i !: ii~i:i ;i,, ::;: :~i;:;! ?:'~;'.:..':?~0._.00~:..;'~:!::;?.:~;?.:;:'.?..~ ;: '., .: 3osz 3osz. ?6 3ooo. OO 3. 315t 3151.76 3100.00 4. . 3251 3251.76 3200. O0 4. ............ 33S ~ ........ i"'33~ z ."~6:'i:;7 7'33oo ,."o'o' ~!'iii:~?:F'.-"~; i""4. " 3451 · 3451'.76':i:'~'::,'.'.:'.'`: ."3400,'00 ':'.'::...".:". '?:~:::. ". i 4. ._'._'_ .............. ~.~ ~ .i .......... 3~.~.., ...Z~..!::'~!;L :;.'.-.:i.....~soo ~:'oo ';_:. :_ LL'.~ .'' '.',"-:i. ::;'..'.4. ;. 3~z 3~,sz..7~ 3600. oo 4. -SOH I'O"' ~L~S'K~'-'f~i:R~)'~.~O-~-'''~OM~ANV ..... WELL NO. M-15 (SEC O1 TllN R12E) PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY _ANCHORAGE_ALASKA. DATE OF SURVEY SEPT. COMPUTATION DATE ._SEPT..__2,__~81 .~__d. OB_NU~BER_BOS$~_l_6882 .... .. ... KELLY BUSHING ELEV.. " .....': .....:"."::'":....-:"OPERATOR-.BLAINE BAERTSCH . . . .. .. ,. . , .,. . .. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH PAGE 1981 51.76 FT. TRUE SUB-SEA TOTAL "'MEASURED ....... VER¥IC'A~' ...... VERTicAL ..... RE~¥A'~'~U'~AR.--~OOF~D'~-~¥~s.' '." MD-TVD ... VERTICAL;.' .'~.'.">'......~ .. . .. . . , , . ., DEPTH DEPTH DEPTH NORTH/SOUTH .'..... EAST/WEST.....:'.i:i.'D:IFFERENOE ' · · CORRECT I ON i':?":i:::;:',':;'::.&...'. ?.?:.:;:...:..;~:'....':....' ' ...................... ' "' · ' " . ...... !:..,.:.i!'i,':~.;:.{:::_.!.:.:.ii!':_'v:_:::.'::'. ' ._ _ 3751 3751 . 76 3700. O0 5.21 N 11 . 36 E O. 09 O. oo 3851 3851 . 76 3800. O0 5.24 N 11 . 67 E O. 09 O. O0 3951 $951 · 76 3900. O0 ....................... 5..20....N .................. 11.....44_E O. 10 ' O. O0 4051 ' 405~.76 ........ .'4000,00 ... 5.09'.N · 10.87.:"E':~::'i~?.:i.~.."...'.'.' '.: 0.-10"" .':..:):;.i '"':'.. ..' :'. ... O".-'O0" :: "~:. ? ~ri~ :.;. " i· '. ............ 4151" 4151.76 ' 41.00.00 . ':"'"::'.'.'.4;83' N '.' '::' .".' 10.:77"i"E:;ii!i?.':.'.??.'"~:.;'''' '0.10 ::;'ii"';'>?:"/.:.::i::'i'?:'>:i'i;':"o. O0!:~:',:i~ ~i?'~: .~":::i;';.;::":::.': .... 4351 4351.76 4300.00 4.41 N 11.66 E 0.11 0.00 4451 4451.76 4400.00 3.62 N 12.74 E 0.12 0.01 ........4551 .......... 4551.~..76 ............ _4.~0.0 ,.. 00 ...................... _2......52_..N .................... 13.87 E O. 13 0.01 4651 4651.76' '"" .4600.00.. ".'. "'..,..v%::i"..2',.26':.N: '..:.:;'..:.: ..... '14~7~'E'::~.ii:r:::ii.?:...:'::.'' '" ..... "O.'i'l:3:..ii::i.::~i;;~:i: i: ~i~:..,:.:.;~O,;O0~i:,ii:.?: i:':' '::::~:':."':':': ::.::'. ' ' 4751 4751 .. 76'..."i':::::.. '4700, O0 "" "'. '.. '::::'i:';'?;1'2'713:: 'N'".".":;;'...' :::;'.'~'.'15~::~4'~' Eii~:?~::;~::!".::.::?':: :~;;':': ..... 0,':i'1"3:.~::::i': ~iii :. ;~::i'~?~;! i~r:;ii~i;:.:.O,:O0 ;?::.i ;~,i;:-~ ~ ?:~:;!!::i?;~??r:.'::'.:.':'4''' '::' .. ::. ~. ................ 4e~ ~ .... 4es z~; 7~,i'..~.::.~i';'.." ~4eoo. oo ....... '.:_ '~i.:':' ::i~!j.i.&~', 141N ......":":":'? ':..' '.:.'.i."1_5';..:.8."???.':"::.:.:':..'..'i:;::'.:::~.:~!:i.~:; O:;';i'4"i:::!::i'.?,ii!:~:.!!:~!?.?.:?:i!'i~. ii::;',: .O'_.,"_O.'Oii.; !i i!i??, :::...::?"'. ':' .: ~ 4951 4951.76 4900.00 1.13 N "15.71 E O. 14 0.00 5051 5051 . 76 5000. O0 O. 91 N 15.72 E O. 14 O. O0 5151 5151.76 5100.'00 0.05 S 15.50 E 0.15 0.00 · 5552 5551.76 5500. O0 1. ~3 S 11.67 E O. 26 O. 10 SPERRY-SUN WELL SURVEYING COMPANY SOH I O 'ALASKA' PETR6~'~UM" ~0MF~'A'NY ANCHORAGE_.ALAS.K_A WELL NO. M-15 (SEC O1 TllN R12E) COMPUTATION DATE PRUDHOE BAY. ................................................................. SEP._T_._.2, ..... 1.9_81 ALASKA DATE OF ~RVEY SEPT. PAGE 1, 1981 ~OB_NUMBER.BOSS=16.882 . KELLY BUSHING ELEV. = 51.76 FT. OPERATOR- BLAINE BAERTSCH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH 'FRU ' SUm-e 'A 'FOYA "MEASURED .........V~¥ICA~ ..... VER'~iCAL~-i'"T'RE¢~ANOUL'AR ...... ¢~)~'~'A~'ES. 'Hi~'2~:UD "....,..." VERTICAL '..?......:' ....'.. ' DEPTH DEPTH · :. DEPTH' '. NORTH/SOUTH...~.'~ :.EAST/WEST.:":.? DIFFERENCE.~".~'~.:..:.;i.:i.'i:.CORRECTION'~:~.:':i.~ ...i.':~:::"ii:":'.."'." ................... 5'~52 ............ 565'~-:"~Z'6. .......... :- 56~'6~'~'~ ................. 6~-~-N 1.59 E O. 84 O. 57 5754 5751.76. 5700. O0 8.38 N 14.85 W 2.48 1.6.4 .......... 5857 5851.76 · 5800. O0 22.39 N 34.18 W 5.31 2.84 596.0 ...... .: .... 595~'~ 76."F ........ 5900.'~00 ........................... :'41.85'-N':~.';.:..i:!?.i:.i?':i,::.i~.i.'.:::'49; 51".i W ..'....'.: · 8'::'35:.': ~.:~ :::.. !'.i.::i,. 'Jill:iii .?:: 3.'"0~:.......;..i..~:i' :'i !"i.i.":"':' "..'::~'.~.:..:' ":' ': !.'ii:...', &06.4 "' &051.76. .... "' 6000. O0 ':6.7.30 "N::.?:!.ii::i!::iiii!ii:::::.!il;i:'64:,~SZ:::~!iW.i..:.i:. i..':'. :.'"'12.68 ::~ i:i;~I ............. 6.171 ...... -_~6!...5...1._..._.7.6.'.'~_.'=.'...~'~.6._!0_0.,i.00 '.. :' ._97_.'_4.2,N_ ~'?.iii~i!!?.!!i:~iii":i'82;.'&4':-'-~.W ': ?',: ":' :.'..' :: .:.!i' 'i~.".', !.9.~'_2....4. ';i:i.:i;;: ;i!..!. ;i i~::ill iiiiil i:i::,::...;:' 6_,_56 6280 6251.76 6200. O0 138.53 N 102.13 W 28.39 9.14 6.498 6.45 6715 6.6.5 6.822 675 ................. 6.929 685 7035 6.95 7142 705 .............. ~ ...... 7249 715 7357 725 ............... 746..6._'.i ........... 735 7576, 745 1.76. 6.300.00 181.42 N 115.87 W 38.12' 9.73 1.76. ............ 6.40.0. O0 223.71 N 121.56 14 46.. 84 8.73 1.76. 6,500. O0 ........... : ..... 26.5.":25':T'N'~;~l'.2,~'.-41:'.,T.:-14-"~. '" 55':;.'24~':..::';'"'," ...'.. $'";39'. :... :;:;'..'::' ;~ .~':~,::'...,'.' . '... 1.'76 '" ,6.&O0, O0 "' 30~;. c22"~::!?N:"'ii:!:ili:?i;ii::?:;;:"Z.31':~:2S'i:'14 ':'!".:.':.:. :' :.'.~':':"63,"30'.'">~;~. !?:!;i!ij:i'i.: ::. ?!':L''. ":"'"':" 8.06 '.'.'.':i':i:i:?:ili':!;?.~;''''': ''':'~'' '". '. 1 ..7..& ..... : ........ .6.700,..00 .......... 344:..4.7.."-.N_?:"':":::'::i:::::'. ::.:!~3_~5.:8_6.1.-.W ' '.:" 70..*'.58;'!!i~:....!;::.??':.'' .'..' '.-_'7....28 ~.:~"i.!;ii?:~i':";i'.'~.'. '..."... ':' 1.76 45800. O0 382.50 N 1"40.17 N 77.6.6. 7.07 1.76. 6900 · O0 418 · 95 N 143.57 W 84.15 6.. 50 1.76. .......... 7000 :..00 .................... ..4.5_5...09 ._N_ 1....4.6..._50........W ................. 90.,._5.2 ................. 1.76 · 7100. O0 ' . ' '. 493,'59''¥N.:,:.~i,':~L?:~i;!;!~:;i~.:.:I::47:;41 . W ".. '. : 97.'6c.:2.::':: ':.':i.::'":::.':::::'}.......:.~:.. '~7.16'"'"'?.:. :::'C:~:::i~i; .L ~:;..'.'".:::';:: '.'. '..'