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Home My WebLink About192-107CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. From:Lau, Jack J (OGC) To:Oliver Sternicki Cc:Leif Knatterud; PB Wells Integrity Subject:RE: [EXTERNAL] RE: A-18A (PTD#192107) POP UE request with TxIA comm Date:Wednesday, August 13, 2025 1:22:52 PM Thanks Oliver, You are approved to POP A-18A under eval for up to 30 days, given IA and OA pressures will be maintained below MOASP values. Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Wednesday, August 13, 2025 1:20 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Leif Knatterud <Leif.Knatterud@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: RE: [EXTERNAL] RE: A-18A (PTD#192107) POP UE request with TxIA comm Sorry, forgot to include these. Yes, testing has been done recently. 8/11/2025: CMIT-TxIA passed to 2517 psi 8/2/2025: MIT-OA w/ N2 passed to 485 psi With the recent passing pressure tests I don’t think it is necessary to repeat them post FCO. Oliver From: Lau, Jack J (OGC) <jack.lau@alaska.gov> Sent: Wednesday, August 13, 2025 12:58 PM To: Oliver Sternicki <oliver.sternicki@hilcorp.com> Cc: Leif Knatterud <Leif.Knatterud@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: [EXTERNAL] RE: A-18A (PTD#192107) POP UE request with TxIA comm Good afternoon Oliver, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. A few questions: What’s the integrity status and history of the production casing? When was the last MITIA or CMIT-TxIA? Was there a MITOA to N2 and/or liquid done post SC repair? With TxIA and a potential SC leak a CMIT-TxIA post-FCO may be prudent to verify the PC as the lone barrier. Thoughts? Jack From: Oliver Sternicki <oliver.sternicki@hilcorp.com> Sent: Wednesday, August 13, 2025 12:41 PM To: Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Leif Knatterud <Leif.Knatterud@hilcorp.com>; PB Wells Integrity <PBWellsIntegrity@hilcorp.com> Subject: A-18A (PTD#192107) POP UE request with TxIA comm Jack, A-18A (PTD# 192107) is an artificial lift producer, currently Not Operable for TxIA communication. On 4/19/2021, a patch was set across GLM#1(7473’-7493’ MD) to repair TxIA communication with a passing MIT-T to 2184 psi on 4/20/2021. On 7/12/2021, a conductor top job was executed under Sundry # 321-315 to repair a surface casing leak. When attempting to place the well on production in August 2021, the well would not flow and SL tagged what is thought to be fill in the tubing. At this same time TxIA communication issues began again with multiple failed TIFLs and subsequent GLV interventions. It was determined that the tubing patch had begun to leak and was it was eventually pulled on 10/24/2022. Hilcorp request permission to POP A-18A under eval for up to 30 days, post coil tubing FCO, to evaluate the success of the conductor top job repair from 2021. If the conductor top job repair is found to be successful, the tubing will be patched again and the well returned to Operable. A-18A will require gas lift to flow during the under eval period. IA and OA pressures will be maintained below MOASP values. Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Supervisor Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, pleaseimmediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently deletethis message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. 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Development Exploratory Service 5 Permit to Drill Number:192-107 6.50-029-20630-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10150 7700 9959 6905 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" x 30" 37 - 115 37 - 115 Surface 2632 13-3/8" 37 - 2669 37 - 2669 5380 2670 Intermediate 7495 9-5/8" 300 - 7795 300 - 6982 6870 4760 Production 7582 7-5/8" 35 - 7615 35 - 6835 6890 4790 Perforation Depth: Measured depth: 9700 - 9958 feet True vertical depth:8788 - 9042 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 33 - 7737 33 - 6935 7700 6905Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer Liner 2522 7" 7614 - 10136 6835 - 9217 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): Top off conductor with 59.4-gal of 14.3-ppg HES Lockcem cement Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 249104431082192291 Well not online Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9231 Sundry Number or N/A if C.O. Exempt: 321-315 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Conductor Top Job Operations shutdown Change Approved Program 5 Conductor x Surface Casing annulus from Surface to 9' Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0047472, 0028286 PBU A-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations None 10056 9138 By Samantha Carlisle at 9:55 am, Aug 04, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.08.04 09:36:42 -08'00' Stan Golis (880) RBDMS HEW 8/5/2021 MGR04AUG2021 DSR-8/4/21 ACTIVITY DATE SUMMARY 7/12/2021 HES Cementing Topped off the conductor with 59.4 gal of 14.3ppg HES Lockcem. Pad operator notified of well status - New OA MAOSP 50psi. ***Job Complete*** 7/20/2021 ***WELL S/I UPON ARRIVAL*** (cement squeeze) MADE MULTIPLE BAILER RUNS TO XX PLUG @ 7723' MD.(recovered 1/2 gallon of scale) EQUALIZED & PULLED 2-7/8" XX-PLUG FROM NIPPLE REDUCER @ 7723' MD. ***WELL S/I ON DEPARTURE, PAD-OP NOTIFIED OF WELL STATUS*** Daily Report of Well Operations PBU A-18A Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:192-107 6.API Number:50-029-20630-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0047472 Property Designation (Lease Number):10. N/A 8. PBU A-18A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Conductor Top Job Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10150 Effective Depth MD: L-80 11. 7/10/2021 Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wrivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9231 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7700, 6905 No SSSV Installed Date: Liner 2522 7" 7614 - 10136 6835 - 9217 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 2669 37 - 2669 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 115 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HBBP Packer 9700 - 9958 8788 - 9042 4-1/2" 12.6#33 - 7737 Production 7723 6924 7723 9959 37 - 115 13-3/8" 9-5/8" Contact Phone:907.777.8547 Date: 4760 78 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2632 5380 Intermediate 7495 300 - 7795 300 - 6982 7582 7-5/8"35 - 7615 35 - 6835 6890 4790 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Meredith Guhl at 12:23 pm, Jun 25, 2021 321-315 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.24 17:27:31 -08'00' Stan Golis (880) SFD 6/25/2021 DSR-6/25/21 10-404 SVS test within 5 days of put back on production. MGR06JUL21 SFD 6/25/2021 , ADL 0028286 dts 7/6/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.06 15:28:12 -08'00' RBDMS HEW 7/7/2021 Conductor Top Job Well:A-18A PTD:192-107 Well Name:A-18A API Number:50-029-20630-01 Current Status:SI Rig:SL Estimated Start Date:7/10/2021 Estimated Duration:2 Days Regulatory Contact:Abbie Barker Permit to Drill Number:192-107 First Call Engineer:Wyatt Rivard (907) 777-8847 (O)(509) 670-8001 (M) Second Call Engineer:Aras Worthington (907) 564-4763 (O)(907) 440-7692 (M) Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent SI Surface Pressure: Min ID: Max Angle: 3310 psi @ 8,800’ TVD 3310 psi @ 8,800’ TVD 2430 PSI 1850 psi 3.725” XN @ 7723’ MD 39 deg @ 5500’ 7.3 PPGE | (Average Ivishak BHP) 7.3 PPGE | (Average Ivishak BHP) (Max BHP-(0.1 psi/ft x 8,800 TVD) (Taken on 4/16/21) Brief Well Summary: A-18 is a gas lifted Ivishak producer in the water flood area. The well has been SI for 18 years. When the well went offline it had a known gas lift mandrel leak and a surface casing leak measured at ~5’ below the OA valve. The well was recently pop’d under eval for 30 days and appears to be economic to repair. The leaking GLM #1(7480’ MD) was patched successfully on 4/19/2021. In June 2021, an attempt was made to excavate and externally patch the surface casing leak. Conductor was removed to ~7 ft below OA valve and SC x Conductor annulus was cleaned out to ~ 9ft below OA valve. The area of suspected leak was found to have minor pitting but no holes. OA was then fluid packed and displaced with N2 to retest for leak depth. Leak was strappedat ~20’4” below OA valve putting it below what is currently accessible for excavation and external casing repair. Moving forward,a conductor top job will be performed down the ~ 7ft of SCxConductor annular space to isolate the SC leak. The OA will be operated at a reduced 50 psi MOASP and fluids will be evacuated from OA to below the leak depth to provide a buffer for thermal fluctuations. Objective:Perform a conductor top job to isolate SC leak. Notes on Wellbore Condition: x Well is secured with XX Plug at 7723’MD x Passing CMIT-TxIA to 2398 psi on 11/11/20 x Passing MIT-T to 2000 psi on 4/20/21. Sundry Procedure (Approval required to proceed): Conductor Top Job 1. Pump sealant (Squeezecrete, Well Lock, or similar product) into the SC x Conductor annulus to the top of conductor a. During previous repair attempt, gravel was evacuated from SC x Conductor annuls to ~7ft below top of conductor. b. 13-3/8”x20” annular volume = .18 bpf c. Cement volume from top of gravel to top of conductor= .18 bpf x 7 ft= 1.3 bbls 2. Re-install flowline and instrumentation. 