. · '" 1.76 ':,7200. O0 ' ",': 534;:.79.T i.'N;i!!!!i'.:ii:!i!ii!;i;',' ii4&.'54'.".~ ".::... ,:',!." ..."' "105~'85;! :~!!i L!!:? ..... ," :'!' :8." 16: i'i ;i .:: i: :'~i;:,!:," ;:;"...' :':" .'. 1.76 7400.00 624.62 N 139.44 N 125.22 10.02 SPERRY-SUN WELL SURV£YINO COMPANY. ................................ ANCHORAGE.~ALASKA SOHIO ALA$~' PETROLZ~M'COMPANY WELL NO. M-15 ¢SE¢ 01TllN R12E) COMPUTATION DATE PRUDHOE.BAY .................................................. SEPT,_2, 1981 ................. ALASKA PAGE 10 DATE OF SURVEY SEPT. 1, 1981 MEASURED DEPTH 7687 7798 ..... 7910 8024 8138 .......8253 8367 8480 ............. 8593 8705 8817 .......... 8928 9039 9149 9260 ......... 9371 9482 9657 ---dOB..NUMBER_BOSS-16882 ........................ KELLY BUSHING ELEV. = 51.7& FT. OPERATOR- BLAINE BAERTSCH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH .... TRUE .......... SUB-SEA ................ TOTAL .................................................... VERTICAL VERTICAL RECTANGULAR COORDINATES ' ' ' MD-TVD .... VERTICAL . . . DEPTH DEPTH NORTH/SOUTH ... EAST/WEST DIFFERENCE - CORRECTION ... :.. :.. .. . . .. . .... . . , ..:....'..'., : : ,...:'. · .... . .. .......................................... :,:, '~...., ,~..~~~..~..~ ........ .': ::'.' ':: "!'..i ":.::" .: 755i.7~- 7500~-(~0 ~'7i';'50' ~ 134.25 W 135.79 10.57 7651.76 7600.00 719.07 N 126.79 W 146.78 10.99 7751.76 ........... 77 O0 .. O0 ................... 768.28 ._ N ............... 11 ~...8~... W ........158 .. 69 ..... 1_ 1..._9..1. 785i.76 .' 7800.00 821.00 N '.'....':::. ::..':':'.::i.103, 97':W" ..' .... 172~:48'::.'."'.:.'/..~:i:i.i:.!..~?..'...;:' ..:.'. 13.80...:..'...'.....::i:.:.i:...'.::i'.'. ' ....:. 7951 ;- 76 ." .' ·7900.00' ' 874.81 N';'i::.:.'::~':i'i?ii~::!?:i,'.:88,.'12' W ' .'."~:".'.~'i 187..'15:::~ii!::!!iiii:i/i?:'!??'!:': .'/ 'i::~' "'i 14.66...:..".':i:"i'".i"i/!:~?I i:"'.":. ':" . . ...'..: ... .8051.._76.~ .......... 8000.. O0 .......................... ·927.'b3._N.~?! i;,:i::i'..'""70.'.i.89.... W ".'.' '201'.55'i.i:.??.i.i,i?;'.i:,;!! ~iL. Li.:L!. 14.._.40~:: :.'..: '.?.':'. "" "'". ..... ."' 8151.76 8100.00 979.56 N 54.33 W 215.44 13.89 8251.76 8200.00 1030.60 N 38.77 W 228.79 13.,35 , ., 8351 .. 7.6 ........... 8300. O0 ............ 1081.35 _ N___.___~3..38... W .................... 24.1 .... 98 .............. 13._20 8451 76.' '8400.00 '1129.58. ..~::~.,..:~=.?..:.:.::::?'~..::::?.8, i8 W ... .754..'05::,: :~;?'...: '::... 12.07..::'.,..::.:i~..;.!~:..:i:..':...,::......"..: 8551 ~ 76 8500,' O0 1175.89. N;,!"i!'i!!;:i:i;;?;.:':'.~;.:;'!?;i?:i.".7.' 57" E ' ... """.'..265,:.'38i?i'::;;?:'?:;.'.: . ':' 11.33 ': :;;:.:: ii~)?:ii! ~: :?:. ? ::!i'':{': .:i::;::':.':'"" .'/: :':. 8651.7&.. 8600..00 .1221 ..96. 'N.?:'.?:~i'}~:.!i23;!57ii:.E. ...... '.:..-.i..i'i'.~._276'!'63~2~::,':':?';.!!i.'' ":..~ 11;.-26::'";':.i.!'?:~':::'.:.'::':;::ii::~:~:i:.:'::.;.:":: ." ..'. 8751.76 8700. O0 1267, 08 N 38.63 E 287.37 10.74 8851.76 8800,00 1312.32 N 52.94 E 298.05 lO.&8 ....... 895i., 76 ............ 89.00..00 ................... 1357,..82._...N .............. 6&....78.._ E ............... 308,_.7.9.. ..... 1.0.._7.3. 9051.76 '., .' .9000, O0 1403, 52.: N"i'.?'...;:::;: ,:.!::'," 80'~ 49 E .. 319.58:: i:: ?:/:' .';.:.:!."i:.:."~..:;;....;:..:i. 0.79'" ::;' . 'i ;'"i.;"::'"'...: .' ' ": .' · 9151.7~,.'. '" 9100, O0 · ' 1449,85...;.N:':::~..:/!i:i?'::::.!~i':.i:ii;i:"94,':10 .E i".:' "...'":.;330.:."64::?!'!'. i';?'iii?.i'/'i?!?ii!.:!.?i;;i'il;:';.l'Z:.."O§ ii:~i:;:..i:i!?:.~?i,il;i;!i.:..:."'.::.'' ..;' ." .. .......... 9'25 i ;1'7...6'.L!'i"'....i._.':'...~200.. 00.._: .... ~- ...... :1.4'~61,~1.3~N ': :.;~ '.""!: ;"~l.0.7:L45_,..E~L~.~$4.,l.'~!63;~~~lO-.~9_9.1:.iiii~:i',;il;~il;i;?i:. i:.;'..i!ii!;i!.::.i:[:.:.'.'..i:i:i:!:i..;'":: ": :....." '.:.. 9309.06 9257.30 1522.73 N 114.93 E 347.94 6.31 ....... THE CALCULAT. ION... PROCEDURES.. USE A .. L I. NEAR.._INTERP_OLATI..ON,...BETWEEN THE NEAREST 20 ..: FOOT..:' MD. ( FROM. RAD I'US: OF'..':' CURVATURE )':' i.: PO I NTS :i :.; :.i :: :.~i !"~i :;;~i;.:; ,i?::'i'::?:: ;~:.::.: ;!!:.;:;:i'7;:?: .:.::: i":::i. ?: ': ;.,::'......:;: :..::!~::.:. ?i:: .: ~::..: ?' ~.::....:.: ..,: ..:.':.. ':. _.. ...:i.......iili: .iiiiiiii i!;!!i:iiiii i?i!i !i i!ii !i!ii i.,i il ;ii iii : .iii i i ? ! i, :i:.'/..,.._ Suggested fora to lx ipmertcd in each "Active" well folder to check for tingly compliance with our regulations. Ot~arator, Well Name and Number Reports .and Materials to be received by: Date Rc~]uired Date Received R~..arks Completion ReP0rt. : Yes f _/~_ ~/ :..~./' .~'~" ?;ell Hist0~ Mud L~ .-, ,/ . ~ , , . .. ~ ,,,-.' ~re ~ips " ,,,..~ ,. ., ~o~e. .... , Core ~scription . Ro~sgored Su~ey Plat , ,. . ¢~.. ..... .(.., Inclination Su~ey , _-.,~ ~ Dire~ional Su~y ,. · ,, S0H I 0 CONF I DENT I AL SOHIO ALASKA PETROLEUM COMPANY · ARCO . , TO: · SFO/.UNIT/STATE: Logs Ind uxed~ 1 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 9/14/81 STATE: 9/14/81 ':If' lO5O REFERENCE: o~'~o F-r~;~. ~)~,~ , .- lowing material is bein~~'submitted herewith. Please acknowledge receipt by signing a this letter and returning it to this office:-- SFO/UNIT/STATE: M-15 M-15 M-15 M-15 M-15 DIL/SFL BHCS FDC FDC/CNL RFT (Sch) 8/22/81 #1 " 8/22/81 #1 "- 8/2'2/81 #1 " 8/22/81 #1 "" 8/23/81 #1 .......... ~.~. ~ ...... --~,,,,~u,~.--~ ~ :-.~ ....................... 2" & 5" 2" & 5" 2" & 5" 2" & 5" .. -- STATE ONLY: M-15 M-15 Magnetic Single Shot Survey ' Gyroscopic Survey . 8/10-8/20/81 9/1/81 #0881-020 #16882' DATE Alaska Oil & sas Cons. Commission A~chorage Caro~ Deve l~p~ Geology Well Re~6~d s ' SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 September 14, 1981 Mr. H. H. Hamilton Alaska Oil & Gas Conservation Cc~mission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir: Well M-15 .(41-01-11-12) Enclosed, in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the monthof August, 1981. RHR:ja Enclosures cc: Well File 917 Yours very truly, District Drilling Engineer $£P 1 5 1981 Oil ~ Co.s. STATE OF ALASKA ... ALASKA { _ AND GAS CONSERVATION CO( .vllSSlON MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Ccm[k~ny 81-85 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20612 4. Location of Well at surface 1716' SNL, 606' WE[., Sec. 1, TllN, R12E, [3PM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 51.76' AMSL 6. Lease Designation and Serial No. ADL 28260 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. M-15 (41-01-11-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of Auqust ,19, 81 .12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month-end: 9657' Footage drilled: 9657 ' Spudded well at 1800 hours, 8/6/81 13. Casing or liner run and quantities of cement, results of pressur9 tests See attac~d .14. Coring resume and brief description None 15. Logs run and depth where run DIL/BHCS/SP/GR @ 9657' FDC/CNL/GR/Cal @ 9657' RFT - 10 pressure readings across Sadlerochit CBL/VDL/GR/CCL @ 9657' ,16. DST data, perforating data, shows of H2S, miscellane~ous data Released rig at 1200 hours, 8/28/81. SFp 1 1981 Oil & ~as Cons. Anchor~'~ Co~;~/$,io~ 17. I hereby certify that the foregoing is true,and correct to the best of my knowledge. ' ' BH ~ ' S,GNED T,TLE District Drilling ~.'Eginee~ATE ~ ' i ~. '~ ' NOTE-Report on this form is required for each c~endar month, regardless of the status of operations, and must be fXed in duplicate with the A~ka OH and Gas Conservation ~omm~s~on b~ the 15th of the ~ucceed~ng month, un~ess otherwise d~rected, Fo~m 10~0~ Submit ~n duplicate Rev. 7-1-80 WELL M-15 (41-01-11-12) W~.T. HISTORSf Spudded well at 1800 hours, August 6, 1981. Drilled 17 1/2" hole to 2665'. Ran 69 jts. 13 3/8" 72# L-80 Buttress casing to 2665'. Cemented with 3720 cu. ft. Permafrost II cement. Installed and tested BOPE. Cleaned out to 2623'; tested casing to 3000 psi, okay. Drilled out to 2704', ran leak-off test to 0.67 psi/ft, gradient. Directionally drilled 12 1/4" hole to 8880'. Ran 231 jts. 9 5/8" 47# L-80 Buttress casing to 8845'. Cemented in two stages: First stage with 1202 cu. ft. Class G cement; second stage through D.V. packer at 2562' with 130 cu. ft. Permafrost C cement preceded by Arctic Pack. Cleaned out D.V.; tested casing to 3000 psi, okay. Cleaned out float equipment and directionally drilled 8 1/2" hole to 9657'. Ran open hole logs. Ran 33 jts. 7" 26% L-80 IJ4S liner to 9657'. Cemented with 396 cu. ft. Class G cement. Cleaned out to 9614', tested casing to 3000 psi, okay. Tested .7"' liner lap to 3000 psi, okay. Changed well over to NaC1; ran CBL. Ran 202 jts. 4 1/2" 12.6% L-80 A/B mod. Buttress IPC tubing to 8412'. Landed tubing with ball valve at 1997'. Installed and tested tree. Displaced tubing to diesel; set packer at 8272'. Tested tubing to 3500 psi, okay. Released rig at 1200 hours, August 28, 1981. $£P 1 5 1981 Alaska Oil & Oas Cons. A~C~Ol'a'g~ CO~IojSSiOi~ SOHIO ALASKA PETROLEUM COMPANY SON I 0 CO,IF I DENT IAL 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE {907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 ARCO TO: EXXON .. Date: 9/10/81 9 1043 PHILLIPS SFO REFERENCE: i?.''1'' /SOHIO MAGNETIC LIS TAPES . · -).,)'7 //The foil. owing material i's being submitted herewith. Please acknowledge receipt by signing a ~ ,,!, Vt cop~' .... y"of this letter and returning it to this office:-- . · , ,~'~~Computerized tapes ~ ..... . J *S-14 , ,, ,, ~'"'----.4, Wet) #62057 7 30/8 · ~_., ~__ ~.. . 7 ~o~~... SF0/AEP ST~.'" ° Magnetic LIS Tape & Listing II II II !1 II II II II II II II II · II II II II (Final) (Final) #62057 7/30/81 #1 #62136 .8/22/81 #2 #62132 6/7/81 #5 #62131 8/22/81 #1 #62135 8/25/81 #2 ............................................................ R-E'£"'E-i V ED- .............................. .... ., o ~ Devel ' logy 'Anchorage well ~Q~as HQ 4-5 ALASKA OIL AND GAS CONSERVATION COMMISSION Hoy le F... }!ami lton/~#' Chairman Thru: Lonnie C. Commissioner Doug Amos ~~ Petroleum Inspector August 18, 1981 Witness the BOPE Test on Sohio's M-15 Well, Sec. 1, TllN, R12E, U.P.M. Permit No. 81-85 on Brinkerhoff Rig No. 36 Sunday August .9, 1981: The BOPE test commenced at 7..30 a.m. and was concluded at 2.-30 p.m. There was one failure, the lower pipe rams door seal. The seal was replaced and the pipe rams were retested. I filled out an A.O.G.C.C. BOPE test report which is attached. In summary: I witnessed the BOPE test on Sohio's M-15 well on Brinkerhoff Rig No. 36, there was one failure which was corrected during this test. I filled out an A.O.G.C.C. BOPE test report which is attached. TATE OF ALASKA OIL & .CAS COMSERVATION CCM~ffSSION B .0. P.E. Inspection Report '/' 'gW inspector ~erator ;ell ~cation: Sec I _T :%~% R ~IC M S, ,9. ~a , .~il linq Contractor~5'~1-~ %~-w hO ~.~, Dcation, C~neral~ ;ell Sign__ %neral Housekeeping ~ ...,~'~_ ~eserve pit .~ ~C.. KgPE Stack gnnular Preventer ~ipe Rams/, ~iind Rams-- ,~oke Line Valves~ ~.C .R. 'Valve '/ __ (ill Line Valves~/' ;heck Valve Date Well ?est Results: Failures, Representative b/t ~ % Permit # ~; ~'~l'Casin9 Set @ Rig ~--R..ep_r..e.._s_e__n_'_tative. -J ~ ~ ~CCUMULATOR SYSTEM Full Charge Pressure ~.~.O~D psig Pressure After Closure I j;? ?...'~ psig Pump incr. clos. pres. 200 psig Fu~l~,. Charge Pressure Attained: -..-.~,~.~ ~,, .,,~) .., .,. ,. .., Controls: Master 6 >' R...~_t'..e..: .. Test Pres sure __~+a~.m ..... ..... ..... - ft. mi~91 sec.. mi n <3 "~ sec. ...... B_i. in. ds_..sw.i, td!...c_g.ver '"~;:~.-."£- Kelly and Floor Safety Valves Upper Kelly J .... Lo~r Kelly. Ball Type_./_`` .... Ins ide BOP . Choke Manifold__/ No. Valves .Test Pressure .... Test Pressure Test Pressure Test Pres sure Test Pressure No. flanges. ~\ Adj ustab le Chokes I-~fdrauically operated choke ................. ~ .~ ;~ u '.'.~:.:. r -'::.-. _-- ' - .- .-.,: ~..:. - ..... ~:;..~_.--. ~... Test Time.' -7 hrs. ~epair or Repla'c~nent of failed cquipment to be made within :nspector/Ccmmission office notified. :emarks:? LD,~3¢..r. ~.',o~ v,~.~n , ',.~ .'/ ~ ~ ~.~ . , ',.~ .. . ..... ~, , days and )i stribut ion .rig. - AO&CCC :c - OperatOr ' '.c - Supervisor Inspector June 23, 1981 5.',.r. P,. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 P.e: Prudhoe Bay Unit M-15 (41-01-11-12) Sohio Alaska Petroleum Company Permit No. 81-85 Sur. Loc.: 1716'SNL, 605'~L, Sec 1, TliN, R12E, UPM Bottomhole Loc.: 158'SNL, 528'WEL, Sec 1, TllN, R12E, UPM £~ar Mr. R.eil~ Enclosed is the approved application for permit to drill the above referenced wel 1. Well samples and a mud log are not' req~uired. A 'directional survey is required.. If available, a tape containing the digitized log information shall be submitted on all logs for copying e~cept experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and. the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the }tabitat Coordinator's office, Department of Fish and Game. Pollution .of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the re~ulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. R. F... Reiley PBU M-15 (41-01-11-12) -2- June 23, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would, appreciate your notifying this office, within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is dril led. In the event of suspension or abandonment, please gave this office .adequate advance notification so that we. may have a witness present. Very truly yours, Alaska Oil & Gas Conse~ation Commission ~nclosure cc~ Department of Fish & Game, ~abitat Section w/o encl. Department of Environmental Conservation w/o/eric1. ~H ~ mm SOHIO ALASKA PETROLEUM COMPANY June 18, 1981 3111 'C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. H. H. Hamilton Gentlemen: Well M-15 (41-01-11-12) Enclosed are the following documents, in triplicate, along with our check for $100.00 to cover permit filing fees. 1. Application for Permit to Drill, 2. Proposed Drilling Program Outline, 3. Blowout Prevention Equipment Diagram, 4. Surveyor's plat showing well location, 5. Directional plan. If you have any questions, please contact either R. H. Reiley at 265-0183 or K. W. Kolthoff at 265-0176. RHR:ja Enclosures cc: Well File #17 Yours very truly, District Drilling Engineer STATE OF ALASKA i" '~ ALASIk~IOIL AND GAS CONSERVATION~ .)MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL;II] SINGLE ZONE [] DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Cc~pany 3. Address Pouch 6-612, Anchor age .,_ Al aska 99502 4. Location of well at surface 9. Unit or lease name 1716' SNL, 605' WEL, Sec. 1, TllN, R12E, ~ Prudhoe Bay Unit At top of proposed producing interval 10. Well number 410' SNL, 540' WEL, Sec. 1, TllN, R12E, UPM M-15 (41-01-11-12) At total depth 11. Field and pool 158' SNL, 528' WEL, Sec. l, TZ1N, R12E, UPM Prudhoe Bay 5. Elevation in feet (in'i-cate KS, DF etc.) / 6. Lease designation and serial no. Prudhoe Oil Pool Est. KBE = 56'.., AMSL! ADL 28260 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Ins. 2975387 Amount $200,000.00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse 10 miles south MP 28257 410 feet ~est well M-13 2590 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. ApProximate spud date ' ' 9732'MD 9408'TVD feet 2469 August 15, 1981 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~0 psig@ ". SurfaCe KICK OFF POINT 5500 feet. MAXIMUM HOLE ANGLE 24 °1 (see 20 AAC 25.035 (c) (2) 4480 psig@ 8800.' ft. '[4X(TVD) . . 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT . . Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20x30 Insula~ .ed Conductor 1'80' Surface 110'. 17 1/2 13 3/8 729 L-80 Butt. 2680' Surface 2680' i 2680' 3720 cu.ft. PermafroSt - . . 12 1/4 9 5/8 479 L-80 Butt. 8780' Sur. face 8780'1 8530' 1200 cu.ft. Class i I 130 cu. ft. Permafros~ 8 1/2 7 29~ L-80 BUtt. 1450' 8280' ~, 8090' 9730'11 94'10' 275 oM.ft, class G 22. Describe proposed program: w/18% Salt See attached proposed drilling 'program outline. , ~.. ,.... ...... . 23. I hereby certify~~d correct to the best of my knowledge . S,GNED [%'--'~ '~ ~ TITLEDistrict Drillino Enoinee~ATE The space below for Commission use ~ ..... CONDITIONS OF APPROVAL 'Samples required Mud log required Directional Survey required APl number []YES ~.O r-lYES ~fNO J~YES r-INO 50-- O % ~' -Z ~ ~ ) '7.._ Permit number Approval date ' ' ~ [- ~-~" 06/23/81 SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY. ,,COMMISSIONER DATE June 23, 1981 . . by order of the Commission .. . II C . Form 10-401 Submit in triplicate Rev. 7-1-80 PROPOSED DRILLING AND CCMPLETION P~ W%~ .T. M-15 Dry bucket 36" hole to 80' belc~ ground level and cement 20" x 30" insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-80 Buttress casing to surface using 3720 cu. ft. Permafrost II cement. Blowout Prevention program consists of 5000 psi W.P. pipe rams, blind rams, and annular preventer frcm 13 3/8" casing point to T.D. M~ximum possible bottcmhole pressure is 4390 psi at 8800' TVDss based on original reservoir pressure. Maximum possible sUrface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVD. Drill'12 1/4" vertical hole to 5500', then drill directionally to 8530' TVD. Run 9 5/8" 47% L-80 Buttress casing to 8530' TVD and cement first stage with 1200 cu.ft. Class G cement. Cement second stage through D.V. packer collar at 2600' with 130 cu. ft. Permafrost C cement. 9 5/8" casing will be hung at surface, the 9 5/8" x 13 3/8" annulus will be Arctic Packed. Drill 8 1/2" hole to T.D. at 9410' TVD. Cement 7" liner to 500' inside 9 5/8" casing shoe with 275 cu. ft. Class G cement with 18% salt. Run 4 1/2" 12.6% L-80 A/B Mod. Butt. IPC tubing w/7 gas lift mandrels and pro- duction packer assembly at 8044' TVD. A subsurface safety valve with dual control lines will be placed at 2000'. Displace tubing to diesel. Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. JLG:ja 5/13/81 ,.,! .... :","' ... ~' ,..'" TRIPLE RAM 5000 PSI WP DRILLING ANNULAR PREVENTER I PIPE(~RAMS ~_~ BLIND RAMS · KILL LINE CHECK GATE GATE DRILLING SPOOL CHOKE LINE GATE HYDR. ASST. GATE PIPE RAMS I I 4O OI 02 35 '~.12 E., R.13 E. 20 50 ~" 40 I, I0 M- 16~'~L _ ~ 468' (Pro pO~~ ) -~ 03 04 02 05 M-14 (Actual) :56 ~855' 99 I' M - 1:5 ' ~M- (Actuel) 605' I ..'"' zo :50 40 --I ti; 486~' I I I I I 31- I 32 I I I I 4ce:5' I ~ -t[Propo,ed) ~ T. 12N. 5,~o' "---~ ~?~'--~" ~ T. I I N. M- 14(AS-eU~LT) LAT. 70° 20' 19.14" I LONG. 148057 ' 34.73" X = 628, 209 Y = 5.974, 5 30 - ~4~5~M.,~6 I .,ol(P.o,o.,~~ I 5 . I I I I 02 03 12 4905' CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to · practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the well thereon. This survey was made by me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others. Date Surveyor NOTE: All bottom holes are 8800' sub sea. REVISED BHL. M-12,1S~I~I6 .......... · ..'