3. Install pressure transmitter with 50 psi alarm on OA Conductor Top Job Well:A-18A PTD:192-107 4. Hang Sign Off OA valve - “Conductor Top Job – OA MOASP 50 psi. Do Not Add Fluid to OA” Slickline 5. MIRU SL unit. 6. Pressure test to 300psi low and at least 2000psi high. 7. RIH and pull XX plug in Nip Reducer at 7718’ MD 8. RDMO Operations / DHD 9. Bring well back on production and monitor SC x Conductor annulus to confirm SC leak has stopped. a. Maintain open bleed on the OA during startup. b. Once thermally stable, use small diameter tubing to evacuate freeze protect from OA to depth of 50-100ft. 10. Obtained AOGCC witnessed SVS test within 5 days of return to production. Attachments: 1. As-built Schematic PCE tested to a minimum of predicted ~MASP 2430 psi. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:192-107 6.50-029-20630-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10150 7723 6924 7700 9959 7723 6905 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" x 30" 37 - 115 37 - 115 Surface 2632 13-3/8" 37 - 2669 37 - 2669 5380 2670 Intermediate 7495 9-5/8" 300 - 7795 300 - 6982 6870 4760 Production 7582 7-5/8" 35 - 7615 35 - 6835 6890 4790 Perforation Depth: Measured depth: 9700 - 9958 feet True vertical depth:8788 - 9042 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 33 - 7737 33 - 6935 7700 6905Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer Liner 2522 7" 7614 - 10136 6835 - 9217 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 249104431082192291 Well not online Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9231 Sundry Number or N/A if C.O. Exempt: 321-225 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028286, 0047472 PBU A-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Attempt Surface Casing Repair By Samantha Carlisle at 2:53 pm, Jun 21, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.21 14:37:35 -08'00' Stan Golis (880) ACTIVITY DATE SUMMARY 5/23/2021 T/I/O = 1750/1750/0. Temp = SI. Bleed TBG & IA (Pre SC excavation). No wellhouse, flowline or AL. Bled the TBG from 1750 psi to 500 psi in 4 hours (~20 bbls). During the TBG bleed the IAP decreased to 350 psi. SV, WV = C. SSV, MV = O. IA, OA = OTG. 02:00 5/24/2021 T/I/O = 270/470/0. Temp = SI. Bleed WHP's to 0 psi (pre SC repair). No flowline, wellhouse or AL. TBG FL @ 240' (3.6 bbls). IA FL @ 1090' (30 bbls). Bled the IAP from 470 psi to 0 psi in 2.5 hours (all gas, BT). During the IA bleed the TP decreased 10 psi & the TBG/IA FL remained unchanged. Bled the TBG from 260 psi to 0 psi in 2.5 hours (Mostly gas, BT, FTS). During the TBG bleed the IAP increased 2 psi. TBG FL unchanged. Bled the IAP from 2 psi to 0 psi in 5 minutes (all gas). The TP increased 8 psi and the IA remained unchanged in the 30 minute monitor. FWPs = 8/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:40 5/25/2021 T/I/O = 9/2/0. Bleed TBG & IA to 0. RU CIW hydraulic lubricator & set CIW H BPV #130 @ 120". Remove companion flange & VR plug from CSG spool side outlet. Strap OA & find FL @ ~95'. RU integral flange & 2" block valve. Pull wellhead scaffolding. Remove THA x TBG spool bolts. Pull 13-5/8" McEvoy THA & 4" CIW tree in 1 pick. Install Well Support Structure Adapter Flange to 13-5/8" McEvoy TBG Spool. Photo document each step per AOGCC requirement. 5/25/2021 T/I/O=300/400/0 Temp ? PPPOT-T (Passed) Stung into test port 2400 ps bled to 0, tested tubing hanger to 5000 psi for 30 min. 200 psi loss in the first 15 min 20 psi in the secd15 mn. 220 psi loss over 30 min (Pass) 5/26/2021 *Surface Casing Repair* Remove floor kit. Place heaters in the cellar and tent it to melt the ice/snow. Evacuate all fluids from cellar and cut away spray in liner, gravel underneath. Level pad in preparation for setting the WSS. 5/27/2021 *Surface Casing Repair* Conduct Critical Lift (lift exceeds 75% of max pick) pre-job meeting with crane operator, rigger, WPO, WP Lead & facility safety rep. Set Well Support Structure over wellhead. Install overhead carrier clamps on I-beam. Remove motor covers. Remove traveling bolts from all four corner posts. WOA Fire Department signs off on Confined Space Rescue Plan at 1600. 5/28/2021 *Surface Casing Repair* Install extraction webbing on overhead beam. Cut away well cellar spray-in liner. Install fire blankets around the top of the conductor. Excavate to 1' below the bottom of the well cellar box using jackhammers and a super sucker. Set a heater trunk in the well cellar and cover with visqueen to thaw the gravel. Tie-in instrumentation trailer. LDFN. 5/29/2021 *Surface Casing Repair* Evacuate water/gravel mix from cellar. Use a torch to remove the southern well cellar wall to allow the shoring sleeve sytem to be centered on the well. Set shoring sleeve system in the excavation. Place rig mats around the shoring sleeve to cover all gaps. Erect scaffolding around shoring sleeve. Continue excavation with jackhammers and super sucker to 2' below the bottom of the well cellar. Cover and heat excavation. LDFN. 5/30/2021 *Surface Casing Repair* Hard wire instrumentation trailer to generator. Verify computer system is operational. Continue excavation to 5' below bottom of well cellar floor. Lower cross members on the iron cross to make up to the wellhead knuckle with ~8" of travel in either direction. LDFN. Daily Report of Well Operations PBU A-18A Daily Report of Well Operations PBU A-18A 5/31/2021 *Surface Casing Repair* Install additional shoring at the south end of the well cellar. Install upper 3' section of shoring sleeve and excavate to 6-1/2' below the bottom of the well cellar. Attempt to raise the WSS, but encounter encoding errors on B leg. It appears that B leg gets in a bind at 2.9" and 5.9". By bringing each leg up 1/2" to 1" at a time, we were able to raise the WSS to 8". Bring the WSS to zero. LDFN. 6/1/2021 *Surface Casing Repair* Continue excavation to 7' below bottom of well cellar. Discover the inside jack screw on the B leg has seized and stripped the threads in the bonnet x housing assembly. Work to disassemble the jack screw from the structure cross member and attempt to remove the entire assembly from the top. LDFN. 6/3/2021 *Surface Casing Repair* Remove broken jack screw and install a new one on leg B.Did not have to remove the whole upper structure to replace jack, it was replaced from the top after jacking the upper structure up to 24". 6/4/2021 * Surface Casing Repair* Continue to reconnect jack screw and fully cycle stucture to make sure everything is functioning properly. 6/5/2021 * Surface Casing Repair* Install iron cross on the structure. ND the knuckle and reposition on the tubing spool to accomodate for the lean of the well head. Installed basket ontop of the iron cross to secure. Wells Support Stucture is connected to the well, will start to cut out outer part of the conductor and insolation off in the morning. 6/6/2021 *Surface Casing Repair* Pulled tension on the well using the Wells Support Structure in 500 LBS incriments all the way up to 10,000LBS. Cut outter cuductor off and remove insulation and prep the surface casing to be cut off. 6/7/2021 *Surface Casing Repair* Drilled a hole in the Surface casing @5', pumped in 1/2 barrels fresh water from the top taking returns out the bottom. R/U nitrogen purge on OA. Purge nitrogen into OA while taking returns through hole in surface casing and up outer casing until monitoring showed nitrogen to surface. Shut in Nitrogen Purge. NES on location cut surface casing off. Removed all gravel and prepped exposed casing for welding on sleeve. 6/8/2021 T/I/O = BPV/0/0. Temp = SI. Leak Depth Determinition (Eval SC leak). OA FL @ 130'. Used 8 bbls Diesel to fluid pack OA. Increased OAP w/ N2 to 30 psi several times for ~1 hr taking fluid returns from conductor to Vac truck. N2 bubbling in conductor at the 9 o'clock position and 12.6 oxygen level reading. Bled OAP to 0 psi. Strapped OA FL. Leak depth @ 20' 4". Final WHPs = BPV/0/0. IA, OA = OTG. 15:30 6/8/2021 *Surface Casing Repair* Buffed exposed surface casing and inspect for hole which could not be detected. Sprayed casing w/ soap applied nitrogen gas to OA no visible bubbles on casing. Nitrogen started to bubble out of conductor gravel. Performed leak depth determination by filling OA with diesel and displacing with N2 until N2 was detected at surface in the conductor. Strapped OA and found hole at 20'4". 6/9/2021 *Surface Casing Repair* Remove 30" of gravel from conductor utilizing a Cusco, unable to get any deeper. Mistras did a 6"x6" grid UT inspection on the exposed surface casing. 6/13/2021 * Surface Casing Repair* Re-use contuctor that was removed and welded it to the bottom cut and on top to the landing ring. Prep to rig down the WSS. Job In Progress. 6/14/2021 *Surface Casing Repair* Disconnect WSS from wellhead and NU theTHA and pressure test.Job Inprogress. Daily Report of Well Operations PBU A-18A 6/15/2021 * Surface Casing Repair* Pull shoring box and backfill excavation.Prep to demobe WWS. Job In Progress 6/16/2021 *Surface Casing Repair* Continue surface equipment demobe. A-18 Surface Casing Excavation- 05/25/21 1) Rig up to the tree cap with Altec crane and remove THA x tubing spool bolts- 2) Remove 4” Cameron tree and 13-5/8” McEvoy 5 Seal Tubing Head Adapter-Install Well Support Structure Adapter Flange needs to be set with the hinge parallel to the wellhead lean. Pictures show it 90* off. We had to adjust after trying to install cross. 