- .... .: ...... ,~ DHO 4/7/8l REVISED 9HL M-1:58 M-I4 FROM PROPOSED TO ACTUAL PJR 4/2/81 ADDED PROPOSED BHL M-II, I~., ,5, t~ 16 RDR 121/IS [81 . /10/80 REV. LOC. PROPOSED M-IS BHL, REMOVED PROPOSED M 12 BHL PJR REVISED PLAT TO SHOW AS-BUILT SURFACE LOCATION PJR 10/16/80 ADD M-12 & M-IS PROPOSED BHL PJR fO/:s/eo WELLS I. I 5,5' :. 55' SUMP I' PAD DETAIL SCALE I"= 300' PORTION OF T. II 1.2 N.,R. I?. t 13 E.,U.M. SCALE I"= I/2 MILE I I I PAD "M" EXTENSION Located in E ~/z PROTRACTED SEC. I,T. ~l N., R.J Z_._[ .,.U_M!A~ MeR!DJ_A_N_~A_L_A. SE__~ Surveyed for SOHIO ALASKA PETROLEUM CO. " i i I iiii I . II Surveyed by F.M. LINDSEY 8 ASSOC. LAND I~ HYDROGRAPHIC SURVEYORS. 2.502 West Northern Lights Boulevard Box 4-081. Anchorocje Alaska _ I I . I m i , CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE Be 6. 7. 8. (3) A drain ~_~. :~," '~.,'Z ti 9. (. thru 11) 10. 11. (4) Casg ~'~. [-23,g] (~2 thru 20) (5) 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. YES NO Is,the permit fee attached ' lelllllllelellllllleetllllltlllillllllltll Is well to be located in a defined pool ................. Is well located proper distance from property line Is well located 'proper distance from other wells ..ii!ii!i!!~!!!ii!i. . Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is well bore plat included ............... Is operator the only affected party ............................ ' ..... Can permit be approved before ten-day wait .......................... Does operator have a bond in force .... Is conductor string provided. Is enough cement used to circulate on conductor and surface ....... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ................... · Will surface casing pro'tect fresh water zones ....................... Will all c'asing give adequate safety in collapse, tension and bursti.~'~-' ' Is this well to be kicked off from an existing wellbore ........... Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... (6) Add: ~.~'~ 25. REMARKS Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating- Test to ~00 Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: Geology: Engineering: HWK ~ LCS BEW WVA ~ JKT~.RAD JAL..J j.~. / ,, ,. rev: 03/10/81 INITIAL I GEO. UNIT 'ON/OFF POOL CLASS STATUS[ AREA NO. SHORE Well Histo.ry 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. ~VP O~O,H02 VERZFICATION bISTING PAGE I ~* REEL HEADER ** ~ERV~CE ~A~E :SERVIC )ATE 183/05/18 ]RIGIN : ~EEL NAM~ ~EEI, ID 20NTINUATION # ;01 )REVIOUS REEb ~DMMENT$ :REEL COMMENTS ~* TAPE HEADER SERVICE NAMF )RIGIN )0000 ~AP~ NA~ :8267 :ONTINUATION ~ 101 ~REVIOUS TAPE : :OMMENTS :TAPE COMM;:NT8 ********** EOF' ~* rlbE HEADER ." I bE NAME : 8F.,RV'IC, O0 ! ..... ~ERVICE NAME. )'ATE : . '"' · ~AXJ[~UM bENG:TH : 1024 ,'.":'ILE TYPE. ' ' .' ,'.." :.' "'.'.".'..<'.'.... :'..'. ""' '"' ?REVIOU&. FI[bE ;...... .. " .'. ..: ... [.,; .. ..' ,.... .... .'.......'.,........:. .'.... .. .... ~* INFOR"AT,IO~.RgCO~D$ **" ' ...... .' .... .' : .>'..'..:.....:.;i ,'..','..'.:.?:.. ,<.. '.' :: ...(" '..:' . ...' . .' ...' . ' .'. : .: " ........... · . ~'NE~ , 'CONTENTS" ' .:":.:':..:'.< ."..,.'.)'">.>'.':..'....../".:".'...':..":'7.'....."' .' ' ,.'.......:.. "; '.":. ' .... UN.I'T ""'.'TYPE ·CATE . SZZE' . CODE·. ' : . . ,.. ... '. · ..'..,, ,,'.'....:?...', ".....' .......... : . .. '. , ' NN "H ' : ' ":' '":':'"'" '"' ';'" "':':"'"":"'"" i"" ......... ' "':'" ::":' ":":'. '"" "' "'"" ' "' "' '"' : '"':'"" ' :'" ' .... ''" " '" '" ' .... 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CE NAME 3 ER'SION .#' 't'"" '" ""'" '""" .'.i: '"'"".i .':..':i::.':'..'.<.j.:.; "'" i.' .'" .:{ '. J .' ..' i ::> ': ' .' ." " 'id".: 'i".':'. '".' ".'...'. "'..": ,' ....'."' ' . ." ..:'."' .'... . . .. · . ~.5 0 50.0 5'0 '0: :, '"' ':.":" ' ' '" ': .' '.:' :> ':".... ".:' ." '.~." 5OO ]VP 010,H02 VERIFICATION PAGE )A?F,. : "' ]~ [, E TYPE : {EXT FILE NAM~ : 1024 ;ERV~CE NAME {RIGIN {0000 !APE NAME :ONT[N[IATION # ~01 IEXT TAPE NAM~ ~OMMENTS {TAPE CO~}ENT8 : :* REEL TRA2[,ER ** ;ERVIC~ NAM~ )SERV)C ~ATE ~3/05/18 'EEL NAME IREEb ID !ONTINUATION # 'EXT REEL' NAME' { 'OMMENTS REEL * **.*'**'** ** '~oF' '~ ~,','** ***** " ,, ,',.,. ~., ..~.....~...... .. *** ':' '"". .. ... . .. .... ' .......... ....... ' ....... ',";".':::"','<.;" .:'.':'~ '.'.,'";",.'J'.:.:~.:':...~L:~.,i!"<. '~ "',':'. J"i'."::::i '.'i..'.."."...<'.'.'''I ":" '.J: '...'. :ii' ~.'.'. '.'.?,..'.. ! :."..".'.: ..] 'i :..'.']. ':'.". '' .'. ... .' '., '"".i ",.: :"'. '' .;.'.'.'.'.':'..'.'..t ...', .': ". ', '.."'~"?~';:'".!.':...% i'~,'." ."".",.'."'.' '.'"., .~..' ..' ........ . . · . ..., :'.....: '.. ! .... ",.' ...... .?..'~<' '..i'.,:...'.'.' :..,.'!.:':..;:!L.".:.:..;'."i:i:...'.::'..:'.'.:':..::.i:: ]: ..'..:.:...:{ .... ~':,.', . :::.:i.i".:i: .]':;. J""'~:...."'.,.'j :i';..' .",'.'.::>.':.,,." ....'..'.'. '.:: '.......... :.· "' 'j h:, ..... ";· :· '·"··',' ·""·! <,,':<,, :'j'·:?h ¥··· ',,, ·, ·,': , · · · '· · · .. , ...... LIS TAPE YERIFICATION LISTING RE.C.E.IVE~ OCT z~ . 1982 .. 5¥P 010:hO1 VER]FICo~'I'IbN LiSTiNG PAGE 1 ** RFEL ~FADEU, SERVTCE ~AME' :SERVlC DATE CONT~UATI[)~4 ~ :0% COMMENTS ** TAPE HEADEP SERVICE NAME :SERVIC D&TF :82/08/23 ORIGIN :6546 TAPE NA~E CONTINUATION ~ :01 PREVIOUS TAPE COMMENTS :TAPR ** FILE ~EADEE FILE ~A~E :SERVIC,O01 SERVICE NA~E VERSION # : DATE : MAXIMU~ LE~C;TH : 102~ FILE TYPE PREVIOUS FILE : ** INFORMATION ., ECORDS ** PN : RANG: TOWN: SECT: COUN: STAT: CTmY': SOHIO' PETROLEU~ PRUDMOE BAY lin I . . · NORTH ''. . SLOPE, ALASKA O'$.A', CONTENTS PRES: TOMOO1E UNIT '];YPE CATE S,I, ZE CODE 000 000 016 06.5 000 000 004 065 000 000 012 065 000.. 000 0.03 065. 'O00 000 0 03 '.06'5 0.00 000 001 06.~. 000 ' '000 '0,I2" '0~5" 000 000 006 06,5 .. 000 000 006 .06'5 ' UNiT TYPE. 'C~TE' 'S~ZE' C.O~E' ..' . . ...000 000. .007 .. 065. ,. ., .OCT 4 1982 Alaska 0{{ & Gas Coa.,,,~, O,{:rmnj.~!o~ [.,VP OIO,H0! VERIFICAT[[~.~..~ LISTING PAGE 2 COmPaNY WELL FIELD COUNTY STATE JOB NUI~:B~R AT ACC: 1070'7,65463 RUN ~1, 0ATE LOGGE'.D:15-~UC.