3) Remove Floor Kit- Melt & evacuate all fluids from cellar 05/26/21 4) Install WSS Base 05/27/21 1) Cut away well cellar spray-in liner 05/28/21 2) Finish Day 1 excavation 1’ below the bottom of the existing well cellar- 1) Install shoring sleeve system- 05/29/21 2) Finish day 2 excavation 2’ below the bottom of well cellar- 1) Continue excavation to 5’ below the bottom of the well cellar- 05/30/21 1) Install upper 3’ section of shoring sleeve & excavate to 6-1/2’ below bottom of well cellar- 05/31/21 1) Troubleshooting WSS leg screw jack from 6/1/21-6/5/21 1) Connect Iron Cross to the Well Support Structure adapter flange. Note: had to reset the adapter 06/5/21 flange to compensate for the lean of the well head. 1) Cut outer skin of insolated conductor along with the foam insulation down to 5’. 6/6/21 1) Drill a hole at 5’ and flush conductor x surface casing with water. 6/7/21 2) Cut conductor off at 5’ bellow the landing ring. 1) Attempt to find hole in exposed surface casing with N2, detected N2 from conductor. 06/8/21 Leak Depth Determination revealed the leak at 20’ 4”. 1) Evacuate gravel out of conductor down additional 30” below conductor cut using cusco pump. 06/9/21 Unable to get any deeper. Perform UT grid of exposed surface casing. Deepest pits still .4”thick. 2) Decision made to discontinue excavation due to inaccessibility of new leak depth 06/10/21 1) Weld conductor and landing ring back onto well 06/13/21 1) Disconnect well support structure. Rig down WSS and NU and test tree. 06/14/21 1) Pull shoring box and backfill excavation 06/15/21 Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:192-107 6.API Number:50-029-20630-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 0047472 Property Designation (Lease Number):10. 341H 8. PBU A-18A 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Surface Casing Repair Op Shutdown GAS GSTORWAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5StratigraphicService WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 10150 Effective Depth MD: L-80 11. Commission Representative: 15. Suspended Contact Name: Wyatt Rivard Contact Email: wrivard@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: 5OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9231 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 7700, 6905 No SSSV Installed Date: Liner 2522 7" 7625 - 10147 6843 - 9228 7240 5410 Well Status after proposed work: 16. Verbal Approval: Change Approved Program 37 - 2669 37 - 2669 14. Estimated Date for Commencing Operations: BOP Sketch 37 - 115 Structural 6870 Proposal Summary 13. Well Class after proposed work: 4-1/2" TIW HBBP Packer 9700 - 9958 8788 - 9042 4-1/2" 12.6#33 - 7737 Production 7723 6924 7723 9959 37 - 115 13-3/8" 9-5/8" Contact Phone:907.777.8547 Date: 4760 78 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2632 5380 Intermediate 7495 300 - 7795 300 - 6982 7582 7-5/8"35 - 7615 35 - 6835 6890 4790 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2430 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. 5/18/21 By Meredith Guhl at 8:30 am, May 04, 2021 321-225 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.03 17:02:03 -08'00' Stan Golis (880) SFD 5/4/2021 SFD 5/4/2021 DSR-5/4/21 , ADL 028286 Photo document repair for inclusion in 10-404 MGR14MAY21 10-404 dts 5/14/2021 JLC 5/14/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.05.14 10:39:05 -08'00' RBDMS HEW 5/14/2021 SC Leak Repair Well:A-18A PTD:192-107 Well Name:A-18A API Number:50-029-20630-01 Current Status:SI Rig:SL+EL+WSS Estimated Start Date:5/18/2021 Estimated Duration:7 Regulatory Contact:Abbie Barker Permit to Drill Number:192-107 First Call Engineer:Wyatt Rivard (907) 777-8847 (O)(509) 670-8001 (M) Second Call Engineer:Noel Nocas (907) 564-5278 (O)(907) 229-9532 (M) Current Bottom Hole Pressure: Max Bottom Hole Pressure: Max. Proposed Surface Pressure: Recent SI Surface Pressure: Min ID: Max Angle: 3310 psi @ 8,800’ TVD 3310 psi @ 8,800’ TVD 2430 PSI 1850 psi 2.45” ID Patch @ ~7494’ MD 39deg @ 5500’ 7.3 PPGE | (Average Ivishak BHP) 7.3 PPGE | (Average Ivishak BHP) (Max BHP-(0.1 psi/ft x 8,800 TVD) (Taken on 4/16/21) Brief Well Summary: A-18 is a gas lifted Ivishak producer in the water flood area. The well has been SI for 18 years. When the well went offline it had a known gas lift mandrel leak and a surface casing leak. The well was recently pop’d under eval for 30 days and appears to be economic to repair. The leaking GLM #1(7480’ MD ) was patched on 4/19/2021. Objective:Excavate and weld an external surface casing patch to restore OA integrity. Notes On Wellbore Condition: x Well is secured with XX Plug at 7723’MD x Passing CMIT-TxIA to 2398 psi on 11/11/20 x Passing MIT-T to 2000 psi on 4/20/21. x Surface casing leak found ~63” below the OA valve on 3/19/13 x Cellar is ~44” deep Pre-Sundry Work: Prep Work 1. Disconnect flowline and instrumentation. 2. Remove wellhouse. 3. Complete an ACWR (Area Civil Work Request) which includes a locate for all utilities, thermosyphons and all underground infrastructure. 4. Disconnect flowline and instrumentation. 5. Verify tubing, IA and OA pressures have been bled to 0psi. 6. Sniff cellar andadjacent area with multi-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations 7. Vac out gravel from well cellar down to cellar liner to remove residual hydrocarbons. Cut cellar floor and vac out additional 2’ of fill to provide more space for conductor removal. 8. Install fire blankets around the conductor landing ring to protect surface casing holes from hot machining debris. Sundry Repair Procedure (Approval required to proceed): Note: For sundry repair work, maintain a daily activity log with brief description and photos of work for submission to AOGCC with 10-404. appears to be economic to rep well has been SI for 18 years. SC Leak Repair Well:A-18A PTD:192-107 Surface Casing Repair 9. Sniff cellar and adjacent area with mutli-gas meter for LEL, CO, H2S and 02. Ensure confined space, egress and ventilation is adequate for operations 10. Excavate and install shoring to a depth of ~6-8’ below existing cellar floor to provide enough room to access the leak site. a. Primary plan is to use modular shoring sleeve set inside of existing well cellar. b. All excavations will comply with the ASH handbook and OSHA Regulations. c. A competent person will be onsite during the excavation and perform daily checks prior to entry by personnel. 11. Install high volume water pumps into a low spot in the floor of the excavation if needed. a. In instances of excessive ground water inflow, previous excavation repairs have benefited from placing a sump pump in a hole in front of or adjacent to well. 12. Move in and rig up Well Support Structure. Place rig mats as needed to level out support structure legs. 13. Install BPV. 14. Nipple down tree at master valve or tubing head adapter as needed to makeup Wellhead Support Structure adapter flange. 15. Prepare to transfer load to the Well Support Structure. Pretension load cells according to operating manual. 16. Pull 10,000 lbs (Wellhead Weight) gradually building up load in 500 lb increments. a. Monitor the wellhead for any signs of movement and discontinue increasing tension if movement observed. 17. Once wellhead neutrally loaded, install secondary containment around lower edge of conductor. 18. Drill or cut holesin the conductor roughly 1 ft and 5ft below the landing rig to ensure adequate space for surface casing patch. 19. Remove cement as needed to confirm weldable, uncorroded surface casing at hole depth before cutting conductor. 20. Flush conductor with water from the landing ring while taking fluid returns from the lower inspection holes. Flush until clean returns are observed. 21. Install N2 purge equipment for the conductor and OA. a. Use of an N2 cap/purge will be determined on site, prior to proceeding, with accurate gas readings and fluid returns observed. b. Prior to cutting conductor, install continuous four-way gas meter for LELs & N2 from the conductor. c. Hot work permit to outline if adjacent wells will require shut in as part of safety mitigations. 22. Cut and remove conductor from above the 5 ft inspection holes. a. Primary cutting option is to use an air arc torch but the Hot Work Permit for this portion of the job will dictate if an alternative cutting method will be required. b. Two horizontal cuts (below landing ring and one at bottom of conductor section) and two vertical cuts will be required to remove the conductor. Alternately, if there is not sufficient room to drop the landing ring below the patch area, the vertical cut may be carried all the way up and through the landing ring. 23. Chip away excess cement from the surface casing. Buff and prepare surface casing for inspection and welding. 24. Inspection department to UT the exposed surface casing. b. Inspect for any additional holes below landing ring. c. Areas to patch to be identified marked and inspected on a grid to ensure competency for welds SC Leak Repair Well:A-18A PTD:192-107 25. Install 14.625” ID clamshell patch. a. Note that there may be a 1-3ft pup joint with collared connection below the starting head that may need to be straddled to weld to good metal above and below leak. b. Circumferentially weld band/spacer rings to the surface casing for the upper and lower patch areas i. Band material: A572-50 or A516-70N, ID=13.375” thickness=.75”. c. Install clamshell patch and weld circumferentially to the spacer rings and vertically to the other patch half. ii. Patch material: A572-50 or A516-70N, ID=14.625” thickness=1/2 or 5/8”. 