-~2 BOTTOM DEPTN TOP DEPTH TAILPIPF LINER TYPE Fi..UIO FLUID LEVEL bDPJ R,SINES 9596 8750 4,5 IN. B272 FT, TG 8411 FT, 7 IN. 10325 FT, TO B272 FULL 'iL~-'~ i,I i, i iii iD..] i[~ [:.]~ .( bVP OIO,HOJ VER1F].CA].!~Of, I.,.!$F. ID:C, PAGE 3 DATA FOR~A? RECDR[? ** ENTRY GLO. CKS SIZE 4 4 DA. TUM. SPF, CIPICATION BLOCKS MNE~ SERVICE SF,_RVICE US{IT ID OROER DEPT $IGM S01 TRAT S01 GR 801 BACK Si)! FBAC SO1 NTDT S01 FTDT SO1 $IG~ $02 FS!G S02 TRAT OR 502 BAC~ 802 FBAC 802 NTDT FTDT 802 $IG~ S03 FSIG TRAT S03 BACK S03 FBAC 803 NTDT S03 FTDT 803 SIG~ 804 FSIG S04 TRAT GR S04 BACK S04 FBAC S04 NTDT 804 FTDT, SIGM '$05 FSIG 805 TRAT '$o5 OR $05 BACK 805 FBAC 805 FT CU GAP! CPS CPS CPS CPS CU GAPI CPS CPS CPS CU GAPI CPS ,CPS CPS CPS GAPI. 'CPS CPS... CPS' CPS CU GAP][ CPS CPS .,AP I LOG 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 o O. 0 0 '0 0 0 0 0 0 0 0 0 0 REPP API AP1 TYPE CLA$ 0 0 40 0 0 42 1 31 0 0 0 0 0 0 0 0 40 1 0 0 42 31 32 0 0 0 0 0 0 o O. 40' 1 0 0 ' .31 3.2 0 0 0 0 0 0 0 4~0 0 0 ..... 0 '0" 0 .0 ' '0 0" 0 O. 4O 1 0 O, "42 1 31 32 .0 .0 0 API MOD 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 .' 0 0 .0 0 0 0 O. '0' O. '0 0 '0 0 0 0 CODE M~TRY 73 6o 65 , I 1..~{ 66 0 FI bE SIZE O, 0 4 0 4 0 4 0 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 0 4 0 4 0 4 0 4 0 4 '0 4 0 0 4 0 0 4 0 4 0 0 4 0 .4 0 '4' 0 4 0 "4 O. 4 0 .... 4 0 4 0 ~"4 0 4 0 4 0 4 PROCE L.F. 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LvP OIO,HO1 VERIF1CATI(3~ LIST1NG PAGE 5 DEPT GR FTD~' FTDT GR FTDT FTDT DEPT FTD? 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"3"452i'"' .164.5449 .. 202,6.2.50. 214,7500 ~ :.3'0'47 ~9 3750 · .. OCT . 19{32 , , LVP OIO.P.O[ VEf~TF1CaT],ON LISTING PAGE 6 FTDT 218.00oo SIG~ GR 62 2187 BACK FTDT 243i8750 SIGn GR 76 4375 BACK FTDT ~08 656;{ 1,9,5884 131,3750 133.5000 FSIG F~AC D~PT RBO0,O000 SIGr~ GR 48,6875 BACK FTDT 117.0625 GR 58.8125 BACK FTDT 144.7500 G~ 69,5508 SACK G~ 74.2109 BACK FTD'f 135,0234 SIG!~ GW 76,5039 BACK FTDT 134.6950 37.8125 108.3750 ]8.O088 12~,4688 ]6.28~3 129 '1500 113.7500 36.5000 129.5195 FSIG FbAC FSlG FBAC FSI(~ FBAC FSIG FBAC FSI~ F~AC DEPT 8746.0000 SlG~ GR -999,2500 BACK FTDT -999.2500 SlG,~ GR -999,2500 BAC~ FTDT -999 2500 SIG~ GR -999:~500 6AC~ FTDT -999,~500 S!G~ GR 80,8125 BACK FTDT 118.3125 S]'G~ GR -999,2500 BACK FTDT -999,2500 -9q9.2500 -999 2500 -9~9!2500 -999 2500 -999,2500 -999,~500 ]7.9375 ~27 5625 '999i~500 -999 2500 FSIG FBAC FSIG FBAC FSIG FBAC FSI(; FBAC FSIG FSAC $* FI:LE TRAILER FILE NA~E :'SERvIC,()O1 SERVICE N~ME VERSION # OATE : MAXIMUN LENGTH : 1024 FILE TYPE NEXT FILE NA~E 16,9262 7&,6250 ~6,6309 67,5~79 39.2~13 50,0000 40.9¢)4~ 57.5000 38.6250 59.4375 38.320! 62,0519 37,7a4~ 64,6~50 -999,25O0 -999,2500 -999.2500 '999,2500 '999,~500 '999.2500 37,4063 55 6563 -999:2500 '999,2500 TRAT NTDT TRaT NTDT NTDS' TRAT NTDT THAT NTDT TRAT TRAT TRAT NTDT TRAT NTDT TRAT NTDT TP, AT NTDT TRAT NTDT 2.3130 199,6875 2,2573 191,4375 5,9~19 22~ 6250 5:8047 263.511.7 6 0~34 225:6250 5,77B3 2.~4,]~2~ 5.8577 236,7656 '999,2500 '999 2500 '999 2500 -999 2500 '999 2500 -999 2500 6 0742 226,5000 '999,2500 '999,2500 ** TAPE TRAILER ** SERVICE NA~ :SER'V'IC DATE :82/08/23 .. ORIGIN :6546 TAPE NA~E : C~NTINUATYON # :01 NEXT TAPE NANE i COMMENTS :T~'PE COMMENTS TRAILER :( LVP O].O,HO1 VERtFICATIO~'~ LISTING ,PAGE 7 SERVICE .~nME :SE~VIC DATE :8210812.3 ORIGIN : REEL CONTINUATION ; ,'01 NEXT RE. EL W.aMF, : 'OCT, ~, .1982. ~mmmmmmmmmmm~mmmmmmmm~ ~mmmmmmmmmmmmmmmmmmmm~ VERIFICATION bI$~N$ I LVP 009.H03 VERIFICATION LISTING PAGE ** REEL HEADER SERVICE NAME ;SERVIC DATE :81/09! ORIGIN : REEL NAME :REEL ID CONTINUATION ~ :01 PREVIOUS REEL COMMENTS :REEL COMMENTS SERVICE NAME :SERVIC DATE :81/09/ i ORIGIN :1070 TAPE NAME 162131 CONTINUATION # :01 PREVIOUS TAPE : COMMENTS :TAPE COMMENTS ** FILE HEADER ** FILE NAME :SERVIC,O01 SERVICE NAME : VERSION # : DATE I MAXIMUM LENGTH : 1024 FIGE TYPE I. PREVIOUS FILE : INFORMATION RECORDS MNEM. CONTENTS mmmm mm~m~m~m CN I' SOHIO AGASKA PETRO, WN : M-1 5 FN I PR BAY RANG: t2~DHOE TOWN: 11N SECT: 01 COUN~ NORTH SLOPE STAT: AGASKA CTR¥: NAM MNEM CONTENTS PRES: NEDIT4F RECORD TYPE 047 RECORD TYPE 047 ** UNIT TYPE CATE SIZE CODE' mmmmmmmm mmmm mmmm~mmmmm mmmmmmmmmmmm . mmmm '000 000 020 065 000 000 004 065 000 000 012 065 000 0'00 003 065 000 000 003, 065 000 000 002 065 000 000 0~2 065 '000 000 006 065 000 000 004 065 UNIT TYPE .CATE SIZE CODE 000 000 OO7 065 LVP 009,H03 VERIFICATION LISTING RECORD TYPE 047 ** ** DATA FORMAT RECORD ** ENTRY BLOCKS TYPE 4 9 0 SIZE REPR ~DE ~ ' . 4 73 4 .65 1 66 DATUM SPECIFICATION BLOC MNEM SERVICE SERVICE UN ID DEPT SFLU ISN IbM ISN ILO ISN GR NPHI DRHO GR CALI ISN NRAT ISN RHOB ISN DT GR BHC ORDER IT A.P! AP1 API APl FI.bE LOG TYPE CLASS MOD NO, FT 0 0 0 0 0 OHMM 0 0 0 0 0 MV '0 I O. 0 .0 OHMM 0 0 0 0 0 OHMM 0 12 46 0 O' GAPI, 7 31 32 0 0 PU '0 68 .2 0 0 G/C3 0 44 0 0 0 GAPI. 0 31 32 0 0 IN 0 28 3 0 0 0 42 I 0 0 G/C3 0 35 I 0 0 US/F 0 52 32 0 0 GAPZ 60 31 32 0 0 DATA DEPT ILD GR DT 9668,000 '999,250 -999,250 75,375 SFLU GR CALl OR -999.250 SP -999.250 NPHI -999.250 NRAT 92.438 DEPT GR DT 9600,000 5.922 67,000 75.000 SFLU GR CALl GR 12.195 SP 51.031 NPHI 8,234 NRAT 61,969 DEPT GR DT 9500.000 3.572 109.500 82,000 SFGU GR CALl GR 3,150 SP 106,875 NPHI 9,047 NRAT 101,375 DEPT GR DT 9400,000 1,792 16,250 87,188 SFLU GR CALl GR 4,176 SP 16,781 NPHI 8.289 NRAT 14,859 DEPT ILD GR 9300,000 ,33 6 2 ,500 SFLU GR CALl 8,258 SP 20.312 NPHI 8,312 NRAT ENTRY .1 6O ,tiN 0 ZE PROCESS SAMPLE LEVEL 4 0 4 .0 1 4' '0 1' 4 0 4 0 4 0 4 0 4 0 4 .0 1 4 0 4 0 4 0 1 4 0 4 0 -999.250 IbM -999,250 DRHO -999,250 RHOB -40.063 IbM 13.623 DRHO 1,900 RHOB '2,088 IbM 25.195 DRHO 2.744 RHOB -65,938 ILM 22,607 DRHO 2,508 RHOB -61,875 IbM 20,947 DRHO 2.400 RHOB PAGE REPR 68 68 68 68 -999.250 :999.25o 999,250 6,211 0.069 2,561 3,492 0.082 2,664 1.883 -0,002 2.238 6.312 0,042 2,346 LVP 009.H03 VERIFICATION LISTING PAGE 3 DT 90.750 GR 9200.00 ~BPT 23 60 LD . GR 33.28 DT 75.75 SFLU GR CALl GR DEPT 9100.000 SFLU ILD 50,938 GR GR 26.297 CALl DT 94.750 GR DEPT 9000.000 ILD 4,410 GR 64,438 DT 76.188 DEPT 8900 000 IbD 16:828 GDR 50,094 T 61.186 DEPT ~800 000 ILD 999:250 GR 58.813 DT -999.250 DEPT 8700,000 ILD -999,250 GR -9.99.250 DT '999.250 8600,~0 ~EPT -999 0 LD .. GR -999,250 DT '999.250 SFLU GR CALl GR SFLU CALl SFLU GR CALl GR SFLU. GR CALl. SFLU GR CALl GR DEPT 8500,000 SFLU ILD -999'250 GR OR '999,2.50 CALl DT '999,250 GR DEPT 8400, ILD '999.