26. Inspect the welds to ensure competency. 27. Attempt an OA integrity test to 200psi to confirm weld integrity a. If unable to reach200 psi due to open shoe, maintain max rate/pressure with triplex and observe for at least 5 min to confirm no leaks. 28. Pull BPV and RDMO Well Support Structure 29. Weld cut conductor halves or new conductor pipe back onto conductor. Re-install landing ring or centralizer. 30. Backfill ground around the conductor and re-install cellar floor. 31. Re-install flowline and instrumentation. Post Repair Work 32. Cement SC by Conductor Annulus back to within ~1ft of conductor top. 33.Install Corrosion Inhibitor in SC by Conductor Annulus up to the conductor top. Slickline 34. MIRU SL unit. 35. Pressure test to 300psi low and at least 2000psi high. 36. RIH and pull XX plug in Nip Reducer at 7718’ MD 37. RDMO 38. Turn well back over to operations. Obtained AOGCC witnessed SVS test within 5 days of return to production. Attachments: 1. As-built Schematic 2. Wellhead/Flutes Photo *See email from W. Rivard (Hilcorp) to S. Davies (AOGCC) dated 5/4/2021 * 1Guhl, Meredith D (CED)From:Davies, Stephen F (CED)Sent:Tuesday, May 4, 2021 2:07 PMTo:Guhl, Meredith D (CED)Cc:Boyer, David L (CED)Subject:FW: [EXTERNAL] PBU A-18A (PTD 192-107; Sundry 321-225) - QuestionAttachments:A-18A - 12-11-92 (7-in LNR).pdfMeredith, To clarify the record for PBU A‐18A, please print the email below along with the attachment for the paper file and place corresponding images in Laserfiche. Thanks for your help. Thanks again and stay safe, Steve CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov. From: Wyatt Rivard <wrivard@hilcorp.com> Sent: Tuesday, May 4, 2021 11:55 AM To: Davies, Stephen F (CED) <steve.davies@alaska.gov> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov>; Abbie Barker <Abbie.Barker@hilcorp.com> Subject: RE: [EXTERNAL] PBU A‐18A (PTD 192‐107; Sundry 321‐225) ‐ Question Hello Steve, Digging into this one, it looks like they partially combined the 7‐5/8” tie‐back liner with the 7” production liner on the original A‐18A sidetrack 10‐407 dated 2/24/1993. They report the 7‐5/8” depth down to 7615’ MD (top of the 7”) but they also reported 561 ft^3 (100 bbls) of cement which was the cement volume pumped on the 7” production liner. The 7‐5/8” tie‐back had a smaller 17 bbl (106 ft^3) cement job pumped at the liner lap. With all of that, the casing, liner and cementing record on original 10‐407 should have looked something like this: 2 The 7” has been reported on more recent 10‐403, 10‐404’s starting in 2016 but I don’t see anywhere that cement volumes would have been reported besides the incorrect 10‐407. The 7” casing depth of 10147’ is likely corrected to original A‐18 motherbore RKB height (~35’) whereas 10136’ is at the A‐18A sidetrack tally RKB height (~25’). The 7” casing tally is attached and daily drilling reports including running of 7” and 7‐5/8” liners included below for reference. Please let me know if you need additional information. Thank You, Wyatt A‐18A 7” Production Liner and 7‐5/8” Tie Back Running 3 4 Wyatt Rivard | Operations Engineer |Hilcorp Alaska, LLC O: (907) 777-8547 | C: (509)670-8001 | wrivard@hilcorp.com 3800 Centerpoint Drive, Suite 1400 | Anchorage, AK 99503 From: Davies, Stephen F (CED) <steve.davies@alaska.gov> Sent: Tuesday, May 4, 2021 9:24 AM To: Wyatt Rivard <wrivard@hilcorp.com> Cc: Rixse, Melvin G (CED) <melvin.rixse@alaska.gov> Subject: [EXTERNAL] PBU A‐18A (PTD 1952‐107; Sundry 321‐225) ‐ Question Hi Wyatt, 5While reviewing Hilcorp’s Sundry Application for this well, I noticed a minor discrepancy. The bottom of the 7‐inch liner is listed on the Sundry Application form as 10,147’ MD, but on the accompanying schematic drawing it is listed as 10,136’ MD. These same footages are shown on a previous Sundry Application by BP (Sundry 316‐172) dated March 2016. On the original Completion Report for this well and also on a Sundry Report dated November 1993, I do not see any mention of a seven‐inch liner at all. Have I missed something? If not, AOGCC’s records appear to be incomplete. Could you please clarify this for me, and if needed, provide documentation for the operations involved in running of the seven‐inch liner? Thanks and stay safe, Steve Davies Alaska Oil and Gas Conservation Commission (AOGCC) CONFIDENTIALITY NOTICE: This e‐mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e‐mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Steve Davies at 907‐793‐1224 or steve.davies@alaska.gov. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. {{ k� lk� 3 ' JTS BAN PT LlPi #3AC3C FT RAN 8-1/2 SECTION WINDOW 7794' - 7854' ITEM ID OD LENGTH TOP BOTTOM 7" NSCC Baker Insert Shoe &Float Jt #1 6.26 7.00 39.61 10096.39 10136.00 7"NSCC Baker Insert Plug Catcher Jt #21 6.26 7.00 39.63 10056.76 10096.39 7" 26#NT80S NSCC Casing (Jt #3 thru #8) 6.26 7.00 236.20 9820.56 10056.76 7" 26#NT80S NSCC Marker Jt 6.26 7.00 20.05 9800.51 9820.56 7" 26#NT80S NSCC CSG Jt #9 thru #63 6.26 7.00 2168.78 7631.73 9800.51 7'X9-5/8" FLEXLOCK LINER HANGER 6.22 8.33 5.62 7626.11 7631.73 7"X8-1/4" LINER TOP PACKER BAKER 6.25 8.25 4.76 7621.35 7626.11 7"X8-1/4" LINER SETTING SLEEVE 7.25 8.25 7.34 7614.01 7621.35 BAKER RUNNING TOOL 10.72 7603.29 7614.01 CASING: 7"26# NT80S NSCC (JOINTS #1THRU #63) MAKEUP TORQUE = 6500 FT -LBS BAKERLOC BOTTOM 2 JOINTS TURBULATOR SUMMARY: (TOTAL USED) 2 PER/JOINT ON JOINTS #1 THRU #33 1 PER/JOINT ON JOINTS #60THRU #63 NO TURBULATORS ON JOINTS #34 TO #59 BAKER INSERT FLOAT EQUIPMENT USED (DESCRIBE FLOAT EQUIPMENT & LOCATION) PLUG CATCHER IN BOTTOM OF JOINT #2@ 10096" FLOAT SHOE IN BOTTOM OF JOINT #1 @ 10136" FLOAT COLLAR IN TOP OF JOINT #19 10096" 7" MARKER JOINT @ 9800' (LINER HANGER AND PACKER DECRIPTION) 7"X 9-5/8" BAKER HYDRAULIC LINER HANGER, L-80 (6.255" ID) 7"LINER HYDRAULIC PACKER, L-80 (6.25" ID) 7" SETTING SLEEVE WITH 6' TIE -BACK EXTENSION (7.25- ID) CEMENT SUMMARY: PUMP 25 BBLS OF 11.9 PPG ARCO SPACER WELL TAKING FLUID DQRtLIG-RUNNING OF CSG & DURING CMT JOB. TOTAL FLUID LOST 380 BBLS MP PU25 BBL50F 8.3 PPG ARCO PREFLUSH. BATCH MIX AND PUMP 480 SX (5fi;CU.Fi.) OFCLASS G CEMENT W/.8%BA-10+.6%FL-32+.3'/oA-2+.3%R-1+.2'/*CD-30+1GPS FP-61- P-6L(slurry (slurrywt = 15.7 ppg). FOLLOW WITH 5 BBLS OF FRESH WATER. DROP PLUG. DISPLACE WITH 23_0 RBLS nF nntm. BUMP PLUG AND SET HANGER WITH 2700 PSI. SET LINER TOP PACKER WITH 4000 PSI. FLOAT EQUIPMENT HELD. FIELD FLUID LOSS TEST = 48 CC /30 MIN C.I.P. @ 0530 HOURS 12-12-92 DID NOT RECIPRICATED PIPE PRIOR TO AND DURING CEMENT JOB BECAUSE OF LOSS CIRCULATION PUMP RATE DURING CEMENT JOB WAS 10 BPM WITH 1200 PSI TO 2500 PSI. RELEASED OFF OF HANGER, NO CMT RETURNS NICK SCALES WELL# A -18A DATE 12/9/92 AVG. 39.43 A JT. # LENGTH 1 39.61 2 39.63 3 39.31 4 39.61 51 38.76 6 39.61 7 39.61 8 39.30 9 39.64 10 39.33 TOT.A% .': 394.41' B JT. # LENGTH 1 1 39.61 12 39.63 13 39.59 14 39.29 15 39.62 16 39.31 17 39.31 181 39.64 19 39.59 20 39.62 A -18A LINER TALLY SHEET CSG / TBG SIZE 7 " JOINT NSCC WEIGHT / FT. 26# C E JT. # LENGTH 21 39.13 22 39.33 23 39.12 24 37.90 25 39.30 26 39.62 27 39.30 28 39.10 29 39.62 3 0 39.62 TOT.C9.€}4' D JT. # LENGTH 31 39.33 32 39.63 331 39.16 34 39.29 35 39.64 36 39.62 37 39.61 38 39.62 39 39.63 40 39.61 TOT.BJ; TOT.D THIS PAGE SUBTOTAL TOTA PREVIOUS PAGE TOTAL: TOTAL THIS PAGE: JT. # LENGTH 41 39.62 42 39.30 43 39.65 44 39.64 45 39.29 46 39.62 47 39.64 48 38.80 59 39.30 f49 50 39.31 TOTE F JT. # LENGTH 51 39.31 52 39.63 531 39.62 54 38.91 55 39.29 56 39.62 57 39.63 581 39.63 59 39.63 60 39.62 TOT F 4 CARRY FOR. TO NEXT PAGE IJT #?? IS A MARKER JOINT. Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:192-107 6.50-029-20630-01-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 10150 7723 6924 7700 9959 7723 6905 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 78 20" x 30" 37 - 115 37 - 115 Surface 2632 13-3/8" 37 - 2669 37 - 2669 5380 2670 Intermediate 7495 9-5/8" 300 - 7795 300 - 6982 6870 4760 Tieback 7582 7-5/8" 35 - 7615 35 - 6835 6890 4790 Perforation Depth: Measured depth: 9700 - 9958 feet True vertical depth:8788 - 9042 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# L-80 33 - 7737 33 - 6935 7700 6905Packers and SSSV (type, measured and true vertical depth) 4-1/2" TIW HBBP Packer Liner 2522 7" 7614 - 10136 6835 - 9217 7240 5410 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 249104431082192291 No Well Test Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Wyatt Rivard wrivard@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.777.8547 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9231 Sundry Number or N/A if C.O. Exempt: N/A No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program 5 N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0047472 PBU A-18A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations Tubing Patch 7471 - 7498 By Samantha Carlisle at 8:43 am, May 03, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.05.03 07:06:13 -08'00' Stan Golis (880) ACTIVITY DATE SUMMARY 4/16/2021 ***WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 300L/2500H*** (set reducer / xx plug & CMIT-TxIA) RAN 30'x3.70" PACKER / PATCH DRIFT DOWN TO 7,500' SLM, TOOLS FELL FREELY, NO RESTRICTIONS. LRS LOADED IA & TUBING W/ CRUDE. RAN 4-1/2" X-LINE (T-brass, B-brass) W/ 4-1/2" LOCK, NIPPLE REDUCER, 2-7/8" XX PLUG (oal: 39"), PUSHED DOWN HOLE WHILE SHIFTING X-LINE , STOPED IN XN NIP @ 7,720' SLM (7,723' MD), CAME FREE AFTER 3 HITS UP, NIP REDUCER LEFT IN XN, ALL PINS ON X-LINE RECOVERED. ***CONTINUE ON 4-17-21 JOB LOG*** 4/16/2021 T/I/O= 1850/1250/0 Temp= 50* Assist Slickline (Patch Tubing/Liner) Loaded IA with 174 bbls crude. Loaded TBG with 170 bbls crude. TBG and IA tracked, reached max pressure on TBG and IA, Unable to get well to take fluid at max rate. Freeze protected FL with 3 bbls 60/40, 14 bbls crude, 5 bbls 60/40, 53 bbls crude and 1 bbl 60/40 per WOA request. Tags hung. Slickline in control of well upon departure. IA OA= OTG. DSO notified. Final Whp's=1200/1325/0 4/17/2021 ***CONTINUE FROM 04-16-21 JOB LOG*** ***WELL S/I ON ARRIVAL, DSO NOTIFIED, PT PCE 300L/2500H*** EQUALIZED 2-7/8" XX PLUG @ 7,720' SLM (7,723' MD). PULLED 4-1/2"x2-7/8" NIP REDUCER FROM XN @ 7,720' SLM (7,723' MD), ALL PACKING & PINS RECOVERED, 2-7/8" XX PLUG PACKED W/ SCALE. SET 4-1/2" XN LOCK, NIP REDUCER W/ 2-7/8" XX PLUG (EQ DEVICE ON SEAT), OAL: 39" IN XN @ 7,720' SLM (7,723' MD), ALL PINS ON X-LINE RECOVERED. PERFORMED COMBO MIT-IA TO T-2075psi / IA-2050psi, 1st 15min LOST 75psi ON TUBING & 50psi ON IA, 2nd 15min LOST 0psi ON TUBING & 20psi ON IA (pass). BLED TUBING & IA DOWN TO 0psi. ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 4/19/2021 ...Well shut in on arrival... (HES EL - patch tbg) SET BAKER 45KB PATCH ACROSS GLM #1, 7,473' - 7,493' ELEMENT TO ELEMENT. ***Job Complete. Well shut in on departure.*** ***Top of patch ~ 7471', bottom of patch ~ 7498', minimum I.D. = 2.45" at ~ 7494', OAL LIH ~ 26.9, OAW LIH ~ 500#*** 4/20/2021 T/I/O=297/329/0 Pressured TxIA to 2250w/8.3 bbls crude, TxIA lost 19/55 1st 15 min and 15/20 psi in 2nd 15 min for a total loss of34/75 psi in 30 min test. bled back~4 bbls. MIT-T to 2000 psi (max applied 2250) PASSED . Pressured tbg up to 2250 w/ 2.2 bbls crude. tbg lost 69 psi 1st 15 min and 19 2nd 15 min for a total loss of 88 psi in 30 min test. bled back ~ 1.6 bbls. Final WHP's= 310/300/0 Pad op notified, tags hung Daily Report of Well Operations PBU A-18A WELL# DATE AVG. A-1 BA 12/9/92 39.43 A JT. # LENGTH 1 39.61 2 39.63 3 39.31 4 39.61 5 38.76 61 39.61 7 39.61 8 39.30 9 39.64 10 39.33 .A& f s� TOT.A . , 04 4 B JT. # LENGTH 1 1 39.61 12 39.63 13 39.59 14 39.29 15 39.62 161 39.31 17 39.31 18 39.64 1 9 39.59 20 39.62 TOT.B 395=2 i THIS PAGE SUBTOTAL TOTA A -18A LINER TALLY SHEET CSG / TBG SIZE 7" JOINT NSCC WEIGHT / FT. 26# C E JT. # LENGTH JT. # LENGTH 21 39.13 41 39.62 22 39.33 42 39.30 231 39.12 431 39.65 24 37.90 44 39.64 25 39.30 45 39.29 26 39.62 46 39.62 271 39.30 47 39.64 28 39.10 48 38.80 29 39.62 49 39.30 30 39.62 50 39.31 TOT.0 192;04 D TOTE 394..27 F JT. # LENGTH JT. # LENGTH 31 39.33 51 39.31 32 39.63 52 39.63 33 39.16 531 39.62 341 39.29 54 38.91 35 39.64 55 39.29 36 39.62 56 39.62 37 39.61 57 39.63 381 39.62 581 39.63 39 39.63 59 39.63 40 39.61 60 39.62 TOT.D ... 395.14 TOT F ��ip PREVIOUS PAGE TOTAL: TOTAL THIS PAGE: CARRY FOR. TO NEXT PAGE JT #?? IS A MARKER JOINT. OF7.4�, • THE STATE Alaska Oil and Gas ti ;.-s=- amo fLAS <:A Conservation Commission A Itf= 333 West Seventh Avenue ✓L,yyr-2-- — C Anchora e, Alaska 99501-3572 T' g GOVERNOR BILL WALKER Main: 907.279.1433 r+ O4' ";'S'" ' Fax: 907.276.7542 www.aogcc.alaska.gov Oliver R. Sternicki Well Integrity Engineer BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool,PBU A-18A Permit to Drill Number: 192-107 Sundry Number: 316-172 Dear Mr. Sternicki: 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, ;V44Ck Cathy P Foerster Chair DATED thisay of March, 2016. RBDMS Lk-- MAR 1 1 2016 RECESTATE OF ALASKA • I . " • ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 1 ?016 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 i a '.rr ( /-' 1. Type of Request: Abandon ❑ Plug Perforations LI Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate LI Other Stimulate ❑ Pull Tubing ❑ Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other New Tech-Set BiSN P p - 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 192-107 ' 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p. 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-20630-01-00 ' 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No lI , PBU A-18A 9. Property Designation(Lease Number): 10. Field/Pools: ADL 0047472 PRUDHOE BAY,PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10150 - 9231 7723 6924 7723 9959 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20"x 30" 37-115 37-115 Surface 2633 13-3/8"72#L-80 37-2669 37-2669 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 2522 7"26#NT80S 7625-10147 6843-9228 7240 5410 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment 4-1/2"12.6#L-80 L-80 33-7737 Packers and SSSV Type: See Attachment Packers and SSSV MD(ft)and TVD(ft): See Attachment No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary ❑ Wellbore Schematic p 13.Well Class after proposed work: Detailed Operations Program RI BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development p ' Service 0 14.Estimated Date for Commencing Operations: 3/10/16 15. Well Status after proposed work: Oil p • WINJ 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Sternicki,Oliver R be deviated from without prior written approval. Email Oliver.Sternicki@bp.com Printed Name Sternicki,Oliver R Title Well Integrity Engineer �73 // G Signature _ / - Phone +1 907 564 4301 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number Integrity 3\Le — \-72.-- Plug 9 y ❑ BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes❑ No ❑ Spacing Exception Required? Yes❑ No L Subsequent Form Required: / C `% '' Approved by: P9,2,L,44„, COMMISSIONER APPROVED BYTHECOMMISSIONc Date: 3^ / // 'TL 3/ //G / !yi OR1 G ,i. I _ RBDMS M4R 1 zols Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. ttachments in Duplicate • • CI a 0 0 0 0 0 0 • N- CONCO - p N rY U) d' U) h- 0 ; O O O O O O i M N. 00 I"- v. co 7 CA 00 v- 00 N m M 00 Cfl N- 00 0 — 00 U) r- r' Nr p) N M r. CO U) CO CA N p) N CO CO 0) C0 H 00 I- r- U) M M M M UD M CO M Cfl .-- CO r N O ' M r CO U) CO 00 a N- .0 N N- N N- V I I I i I I i 4-1 Q Q 00 UP h- f� CO v- `� N M 0 Q M M co U) M Cp co .Q co 0' UD O00) 0 O 00 a) ~ Cp O J -11 Z J 00 = ecoI (Nk *kF .N N X N- N- Z N - 0) v- t) 00 N - Cep ` U N _ N N 2 CT I9 o (` -C CD 00 co C4 N- C)) N O C I� (ID r U) V' U) N- C) N N- ti N W W W cn0 Q Q Q N 0 U uJ LIJ LU w O � I• W— HI- Zm 0 Z Z Z J m a) 1110 m LC) LO O .0O CO N- a)• O N ❑ co co O O o0 oO O a O F- co CO d N- O a o 0 O N ❑ 0CD CO CO Cr) CO O > p CO CO O 0 rx❑ ® w z LU w 0 w ❑ F- F J w U, U 0 > 0ED co o J U U w w w ++ a LO 00 CO Q Q Q w CL a U Ct a ) r- co cm U U 0 J W W0 J 0 0 0 0 0 J J N = _ < Z 0 0 a W a L U U 0 w = _ ❑ ~ ❑ Z p Z Q 2 O v~) co u)) v) c co +-� r O aF- 0 • ma Nr CO +rmrnrnrn cv 0. co " 1- O � (/) Y U O CO OCOc~i) can CO CO CD a. a, 0 U c oco co w,/ is 0_ Q CL m 00 OO CO a 0 t a, a 0 0 0 0 0 D � 0 x 0 0 0 w J Z O N N N ZL a i < W N NN ❑ LLJ 11 ❑ W _ W ❑ W LL d Z - U' J :.9 U w W W LL W a Ln L1) in < ❑ O J '� F- J J J D G! a O CO ❑ R ❑ E W J0 . L'1 W W < < a. m cn LL LL :n LL co a ce m E co z Q Q Q COCOCO cnQQ 0_ CO N L.L.Qm a aOOw m m0cc • • Packers and SSV's Attachment ' PBU A-18A SW Name Type MD TVD Depscription A-18A PACKER 7632.1 6849.38 7" Liner Top Packer A-18A TBG PACKER 7709.18 6912.39 4-1/2"TIW HBBP Packer ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V20,DBR,LHD,EAZ,BPG 10/12/15) General Information Well Name: A-18 Well Type: Gas Lift Producer API Number: 50-029-22300-00 Well Activity Classification: Conventional 4 Activity Description: Set BiSN Plug • Cost Code/AFE: APBOTMMA Field/Reservoir: PRUDHOE IVISHAK 12 Month Avg IOR, bopd: Job Type: Mech-Plug Estimated Cost, $K: AWGRS Job Scope: NEW TECHNOLOGY PROJECT Other regulatory — - requirements? None Sundry Form 10-403 Required? Yes Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Jennifer Julian Contact numbers: (907)240-8037 (907) 240-8037 Well Intervention Engineer: Oliver Sternicki Contact numbers: (907) 564-4301 (907)350-0759 Lead Engineer: Brian Glasheen Contact numbers: (907) 564-5905 (907) 545-1144 Date Created: February 26, 2016 Revisions (date,who,what changed): Current Well Status Information Water Rate or Gas Rate or Date Oil Rate Inj Rate Gas Injection GOR GFTP or Injectior Choke Setting as Lift Rate Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) Cut(%) (Mscf/Day) (psi) 5/17/2003 107 2286 BWPD/ 422 3,943 95.5 WC 96 2,940 227 Current Status: Not Operable Shut In Inclination>70°at Depth(ft) N/A Recent H2S (date,ppm) 5/3/2003 30 fir,,, Maximum Deviation(Angle and — Depth) 28° 4,636' MD - Datum depth,ft TVDss 8,800' TVDss Dogleg Severity(Angle and Depth) 54° 9,456' MD Reservoir pressure(date, psig) 7/19/1994 3,561 psi Minimum ID and Depth 3.725" 9,369' MD Reservoir Temp,F 226° F Shut-in Wellhead Pressure SSV closed expect 1400(AL Known mech. integrity pressure) problems (specifics) Surface casing leak at 63"on 3-19-13.-LDL found leak at GLM#1 at 7480' on 6/27/12 Last downhole operation (date, operation) 7/16/2012 Set TTP. DGLV's Most recent TD tag (date,depth, toolstring OD) NA Surface Kit Fit-for-Service? NO If No,Why? Well is blinded and requires VSM work to bring back into service. Comments,well history, This is a New Technology Project to test setting a BiSN plug (downhole solder), which is a metal to metal background information, sealing technology etc: • Well Intervention Details Suspected Well Problem: [None Specific Intervention Intervention or Well Objectives: 1 Set 3.5" OD BiSN plug in 4.5"tubing tail and pressure test plug to validate setting. 2 3 Key risks,critical issues: Mitigation plan: 1 New technology L2RA for BiSN plug 2 Setting off BiSN plug at surface. BiSN specific procedure to be followed 3 Summary Step# Service Line Activity 1 FB CMIT TxIA to 2500. Establish LLR if fails 2 SL Run Temp gauge . Pull PXN plug 3 EL Set BiSN plug @7715' MD 4 FB CMIT-TxIA to 500 psi, 1000 psi, 1500 psi, 2000 psi, 2500 psi. LLR if fails Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 FB CMIT-TxIA to 2500 psi. LLR if it fails 2 SL Run Temp gauge and obtain 10 minute reading at 7715'. Pull PXN plug Set bottom of BiSN plug @7715'. Though not an explosives operation, follow grounding and isolation 3 EL procedures set forth in GWO Alaska Region Recommended Practice:E-line Set Packers,Retainers and Bridge Plugs. Tie into tubing tally dated 12/15/92. 4 FB CMIT-TxIA to 500 psi, 1000 psi, 1500 psi, 2000 psi, 2500 psi. LLR if fails Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 0 MMSCFD: 0 BWPD: Expected Production Rates: — 0 FTP(psi):[ 0 Choke setting:I 0 PI(bfpd/psi dp) Post job POP instructions: [Leave well shut-in Attachments-include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form,logging form,well test chart,annotated mini log,annotated log section,tubing/casing tallies,Wellhead info,etc Approvals Management Approval: Date: Wells Approval: Date: TREE= 4-1/8"MC -VOY 1 WB-LHEAL At EVOY • SAFETY NOTES: ACTUATOIz= OTIS A-18A OKE.BEV= 86.1' BF.ELEV= 52.9' I C0,,y KOP= 3350' L I ! . Y /4C Ml3x Angle- 39" (05500' Datum MD= _9799' [TOP OF 9-5/8-J_ 300' Datum TVD. 8800'SS ^a -39' 9-5/8"X 7-5l8"XO,D=6.87" 1 © L 2015' -I4-1/2"OTIS SSSV NP,D=3.813" Mi _2592' '-9-518"DV FKRR� 13-3/8"CSG,72#,L-80,D=12.347" 1 2670' ' GAS LFT MANDRELS ST MD TVD DEV TYPE VLVLATCH PORT DATE Minimum ID = 3.725" 7723' IF 5 3097 3097 6 -CAMC O DMY BK 0 05/26/05 OTIS XN NIPPLE 1 4 5374 5078 39 CAMCO DMY BK 0 05/26/05 3 6667 6079 39 CA MOO DMY BK 0 05/26/05 2_7374 6639 36 CA MCO DAY BK 0 NteN. �7480)6725 35 CAMCO 'DMY BK 0 07/16/12 • "STATION#1=DMY HAS EXTENDED PACKING 4 7-518"CSG,29.7#,STL NT-95,D=6.875" H 7609' '''' - _.--------- I ! 7609' 1-7-5/8"X 7"XO,D 1;6:25;1 I9-5/8'X 7"BKR TIEBACK SLV,ID=7.25' --L 7614' —) 19-5/8"X 7"BKR LNR TOP PIR,D=6.25" 1-I 7621' — _ 7615' I-17"BKR T1�ACK SEAL ASSY 1 Ala 9-518"X 7"BKR LNR HANGER,D=6.22" I---1 7626' I I , 4< 7668' 1--14-112"OTIS X NP,D=3 813' 1 10 0---- 7700' 1H 7"X 4-112"TMI HBBP PIR,D=4.00" I � 9 I 7718' I--14 1/2"OTIS X NP,D=3.813" I 1?)4 7723' -I-I4-1/2"OTIS XN NP, D=3.725" 7723' I-4-1/2"PXN TTP(05/27/05)J 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" H 7727' \ 7728' H4-112'TBG TAIL WLEG I 7704' I--I ELMD TTL LOGGED 12/26/92 9-518"MILLOUT WINDOW PERFORATION SLIVMARY I 7795'-7855' REF LOG: BRCS 12/10/9211111410 ANGLE AT TOP FERF: 11"@ 9700' y.• :•,:•. 9800' I-17"X 20'MARKER JOINT-1 Note:Refer to Production C8 for historical pert data '::::,::' SIZE SPF INTERVAL OpniS4z SHOT SQZ • .•:•F::•:•. .'.':::.: •V::.S'.••, 9959' 3-3/8"PERF GUN/CCL 3-3/8" 6 9700-9715 C 10/07/93 •"•':�':.��.'..:4,.:.'.•.;.;, - :..:,.r::..4.044.1......•404 (32.5') 12/26/92 3-3/8" 6 9794-9838 C 12/26/92 ••• ••' • 3 318" 4 9948-9958 C 12/26/92 :1':;::•:::; :':::•••'• H P$TD 10056" ••y • �::::::If•...•.,i•:::,:11••111•.•• ��• ` F9-5/8" ♦:1:1•.CSG,47#,L-80,D=8.681" - 9904' :::.... .::a::a.mv. 17"LNR,26#,NT-80S,.0383 bpf,D=6.276" H 10136' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/01/81 ORIGINAL COMPLETION_ 03/12/14+TAO/JMD ADDED SAFE)Y NOTE A-18A 12/16/92 SIDE TRACK COM PLEI 110 02/11/16 TK/JMD REMOVED SAFETY NOTE WEIL: 92-10 06/29/01 CFVKAK CORRECTIONS - P AFi No: 92-1070 05/26/05 KSBJPJC GLV C/O API No: 50-029-20630-01 Sec.35,T11N,R 13E,2043'FSL&1014'FEL 09/22/05 MORfTLH TTP SET(05/27/05) 07/18/12 THWJMD GLV C/O(07/16/12) - — BP Exploration(Alaska) I f�c(l�I e WelDiok r„ ,,,, , ,, U Metal to Metal Gas Tight Seal 4 No mechanical parts 4,. J Effective even in Corroded and Damaged Casing Larger Drift than Traditions' , 900 0 f_; i sa Bridge Plugs - by passes restriction k . i® s L ti 444'43330o/ „ ,, ,—"1" :,=,:s,,. irm . ,,. , /1A\ Reduced Rig Time - Ready for �� ' I° ® Q o oil ®®'11 Testingin 1 /2 hour ® I i 3� �� High Holding Pressure :a. ®®As v s♦ High Working Temperature up to 600 °C Ijill ®®®1®0011"" 4 ISO 14310 -VO Rated - Gas Tight ©i.,1 1!01„•' For further information call us on: 832-9 19-7500 B iSN s email: info@bisnoiltools.com 1 www.bisnoiltools.com OIL TOOLS · XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. [~A'/~r~ File Number of Well History File PAGES TO DELETE RESCAN Complete I-1 Color items - Pages: GrayScale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA n Diskettes, No. n Other, No/Type OVERSIZED Logs 'of various kinds n Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ THE MATERiAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE NOVEMBER 13, 2000 PL EW M ATE R lA L U N D E TH IS M A R K ER R LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 February 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: WELL 117 A-18~ DESCRIPTION ECC No. PLS FINAL BL + RF Run # 1 3704.01 PLS FINAL BL+RF Run # 1 5757.02 GR/CCL FINAL BL+RF Run # 1 5820.05 PLS FINAL BL+RF Run # i 5820.04 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~x~(907~ 563-7803 Received b~/~_~//,~~/{~ Date: RECEIVED FEB 2. 2 1995 Alaska 0ii & Gas Cons. Commission Anchorage ~ ~&OGCC Individual Well Ge61ogical Materials Inventory PERMIT DATA T DATA_PLUS 92-107 5771 92-107 5503 92-107 SURVEY 92-107 SURVEY 92-107 DAILY WELL OP 92-107 407 92-107 SSTVD 92-107 92-107 92-107 T 9525-9925 PDK-100 T 9395-100108 OH/DLL/AC/GR R 7800-10103 MD SPERRY SUN a 7800-9362 ANADRILL R 11/29-12/18/92 R COMP DATE: 12/28/92 L 9380-10075 MD PFC/GR/CCL(PERF) L 9600-9843 PERF I~ 7570-10028 PDK/TEMP/GR/CCL L 9600-9911 · 92-107 PDK-100/TEMP L 9600-9911 92-107 DLL/GR ~'. 9380-10075 92-107 BHC/AC/GR L 9600-10108 Page: Date: RUN 1 1 1 1 1 1 1 1 1 1 11/16/94 DATE_RECVD 09/14/93 01/04/93 02/24/93 02/24/93 02/24/93 02/24/93 12/22/92 10/15/93 01/04/93 09/20/93 08/09/93 12/22/92 12/22/92 Are dry ditch samples r eq~ yes ~nd received? ye~ Was the well cored? ye~__~iD~ Analysis & description received? yes~ wA~~i w~~ li~e~~~p ~~~nU~l~re~~ed? ye~ COMMENTS ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276.7542 July 28, 1994 Steve Farris/Jerry Bixby Wireline/Completion Supvrs BP Exploration (Alaska), Inc P O Box 196612 Anchorage, AK 99519-6612 Re: No-Flow Verification BPX PBU well # A-18 PTD 81-108 Dear Mr. Farris/Bixby: On July 21, 1994, our' Inspector Jerry Herring' witnessed a no-flow test on BPX's PBU well #A-18 (PTD 81-108). The well had been shut-in and bled down to an atmospheric tank on-site. The well was essentially dead; a gas meter showed that the flow rate was approximately 50 SCF per hour versus 900 SCF per hour acceptable. Since this rate is well below the limits for "no-flows", the Inspector concluded that subject wells were not capable Of unassisted flow of hydrocarbons. The Commission hereby authorizes removal of the subsurface safety valve from BPX's PBU well #A-I~ (PTD 81-108) on the condition that the low- pressure sensor and surface safety valve must be maintained in good condition; and, if for any reason, the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be reinstalled and maintained in good working condition. Sincerely, Blair E..Wo~ell PI Supervisor c: Jerry Herring bew/nlpbal 8 ~0~ prinfed on recycled paper MEMORANDb... TO: THRU: David Johns.