~5O00 GR '999,250 DT '999,2'50 DEPT 8300,000 ILD -999,,250 GR -999',250 DT '999.250 DEPT ~200,000 ILD 999.250 GR -999.250 8FLU CAbI ' GR . SFLU GR CkbI ' GR SFLU . . 18. 031 28,094 SP 33,688 NPHI 8,406 NRAT 33,188 51.312 SP 28.922 NPHI 8,477 NRAT 23.734 3,527 57,063 8,641 74,188 49.719 54.125 NPHI 8.914 NRAT 37.625 -999.250 SP 62.094 NPH! , 50 -999. 65, -999.-999. '999, = 62. 999. '999, "99'9, 61. -9.99, -999, 250 SP 500 NPHI. 250 NRAT 250 0 SP 50 NRAT 25O 250 SP 406 NPHI 250 .NRAT 25O '999.2.50. SP 48,.125 NPHI "999.250 NRAT -999.250. ' . '999. . 49., '999'. -999. 250 SP 2563 NPH! 50 .NRAT 250 -999,250 40.531. NPHI -999.250 NRAT -50.312 ILH 13.672 DRHO 1.919 RHOB -45,094 IbM 22.217 DRHO 2.498 RHOB 0.154 ILH 15,039 DRHO 2.027 RHOB 9.859 ILH t.395 DRHO ,338 RHOB , 24 DRHO 4,129 RHOB "999'.250 I. LM '999.~50 DRHO -'999. 50 RHOB -999.250 IbM '999,250 DRHO -999.250. RHOB '999,250 IbM '999,250 DRHO '999,'250 RHOB '999',250 IbM =999'.250 DRHO -999,250 RHOB .'999,,250 IbM' :999,.250 DRHO 999,; 250 RHOB -999.'250. -999..250 'DRHO -999,,250 RHOB 21.156 0.018 2,418 34.688 0,000 2.250 3.178 0.021 2.516 19,469 ,003 .625 250 ,583 2,373 '999.250 '999,250 '999.250 =999,'250 =999'.250 '999.250 -999 25O -999:'250 -999.250 '99.9,250 '999. 250 '999.250 -999,250 -999.250 "999.250 ' =999.250 '999.250 -999,250 DT DEPT ILO GR DT DEPT lbo GR DT DEPT GR DT DEPT GR DT DEPT G~ DEPT GR DT DEPT GR DT DEPT GR DT DEPT GR DT DEPT GR DT DEPT GR 009,H03 VERIFICATION LISTING '-999.250 GR 810~,000 SFLU -99 ,.250 GR -999,250 CALl -999.250 GR 8000,000 SFLU -999,250 GR '999.250· 'CA. LI -999,250 GR . . 900,000 SFLU ~999,250 GR -99~,250 CAG! -99 ,250 GR 7800,000 SFhU '999,250 GR "999,250 CALI '999,250 GR 7700.000 SFLU -999,250 GR -999,250 CALl -999.250 GR 7600,000 SFLU '999,250 GR '999,250 CALl -999,250 GR 7500,000 SFLU '999,.~50 GR -999. GR 7400,000 SFLU -999.250 G~ -999,250 CALl -999.250 ~R 7300,000 SFLU -999.250 GR -999,250 CALl -999,250 GR 7200.000 SFbU -999.25O GR '999,250 CALl '999,250 OR 7100.000 SFLU =999,250 GR '999.250 CALI -999.250 -999 5O -99 5O -999 250 60~844 '99~0'250 =99 ,250 "'999,250 46,906 -999,250 -999,250 -999.250 -999,250 -999.250 63,063 -999,250 '999,250 '999,250 52,656 -999.250 -999.250 -999.250 54,156 -999, 50 -999,250 -999,250 45,250 -999,250-999,250 -999.250 46.125 -999.250-999.250 -999.250 48,125 -999,250 SP NPH! NRAT SP NPHI NRAT SP NPHI NRAT SP. NPHI NRAT SP NPH! NRAT NPHI NRAT NPHI NRAT SP NPH! NRAT NPHI NRAT NR~T SP NPRI NRAT -999.250 =999,250 -999.,25,0 .. DRH.O RHDB -9'9'9.250 'IL:M '999,250 DRHO '99.9,250 RHOB' -999 50 50 ...DRHO '999,250 RHOB ='999.'250 ILM' '999.250 DRHO '999,250 RHOB' :999,250 ILM. 999,250 DRHO '999.250 RHOB '999,250 ILM '999,250 DRHO -999,250 RHOB '999,250 ILM "999,250 DRHO '999,250 RHOB '999.250 ZGH '999,250 DRHO '999,250 RHOB '999.250 IhM '999.250 DRHO '999.250 RHOB '999.250 ILH '999.250 DRHO '999.250 RHOB '99g,250 Ih~ '999,250 DRHO '999,250 RHOB PAGE -999,250 .-'999,250 -999,250 -999,250 -999,250 '999,'250 "999,250 -999,250 : 9.9. 5o .999. 50 '999"250 -999.2~0 -999.2 0 -999.250 i99,250 99,250 999,250 ~999,250 999,250 -999.250 -999,250 -999.250 -999,250 9,250 99.250 '999.250 '999.250 '999,250 -999,250 -999,250 -999,250 LVP 009,H03 VERIFICATION LXSTXNG PAGE 5 -999,250 GR DEPT 7000 ZED -999 GR -999 DT -999 DEPT 6900 XLD -999 GR -999 DT -999 ~EPT .6800 LD 999 GR 999 DT '999 .000 SFLU ,250 GR ,250 .250 DEPT !700 XLD 999 GR 999 DT -999 DEPT 6600 ILD -999 GR -999 DT -999 DEPT 6500 ILD !99 GR 9999 DT 999 DEPT 6,t00 ILD -999 GR -999 DT -999 EPT 6300, LD -999, 'GR -999'., DT -999. ~EPT ~ OR -999 DT -999 DEPT 6100 -9.99 DT -999 DEPT 6000 ILD -999 GR -999 ,000 aFLU ,250 GR .250 CALX .250 GR .000 aFLU .250 GR 250 CALX 000 aFLU .250 CALX .250 GR ,000 aFLU ,250 GR ,250 CALX ,250 GR ,000 aFLU ,250 GR ,250 CALI ,250 GR .000 SFLU ,.250 GR ,250 CALl ,250 GR 00.0 aFLU 2.50 GR 250 CALX 250 OR ,000 aFLU ,250 GR ,250 CALX ,250 GR 000 SFLU ., 50 CALX ,250 GR ,000 aFLU ,~50 OR , 50 CALX -999 -999 50 -999-999 -999 41 -999-999 -999 76 -999-999 999 110 999 '999 '999 94 -999 -999 -999 48 -999-999 -999 55 -999 '999 -999 54 -999-999 -999 -999 -999 .53 -999-999-999 57 -999 °250 .250 ,531 .250 .250 .250 .719 .250 .250 .250 .875 .250 ,250 .250 ,438 .250 .250 . 75 .250 .'250 ,250 ,750 ,250 ,250 5O ,250 ,2'50 ,250 ,250 ,250 ,250 , 56 ,250 ,250 :250 ,.~19 ~0 ,250 ,250 SP NPH! NRAT SP NPHI NRAT ap NPH! NRAT SP NPHI NRAT ap NpH! NRAT ap NpH! NRAT SP NPHI NRAT SP NPH! . NRAT NPHI NRAT aP NPHX. NR.AT SP NPH! NRAT -999.250 -999,250 -999.250 -999.250 .-999.250 999.250 '999,250 '999,250 '999,250 -999.250 -999.250 -999.250 '999, '999,250 '999.250 '999,250 '999,250 ,. -999,250 -999,250 -999,250 -999,225'0 -999, 50 -99'9°250 ,999,~50 .-99.9, 50 -999,250 -999.250 -999,.2.50 -999,250 -999,250 -999,250 -999,250 DRHO RHOB IbM DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB DRHO 'RHOB DRHO RHOB DRHO RHOB DRHO' RHOB ~999.250 999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -99~,250 -99 .250 -999.250 -9991250 -999.250 "999,250 '999,250 "999,'250 '999,250 "999,250 '999,250 =9'99,250 -999,250 -999,250 -999,'250 '999,250 =999,250 -9'99.~50 '999, 50 '999,250 "999,2~0 '999,.2 0 '999.250 LVP 009.H03 VER IFICATION -999.250 GR DEPT 590 IhD -99~ GR -999 DT -999 O0 SFLU. '~50 GR .250 ,250 DEPT 5800,000 SFLU iLD -999,250 GR GR '999,250 CALl DT '999.250 GR DEPT 5700 000 SFLU ILD -999~250 GR GR -999.250 CAL! DT 999, ,250 GR DEPT 5600,000 SFLU I~D -999,250 GR GR -999.250 CAI~I DT '999,250 GR DEPT 5500,000 SFLU ILD '999,250 GR GR '999.250 CALl DT '999.250 GR DEPT 5400 ILD =999 GR =999 DT -999 DEPT 5300 ILD -999 GR -999 DT -999 DEPT 5200 ILD -999 GR -999 DT -999 DEPT 5100 I~D =999 GR -999 DT -999 DEPT 5000 IhD -999 GR -999 DT -999 ,000 SF~U 250 GR '250 CALI '250 GR . 