~o~, Chairm~ State c.. , laska Alaska Oil and Gas Conservation Commission DATE: July 25, 1994 Blair Wondzell, ~'(z9 P. I. Supervisor FROM: Jerry Herring, ~ SUBJECT: Petroleum Inspector FILE NO: lj9kgubd, doc ,. No Flow Tests BPX, Pruhoe Bay PBU A-18, PTD 81-108 Thursday, July 2!, !.994: I traveled to BPX's Prudhoe Bay Unit to witness a no flow test on well A-18. Upon my arrival, the high water cut i Iow GOR well was shut-in, depressurized and was open to atmospheric pressure, 'Only traces of gas vented from the well. BPX is using an American Meter ^L-425 (vendor data attached) to measure the gas flow rate which was recorded to be less than 50 scfh. The well demonstrated that it is not capable of unassisted flow. , I think using the American Meter AL-450 is a good tool to measure the volume of gas Venting during a no-flow test. The American Meter AL-450 is a positive displacement meter used for residential gas metering. With the Iow pressure rate being measured during no-flow testing, this meter is a good tool to verify rates are within acceptable tolerances. Summary: I witnessed a no flow test on PBU well A-18 REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdoWn Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other X 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2043' NSL, 1014' WEL, SEC. 35, T11N, R13E, UPM At top of productive interval 809' SNL, 1597' WEL, SEC. 02, TION, R13E, UPM At effective depth 781' SNL, 1633' WEL, SEC. 02, TION, R13E, UPM At total depth 820' SNL, 1581' WEL, SEC. 02, TION, R13E, UPM 12. Present well condition summary Total depth: measured 10150 feet true vertical BKB 9512 feet 5. Type of Well: Development Exploratory Stratigraphic Service Plugs (measured) 6. Datum elevation (DF or KB) KBE= 86.10 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number A-18A (34-02-10-13) PBU 9. Pe.Q'rjj.t nqmber/approval number 10. APl number '~' 50- 029-20630--~/ 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 10056 feet true vertical BKB 9431 feet Junk (measured) Casing Length Size Cemented Structural -- Conductor 110 20x30 8 c.y. Surface 2637 13 3/8 3720 c.f. I nte rmediate 7762 9 5/8 1380 c.f. Production -- Liner 42 75/8 561 c.f. Perforation depth: measured 9794'- 9838' (6 spf) 9948'- 9958'(48pf) true vertical subsea 8882'-8925' 9033'-9042' Measured depth 143 267O 7795 7573-7615 True vertical depth BKB 143 2670 6982 6801 - 6835 Tubing (size, grade, and measured depth) 4 1/2" L-80 to 7728' with 4 1/2" tailpipe to 9450' Packers and SSSV (type and measured depth) 9 5/8" BOTpacker at 7700; 4 1/2" SSSV at 2015 13. Stimulation or cement squeeze summary See Attachment RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. ~;ommiss Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 160 479 378 2690 1030 830 4159 2510 247 256 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby gertify that the foregejng is true and correct to the best of my knowledge. Signe~r~,v/~'~/f,-~..,~.~~] ~j~ Title Senior TechnicalAssistant/ · Form 10-~(J4 Rev 06/15/88 Date SUBMIT IN DUPLI{~ATE 2/25/93 WELL A-18A(34-02-10-13) Hydraulic Fracturing A Hydraulic Fracture (Ivishak) was performed using the following fluids: FLUIDS PUMPED; FRAC: 30 BBLS 40# GEL PREPAD TO ESTABLISH RATE 587 1 O4 29 34 37 39 39 39 39 39 286 89 110 BBLS 40# X-LINK GEL PAD W/0% ESL Dirty 1 PPG 2 PPG 3 PPG 4 PPG 5 PPG 6 PPG 7 PPG 8 PPG 9 PPG 10 PPG 20# LINEAR GEL FLUSH Diesel used today 10/7/93 fjh 10/21/93 The following additional interval were perforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9700'- 9715' MD RECEIVED NOV - 8 1993 Alaska 0il & Gas Cons. Anchorage P~SE~ SIGN ONE COPY AND RETU'--~TO: ATLAS WIRELINE SERVICES Pouch 340013 Prudhoe Bay, AK 99734 This is to acknowledge receipt of the following prints and negatives. COMPANY: STATE OF ALASKA OIL & GAS CONSERVATION COMM. ATTENTION: LARRY GRANT FIELD: PRUDHOE BAY WELL - LOG DESCRIPTION PRINTS NEGS. SEPIA A-18 A PFC~PERF>G~CC-L- 5" c~tO .._1 9~ 0 1 E-03 PLS ~,, 1~~ %~~ 0 . 1 H- 18 PLS ~C~' ~~v~ ~- o9 PLS [LEAK DET~ a,, %%~ ~ U~O 0 ~ . R-24 PFC~ERF)GR/~U 5" ~ ~ qq~ 0 1 R-30 CN/GR 5" ~%~003 %t~q% 0 1 W-07 PDK-100 Gm/~u 5,, ~%~! ~q~q 0 z Z-07 A PFC~PERF)G~ 5" l~a~ %~q~ 0 1 Z-12 PDK-100 GR 5" ;U?~ ~ [%~5{ 0 1 Y-36 BHC/AC GR a~" }lo~--1 }~5 0 1 DIFL/GR 2~5t~ 1%O~ %~%~ 0 1 WATER SA~TION ~" 1 !{~- ~ 0 ~ ~,,,. 1 " "clVED FORMTOOL\RTNCARD DATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 09/15/93 T# 85O20 BPX/PBUOLOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-18Aq~'j0~ PDK- 1001 ~fl%°/~lcZ&07 / 29 / 93 #1 $-12~-~ PERF) ~C~/CCL, 09/09/93 #1 X-03 ~ (PERF){~C-IC~ICCL- 09/09/93 #1 X- 19A fi%- lq~(PERF) ~;~/~ 09/09/93 (PERF> ~/~ 09/11/93 X-2 SBL/~JC&U 09/10/93 Z-2 9 ~6 (PERF~C~ 9600.00- 9911.00 ATLAS 5 " 10200.00-10612.00 ATLAS 5 " 11700.00-11900.00 ATLAS 5 " 9750.00- 9950.00 ATLAS 5 " 8970.00- 9416.00 ATLAS 5 " 8370.00- 9450.00 ATLAS 5 " 09/1'0/93 #! __ . 8370.00- 9450.00 ATLAS 5 " 09/10/93 #1 11328.00-11773.00 ATLAS 5 " Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 .f DATE: 09/08/93 T# 84982 BPX/PBU ~APE W/LISTING Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-18A CH/PDK-100 FIN 07/29/93 # 9525.00- 9925.00 1600BPI API~500292063001 9463->TP# ATLAS REF#5820.02 Information Control Well Records BP EXPLORATION BP Exploration (Alaska) Inc, 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 08/04/93 T# 84842 BPX/PBU~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A- 18~'~~PDK- 10 0 i 'T~rvl~ H-15~% ~% CNn PORO P-04%%-~ PRODUCTION LOG 07/24/93 S-2290,%~ TUBING CUTTER 07/25/93 07/29/93 #1 07/28/93 #1 07/28/93 #1 07/27/93 #1 07/26/93 ~1 9600.00- 9911.00 ATLAS 5 " 9850.00-10100.00 ATLAS 5 " 11300.00-12351.00 ATLAS 5 " 10850.00-11388.00 ATLAS 5 " 10870.00-11100.00 ATLAS 5 " 11350.00-11850.00 ATLAS 2/5" 9250.00- 9550.00 ATLAS 5 " Information Control Well Records O! STATE OF ALASKA "' ISSION O/¢) ALAS~ 0IL AND GAS CONSERVATION COMM WELL COMPLI=TION OR RI:::CO P LETION REPORT 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPEiXDED [] ABANDONED [] SERVICE [] _ 2. Name of Operator 7. Permit Number BP Exploration 92-107 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 s0- 029-20630-01 4. Location of well at surf ace .~~[ 9. Unit or Lease Name U%~,"-~--~TE i ,____ ,"~~..~__ 10.Prudh°eBayUnitwell Number 2043' NSL, 1014' WEL, SEC. 35, T11N, R13E, I ~TtC)NS1 At Top Producing Interval , z. ~J ! ' A-18A (34-2-10-.13) 781' SNL, 1633' WEL, SEC. 2, TION, R13E, UM i~ 1~.. Field and Pool At Total Depth ~i ~' I~~ '. Prudhoe Bay Fieid/Prudhoe Bay Pool 820' SNL, 1581' WEL, SEC. 2, TION, R13E, UM 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 86.1' I ADL 28313 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. o~ Aband. 115. Water Depth, if offshore 116. No. of Completions 12/3/92 12/10/92 12/26/92I N/Aeet MSL J One 17. Total Depth (~D+TVD) 18. Plug Back Depth (MD+TVD', 19. Directional Survey ~20. Depth where SSSV set ~21. Thickness of Permafrost 10150' MD/9230' TVD 10056' !~¢.?./9178' TVD YES E~ N~ []! 2015feet MD ! 2055' (Approx.) 22. Type Electric or Other Logs Run DLL/BHCS/GR 23. CASING, LINER AND CEMENTING RECORD SE-I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEM~ RECORD AMOUNT PULLED 20" X 30~ Insulated Conductor Surface 110' 36" 8 cu yds Concrete 13,3/8 72# L-80 Surface 2670' 17-1/2" 3720 cuft Arcticset II 9-5/8 47# L-80 Surface 7795' 12-1/4" 1380 cuft Class "G" 7-5/8' 29# NT-95 42' 7615' 8-1/2" 561 cuft Class 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ~ RECORD interval, size and number) SIZE DEPTHSE'[ (MD) P.~.iOK~R SET tMD) Gun Diameter 3-3/8" 4-1/2", L-80 7728' 7700' MD TVD 9794'-9838' 8882'8925' 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9948'-9958' 9033'-9042' 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing. gas lift, etc.) 12/28/92 ! Gas Lift Date °' Test H°urs TestedTEST PERIOD ~:{O[XJCTION FOR lO I L-BBL I~ GAS'MC F WATER-BBL CHOKE,.~ZE IGAS-OJL 'RATIO Flow Tubh'B Casing Pressure C~,.-~,~LATED } ©:~L~;~.'-~-L GAS.~,i~F WATER-BBL OIL GR,',VITY-API (corr) Press. 24-HOUR RATE ~! 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. RECEIVED FEB ? 4 /Jlas .ka_ Oil & Gas Cons. Commission Form 10-407 Rev. 7-1-80 CON~NUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKE~ ~ FORMATION TESTS NAME Include interval tested, pressure dale, all fluids recovered and gravily, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag River 9695' 8784' Sh ublik 9717' 8806' Sadlerochit 9 794' 8882' '"' ' Orage '",,tssion 31. UST OF ^ r^c'ME S 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed.;.~-?~/~.~;~'Z~-¥~-'' ('"~~ ~'~--"~Title Drilling Engineer Supervisor Date ~///'~'~ :'__. / INSTRUCTIONS ~eneral: 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-expl~.in. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: A-18A BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50-029-20630 PERMIT: APPROVAL: ACCEPT: 11/29/92 12:00 SPUD: RELEASE: OPERATION: DRLG RIG: DOYON lC WO/C RIG: DOYON 16 11/29/92 ( 1) TD: 0 PB: 0 MOVE RIG TO A-PAD MW: 0.0 MOVING RIG DOWN SPINE ROAD TO KUPARUK RIVER BRIDGE, TOWARDS A-PAD 11/30/92 (2) TD:10706 PB:10647 12/01/92 (3) TD: 8100 PB: 8100 12/02/92 (4) TD: 7840 PB: 8100 POH, L/D 4-1/2" CR TBG MW: 0.0 MOVE RIG TO A-PAD, RAISE DERRICK, TAKE ON SEAWATER, RIG UP ON TREE TO CIRC, PULL BPV, NO WELLHEAD PRESSURE, CIRC DIESEL F/WELL, INSTALL TWC, R/U BOPE & TEST, PULL TWC, R/U TORQUE TURN, M/U LNDG JT, PULL TBG FREE, PULL HGR TO FLOOR, CBU,. GAS PRESENT, CIRC OUT GAS TILL WELL STABLE, R/U SPOOLING UNIT, POH & L/D TBG M/U SECTION MILLING ASSEMB. MW: 0.0 KC1 POH, L.D TBG, CLEAR RIG FLOOR, INSTALL WEAR RING, M/U BRIDGE PLUG, RIH & SET @ 8100', CHG WELL BORE FLUID OVER TO 9.TPPG MILLING FLUID F/SEAWATER, 18 PP~ MUD PILL F/TOP OF BRIDGE PLUG-~TO 7860', POH W/5" DP, M/U SECTION MILL, DRILL COLLARS & HWDP, RIH MILLING 9-5/8" CSG @ 7840' MW: 0.0 KCl RIH W/SECTION MILL, CIRC & COND MUD, CUT 9-5/8" CSG ~ 7794', MILLING 9-5/8' CSG 7794'-7840' 12/03/92 (5) TD: 7840 PB: 8100 CLEAN BOPS & PIT EQUIP MW: 0.0 KCl MILLING TO 7854' CIRC. PULLED TO 5375'. CBU. POH. RIH. WASH TO 7954' POH TO 7854' CLEAN BOPS. 12/04/92 (6) TD: 7875' (7875) DRILLING TO 7875 MW: 9.8 VIS: 58 12/05/92 ( 7) TD: 8364' ( 489) 12/06/92 ( 8) TD: 8765' ( 401) DRLG W/MOTOR @ 8364' DRILLING W/MOTOR F/7875'-8364' MW: 9.9 VIS: 61 DIRECTIONAL DRLG @ 8765' MW: 9.8 VIS: 62 DRLG F/8364' TO 83-80', DROP SURVEY, PUMP PILL, POH, CHG BIT & MWD, RIH FILL P~?E & CHK MWD, RIH TO 8089', FILL PIPE, WASH & REAM 9295'-8380', DRLG 8380' TO 8765' RECEIVED 41aska 0il & Gas Cons. Commission Anchorage WELL : A-18A OPERATION: RIG : DOYON 16 PAGE: 2 12/07/92 (9) TD: 9341' ( 576) DRILLING MW: 9.7 VIS: 68 DIRECTIONAL DRILLING W/MUD MOTOR @ 8765'-9341' 