000 SF~U '250 GR .250 CALl ,250 GR .000 SFLU .250 GR .250 CALl ,250 GR ,000 SFGU ,250 GR ,250 CALl ,250 GR ,000 SFGU ,250 GR ,250 CALl ,250 GR DEPT 4900.000 6FLU I~D -999,250 GR GR -999.250 CALl -999.250 -999,250 40,750 "999.250 '999.250 '999 250 '50~'500 '999..250 '999,250 '999,250 44.031 -999,250 '999.,250 '999.250 44,344 -999,250 '999,250 -999,250 57,813 -999 250 '999~250 '999.250 41,438 =999.250 -999.250 -999.250 48.625 -999.250-999,250 ' 99.250 94 .938 -99~,250 -999,250 -999,250 -~ .250 - 99.250 -999,250 43,531 '999,250 -999,250 9.250 '9~5.03! -999.250 SP NPHI NRAT NPH! NRAT NPHI NRAT .$p NPHI' NRAT SP NPH! NRAT SP NPHI NRAT ~P NPHI NRAT NRAT NPHI NRAT SP NPHI NRAT SP NPHI NRAT -999. '999..250. -.999,250 -999.2.50 ''.999.250 '999.2'50 '999,,250 '999.250 '-'99'9.2.50 :999, . 999,250 -999,250 =999,250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 '999.250 '999.250 '999.250 '999.250 '999.250 '999.250 DRHO. RHOB DRHO RHDB IbM DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB IbM DRHO RHOB DRHO RHOB DRHO RHOB DRHO RHOB '999,,250 '999,250 '999,250 .-99'9.250 9.99..250 -999.250 .-999,250 999,2'50 -999,2 50 9'99.250' 999.250 999.250 i999.250 g99'. 250 999.250 i999.250 999,250 999.250 '999,250 '999.250 '999.250 -999.250 -999.250 =999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 LVP 009.H03 VERIFICATION LISTING PA(IE 7 DT -999.250 (IR DEPT 4800 000 Sf'LU ILD '999:250 GR GR '999,250 CAbT DT '999.250 GR DEFT 4700,000 SFLU ILD '999,250 GR (IR '999,250 CALl DT '999,250 GR 4600,000 SrbU yEFT 99 250 OR LD '9 . OR '999.250 CALl DT -999,250 OR DEPT 4.:50i.000 SFLU II.D 99 .250 GR GR 99 ,250 CALl DT 999.250 OR DEFT 4400,000 SFLU ILD '999,250 GR GR '999,250 CALl DT '999,'250 GR DEFT 4300,000 SFLU ILD i9999,250 (IR OR 99 ,250 CALl DT 999,250 OR DEFT !200!000 SrbU lbO 99'9 250 Ge 99 250 CAbI DEPT 4100,000 SFLU ILD -99.99, 250 GR GR -99 .25..0 C'AbZ DT ,999,250 GR · 50 OR GR '999.250 CAb.I DT '999,250' GR ., oo.ooo GR '99'9', 250CALI DT '999,'250 GR PT !800!000 SFLU ~[D 999 250 OR GR 999 250 CALl· -999.250 -999.250 23,797 -999.250-999.250 -999.250 36.250 -999.250 '999.250 '999,250 43,625 -99~,250 -99 .250 -99~.250 3 .844 -99~.250 -99 ,250 '999,~50 35, 31 '999,250 '999,250 '999,250 35.094 ·'999,250 '999,250 '9'99.250 '36,906 -999.250 '999,250 4' -99 250 -9'99,.250. .'999,250 19.234 '999.250 '999,250 9,250 9~4,094 999.250 SP NPHI NRAT 8P NPHI NRAT SP NPH! NRAT NPH! NRAT NPHI NRAT SP NPH! NRAT $P NPHZ NRAT '$p NPHI NRAT SP NPHI. NRAT NPH! NRAT SP NPH! NRAT '999,250 IbM '999.250 DRHO '999.250 RHOB -999,250 lbR '999.250 DRHO '999.250 RHOB -999.250 ILH '999.250 DRHO '999,250 RHOB '999,250 IbM '999.250 DRHO '999,250 RHDB '999.250 ILH '999.250 DRHO -999.250 RHOB -999,250 IbM -999.250 DRHO -999.250 RHOB =999,150 '999, 50 DRHO "999,250 RHOB -999 250 IbM' -99:250 DRHO · -99~,2'50. RHOB -99.~ , DRHO' '9.99.250 RHOB ..~999,250 .I.~M 0 DRHO '99 'I.~0 RHOB' .9999,. -999,250 -999,250 DRHO -999,250 RHOB i!99,250 99.250 99.250 -999.250 -999.250 -999.250 =999.250 -999.250 =999.250 -99g.250 1999,250 999,250 -999.250 -999.250 -999,250 '999,250 '999,250 -999,250 =999,250 -999,250 =999,25.0 "999.2.5o -999.250 -999.250 .-999 .250 -9'99!250 -999 250 -9.99,250 -999,250 -999.25.0 -999,250 -999.250 -999,250 LV~ 009,H03' VERIFICATION LISTING DT -999..250 GR -999,250 DEPT 370~.000 SFbU -99~.~0 ILO ~'99 .~50 GR · 2 , 6 NPHI GR "999, 50 CALl "999,250 NRAT DT '999,250 GR ' "999,250 DEPT 3600.000 &FLU -999,,250 IbD -9~,250 GR .39,250 NPHI · -9 ,250 CALl "999,250 NRAT ~ -999,250 GR -999,.250 ooo ~EPT -999 5 LD ~2 0 GR ,406 NPHI GR -999,250 CALl "999,250 NRAT DT -999,250 GR -.999,'250 DEPT 3400,000 SrbU -99,9,250. lbo '999 '~0 GR 42.594 NPHI GR -999! 0 CALl. '-999.,.250 NRAT DT -999 250 GR '999,250 oo.ooo yEPT -999 250 GR , 38 NPHI LD , GR -999 250 CALl '999,~0 NRAT DT -999:,250 GR -999. 0 DEPT 3200.000 SFLU '999,250 SP ILD '999,250 GR 38,781 NPHI GR '999,250 CALl "999,250 NRAT DT '999,250 GR '999,250 DEPT 3100,000 SFLU '999,250 SP ILD '99g.250 GR 35.469 NPHI GR -999.250 CALl '999.250 NRAT DT '999,250 GR "999.250 DEPT 3000.000 Sf'LU '999,250 SP ZLD '999,250 GR 23,219 NPHI GR =999,250 CALl '999,250 NRAT DT '999.250 GE '999.250 D£PT ~900,000 SrbU :999.250 SP ILD 999.250 Ge 41.~44 NP"I GR '~99.250 CAGI 999.250 NRAT DT ' 99.250 Ge -999.250 DEPT 2800.000 SFbU -999.250 SP ZLD -999,250 GE 45,094 NPHI GR '999.250 CALl '999.250 NRAT DT '999,250 GR '999.250 DEPT 2700.000 SFLU -999,250 SP IbD "999.250 GE 46.344 NPHI GR "999,250 CALl '999,250 NRAT '999, '999,250 '999,250 ,9.99,250 '999'250 '999,250 .'999,250 '999,250 "'999,250 '999,250 '999,250 -999.~50 -999. ~0 '999,250. -999,250 -999,250 -999,250 -999.25O -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 ..IBM .DRHO RHOB IbM' DRHO RHOB DRHO' RHOB DRHO RHOB DRHO R. HOB IbM DRHO RHQB DRHD RHOB DRHO RHOB DRHO RHOB IbM DRHO RHDB DRHO RHOB PAGE -999°250 =999,25O =999.,.250 ,=999,250 =999,250 =9.99,250 =999,250 =9991250 =999,250 '-999,250 -999,250 -999,250 -999..250 -999.250 -999,250 -999,250 .-999,250 999,250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999.250 -999,250 -999,250 -999.250 LVP 009,H03 VERIFICATION LISTING PAGE 9 DT -999,250 GR -999,250 DEPT 2600.000 SFLU -999.250 SP ILO -999,250 GR 24.766 NPH! GE -999.250 CALl ~999.250 NRAT DT '999,250 GR 999,250 DEPT 2500,000 SFLU lED '999,250 GE GR '999,250 CALI DT '999,250 GE DEPT 2400,000 SFLU ILO -999,250 GR GE -999,250 CALl DT -999,250 GE DEPT ~300,000 SFLU ILO 999,250 GR GR '999.250 CALI DT -999.250 GE DEPT 2.263,500 8Fr. O ILO 999,'250 GR GR 999,250 CALZ DT :999,250 OR -999.250 SP 17.594 NPHI -999.250 NRAT -999,250 '999,250 SP 21,531 NPH! -999.250 NRAT '999.250 '999.250 SP 17.,203 NPHI '999,250 NRAT '999,250 '999,250 SP 21,188 NPHI :999,250 NRAT 999.250. FILE NAME :SERVIC,O01 SERVICE NAME VERSION # DATE : MAXIMUM LENGTH : 1024' FI~E TYPE NEXT FILE NAME ** TAPE TRAILER SERVICE NA~E ;SERVIC DATE :81/0 / 1 ORIGIN :1070 TAPE NA~E 62131 CONTINUATIO~ # :01 NEXT TAPE NAME COMMENTS :TAPE. COMMENTS *~ REEL TRAILER SERVICE NAME. :'SERVIC DATE :81/09/ 1 ORIGIN : REEk NAME :REEL ID '999,250 ILM '999.250 DRHO '999.250 RHOB '999,250 ILM '999,250 DRHO '999.250 RHOB -999.250 ILM '999,250 DRHO -999,250 RHOB -999,250 ILH '999,250 DRHO '999,250 RHOB =999,250 ILM =999,250 DRHO =999,250 RHOB -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -99~.250 -99 ,250 999,250 ~VP 009,H03 VERIFICATION PAGE CONTINUATION # NEXT REEb NAME COMHENTS IREEb COMMENTS ~~~ EOF