12/08/92 (10) TD: 9505' ( 164) 12/09/92 (11) TD: 9788' ( 283) DRILLING @ 9505' MW: 9.8 VIS: 61 DIRECTION DRLG W/MUD MOTOR 9341'-9424', PUMP SWEEP, DROP SINGLE SHOT SURVEY, DRY JOB POH F/BIT CHG, CHG BOOT IN FLOW LINE, M/U PACKED HOLE ASSEMB., RIH, CUT DRLG LINE, RIH, BRK CIRC @ SHOE, REAM F/9346' TO 9424', DRLG F/9424'-9505' DRILLING 8-1/2" OPENHOLE DRILLING 8-1/2" OPENHOLE @ 9788' MW: 9.8 VIS: 83 12/10/92 (12) TD: 10150' ( 362) 12/11/92 (13) TD:10150' ( 0) 12/12/92 (14) TD:10150 PB: 0 12/13/92 (15) TD:10150 PB: 0 12/14/92 (16) TD:10i50 PB: 0 WASH & REAM TO BTM. MW: 9.8 VIS: 48 DRLG TO 10150' TD WELL @ 01:00 HRS, 12/10/92. CIRC. SHORT TRIP TO SHOE. RIH. REAM TO BTM WASH & REAM TO 5TM MW: 9.9 VIS: 52 WASH & REAM THRU TIGHT HOLE F/10074'-10150' TD, CBU, SPOT LIQUID CSG PILL IN 8-1/2" HOLE SECTION, NO FLUID LOSS, DROP SURVEY TOOL, POH, NO TIGHT SPOTS, L/D BHA, NO FLUID LOSS, R/U ATLAS W/L, RIH TAG BTM @ 10116', RUN DLL/BHCS/GR, POH R/D W/L, NO FLUID LOSS, M/U 8-1/2" BIT RIH FOR WIPER TRIP, BRIDGE IN HOLE @ 9918', L/D 8 JTS DP, WASH & REAM THRU OPEN HOLE SECTION F/9855' REV CIRC. MW: 9.9 KC1 CIRC. CIRC HI-VIS SWEEP. SPOT LIQ CSG PILL. POOH. L/D BHA. RIH W/ 7" LNR ON DP. CIRC @ BTM. PUMP 25 BBLS ARCO SPACER, 100 BBLS CMT. DISP W/ MUD. BUMPP PLUG. SET LNR HGR & LNR TOP PKR W/ 4000 PSI. RELEASE F/ LNR. REV CIRC. POOH. L/D DP. MW: 9.9 KCl REV CIRC @ TOL. POOH. LD/ DP, LNR RUNNING TOOL. RIH W/ HOWCO RBP. SET @ 500' PULL PACKOFF. DUMP SAND. RIH W/ TSA MECH CSG CUTTER. CUT CSG @ 300' DISP TOP 300' W/ DIESEL (85 BBLS). POOH. L/D CSG CUTTER. RIH W/ SPEAR. SPEAR CSG. PULL HGR TO FLOOR. POOH, L/D 7 JTS 9-5/8" CSG. NO HOLE FOUND. RIH. REV CIRC SAND & DIESEL. RECOVER RBP. L/D TOOLS. RIH W/ 7" BAKER POLISH MILL TO 7623'. POLISH TIEBACK SLEEVE. CBU. POOH. CIRC. MW: 9.9 KCl POOH. L/D DP. TEST BOPE. RIH W/ 7" BAKER SEAL & 7-5/8" CSG. STING INTO 7" TIEBACK LNR. CIRC. R£¢EIVED Nas[fa Oil & Gas Cons. Commission AnChorage WELL : A-18A OPERATION: RIG : DOYON 16 PAGE: 3 12/15/92 (17) TD:10150 PB: 0 12/16/92 (18) TD:10150 PB: 0 12/17/92 (19) TD:10150 PB:10056 12/18/92 (20) TD:10150 PB:10056 RIH WITH 3-1/2" DRILLPIPE MW: 9.9 KC1 CIRC WHILE BJ SERVICES BATCH MIXES CMT. PUMP 5 BBLS H20, TEST LINES TO 3000 PSI, PUMP 56 BBLS DIESEL, DROP BTM WIPER PLUG, PUMP 80 BBLS SEAWATER, PUMP 19 BBLS 15.8 PPG CMT, DROP TOP PLUG, DISPLACE FLUID WITH MUD USING RIG PUMP @ 8 BPM, DID NOT BUMP PLUG, CIP 0800 HRS, SLACK OFF ON CSG, STAB 7" SEAL ASSEMBLY IN TIE-BACK SLEEVE, PRESSURE.UP TO 1000 PSI TO CHECK SEALS IN TIE-BACK. RIG DOWN TORQUE TURN CSG CREW. N/S BOPE. SET SLIPS ON 9-5/8" CSG, SLACK OFF WEIGHT ON PIPE, CUT CSG, INSTALL NEW PACKOFF IN WELLHEAD, CUT & DRESS OFF CSG STUB FOR PACKOFF SEALING AREA, N/U TBG SPOOL. N/U BOPE. CHANGE RAMS FROM 7-5/8" TO 3-1/2". ATTEMPT TO TEST 9-5/8" PACKOFF, NO TEST' PUMP IN PACKING, CSG HGR PACKOFF TESTED. N/D BOPE. CHANGE OUT TBG SPOOL & 9-5/8" PACKOFF, N/U TBG SPOOL, TEST PACKOFF TO 3500 PSI, OK. N/U BOPE BRK DOWN LANDING JT, LAY DOWN BJ CMT HEAD & ELEVATORS. TEST BOPE, NO PROBLEMS. N/U 6-3/4" BIT, P/U 9-4-3/4" DRILL COLLARS, P/U 3-1/2" DRILLPIPE FROM PIPE SHED, RIH TO CLEAN OUT 7-5/8" CSG. DISPLACE WELL TO DIESEL MW: 9.9 KC1 RIH WITH 3-1/2 DRILL PIPE. TAG'CMT. AT 7440, BKR. CIRC TEST CSG. TO 3500 PSI OK. DRILL OUT CMT. PLUGS, FLOAT COLLAR, CLEAN OUT TO 7608. CBU. POH, LAY DOWN 6-34 BIT. MADE UP 6" BIT, 7" SCRAPER, RIH. DRILL CMT. F7608 TO 7640. CBU. PICK UP DRILL PIPE TO 9994. DRILL CMT.F 9994 TO 10056. CBU. TESTING PACKER MW: 9.9 NaC1/Br REV. CIRC. DISPLACE WELL TO 8.5 BRINE. TEST CSG. TO 3500PSI WITH SEA WATER. POH LAYING DOWN DRILL PIPE TO 7600 FT. CIRC. AND TREAT BRINE WITH CORROSION INHIB. POH LAYING DOWN DRILL PIPE AND BHA. PULL WEAR RING, RIG UP AND RUN 4-1/2 TBG. MADE UP TBG. HANGER, MADE UP CONTROL LINES, AND TEST TO 5000 PSI, LAND TBG. SET PACKER WITH 4000 PSI. RIG DOWN RIG MW: 8.5 NaC1/Br TEST PACKER. SET TWC. ND & REARRANGE BOPS. NU & TEST TREE. PULL TWC. U-TUBE DIESEL. INSTALL BPV. RELEASE RIG AT 1900 HRS. 12/17/92. SIGNATURE: (drilling superintendent) DATE: ~RRY-SUN DRILLING SERVICES,~"~ ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/A-18A 500292063001 NORTH SLOPE COMPUTATION DATE: 12/29/92 DATE OF SURVEY: 12/10/92 MAGNETIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-20094 KELLY BUSHING ELEV, = 86,10 FT, OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/IO0 NORTH/SOUTH EAST/WEST SECT. 7800 6987,00 6900,90 35 17 S 17',10 W ,00 2386.00S 870,00W 2510,58 7943 7106,77 7020,67 32 8 S 6,44 W 4,66 2463,86S 886,54W 2590,16 8037 7187,13 7101,03 29 31 S 2,07 E 5,43 2511.65S 888.50W 2637,41 8131 7270,50 7184,40 26 25 S 7,49 E 4,25 2555.74S 884,92W 2679,93 8225 7356,20 7270,10 22 18 S 12,82 E 4,95 2593,93S 878,22W 2716,05 8318 7443.03 7356.93 18 59 S 19.06 E 4.29 2625.39S 869.38W 2745.16 8411 7531.43 7445,33 16 12 S 25.09 E 3.59 2651.37S 858.96W 2768.58 8504 7621.62 7535.52 13 8 S 36.70 E 4,54 2671.65S 847.11W 2786,13 8595 7710.51 7624,41 12 6 S 52.97 E 4.05 2685.71S 833.30W 2797.19 8690 7802.77 7716.67 12 8 S 60.48 E 1.67 2696.55S 816,77W 2804.57 8782 7893,25 7807,15 12 19 S 61,08 E ,24 2706.12S 799,66W 2810,59 8876 7984,82 7898.72 12 41 S 60,11 E ,46 2716.10S 781,96W 2816,89 8969 8075,42 7989,32 12 51 S 59,03 E .31 2726.51S 764,24W 2823,60 9062 8166,30 8080,20 13 16 S 58,41 E .46 2737.46S 746,22W 2830,79 9154 8255,95 8169,85 12 47 S 58,96 E ,54 2748,25S 728.49W 2837.88 9248 8347,11 8261,01 12 36 S 58,96 E ,20 2758.83S 710,90W 2844,79 9339 8436,55 8350,45 12 28 S 56,85 E ,52 2769.40S 694,05W 2851.84 9433 8527,62 8441,52 12 32 S 54,68 E ,51 2780.77S 677,35W 2859,69 9524 8616,80 8530,70 12 10 S 53,66 E ,46 2792.21S 661,50W 2867,79 9618 8708,70 8622.60 11 31 S 53,67 E ,69 2803.63S 645.96W 2875,94 9710 8799,05 8712,95 11 5 S 53,27 E .49 2814.39S 631,44W 2883,62 9803 8890,69 8804,59 10 44 S 52,38 E .42 2825.07S 617,36W 2891,32 9896 8981.76 8895,66 10 38 S 52,95 E ,15 2835.50S 603,68W 2898,85 9991 9074,80 8988,70 10 25 S 52,74 E .24 2845.95S 589.88W 2906,39 10085 9167,67 9081,57 10 11 S 53.96 E ,34 2856.04S 576.33W 2913.61 10103 9185,01 909.8,91 10 9 S 53,90 E ,25 2857.88S 573,81W 2914.91 THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM HORIZONTAL DISPLACEMENT AT SOUTH 11 DEG, 21 MIN, ARE BASED ON THE USE CURVATURE METHOD, = 2914,91 FEET WEST AT MD = 10103 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 191,35 DEG, OF RECEIVED Alaska.Oil.& 8as Cons. Commissior~ ~nchorage S~RY-SUN DRT-LLING SERVICES ANCHORAGE ALASKA PAGE PRUDHOE BAY DRILLING PBU/A-18A 500292063001 NORTH SLOPE COMPUTATION DATE: 12/29 /92 DATE OF SURVEY: 12/10/92 JOB NUMBER: AK-EI-20094 KELLY BUSHING ELEV. = 86.10 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTR EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 7800 6987.00 6900.90 2386.00 S 870.00 W 813, 8800 7910,17 7824.07 2707,91 S 796.42 W 889, 9800 8887,03 8800.93 2824.64 S 617.91 W 912. 10103 9185.01 9098.91 2857.88 S 573,81 W 918. O0 83 76.83 97 23.13 04 5.07 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. RY-ASUN DRILL'[NG SER¥ICES/-'~ ' .' ' NCHORAGE ALASKA PAGE PRUDHOE BAY PBU/A-18A 500292063001 NORTH SLOPE COMPUTATION DRILLING DATE OF SURVEY: 12/10/92 JOB NUMBER: AK-EI-20094 KELLY BUSHING ELEV. = 86.10 DATE: 12/29/92 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASD DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES HD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 78OO 7919 8036 8149 6987.00 6900.90 2386.00 S 870.00 W 813.00 7086.10 7000.00 2450.86 S 884.84 W 833.31 20.31 7186.10 7100.00 2511.05 S 888.49 W 850.15 16.84 7286.10 7200.00 2563.24 S 883.85 W 863.08 12.93 8258 8364 8468 8570 8673 7386,10 7300.00 2605.48 S 875.38 W 872.00 8.93 7486.10 7400.00 2638.71 S 864.42 W 877.98 5.97 7586.10 7500,00 2664.44 S 851.95 W 882.01 4.04 7686.10 7600.00 2682.33 S 837.36 W 884.67 2.65 7786.10 7700.00 2694.78 S 819.89 W 886.95 2,29 8775 8877 8980 9O83 9185 7886.10 7800.00 2705.37 S 801.02 W 889.27 2.31 7986.10 7900.00 2716.24 S 781.71 W 891.69 2.43 8086.10 8000.00 2727.76 S 762.15 W 894.24 2.54 8186.10 8100.00 2739.91 S 742,24 W 896.92 2.68 8286.10 8200.00 2751.78 S 722.63 W 899.52 2.59 9288 8386.10 8300.00 2763.34 S 703.45 W 902.00 2.48 9390 8486.10 8400.00 2775.45 S 684.89 W 904.42 2.42 9492 8586.10 8500.00 2788.28 S 666.84 W 906.84 2.42 9595 8686.10 8600.00 2800.90 S 649.67 W 909.09 2.25 9697 8786.10 8700.00 2812.87 S 633.47 W 911.10 2.01 9799 9900 10002 10103 8886.10 8800.00 2824.54 S 618.05 W 912.95 1.85 8986.10 8900.00 2835.99 S 603.03 W 914.72 1,77 9086.10 9000.00 2847.21 S 588.23 W 916.43 1.71 9185.01 9098.91 2857.88 S 573.81 W 918.04 1.61 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS PA~E CO~'A~fi' F~tE/HOE BAY DRILL!NJ-' WELL N~£ A-18A LOCATION ! PBU WOA LOCATION 2 P~SHOE BAY, MAGNETIC DB]LIbaTiON DATE: 5-DEC-92 W~uL N~BER 0 WELL HEAD LOCATION: LAT(N/-S) 0.00 AZIMUTH FROM RItTARY TABLE TO TARGET IS TiE IN POiNT(TIP) ~ASL~ED DEPTH 7800,00 TRUE VERT DEPTH 6987,00 INC_.L!NATION ~ AZIMUTH !97,10 LATITUDE(N/-S) -238~00 DEP~:rURE(E/-W) -870,00 DEP(E/-W) 0,00 131,87 · ~;s Cons. ~ncl~Ora;~ .Comn~i~lon · ~£ MEASURED INTERVAL VE~ITiCAL DEPTH DEPTH ft ft ft 7800.00 0,0 6987°00 8028.93 228.9 7180.~. 8151,99 123.1 7289.t2 8217,33 65,3 7348,7i 8248,48 31,2 7377.59 0 ************* ANAI)RILL ********.*****.* S~E¥ CALCULATIONS **.***** MINIMUM CURVATURP. ME?HOD ******* TARGET STATION AZIMUTH LATITUDE SEC~i.ON iNCLN, N/-S ft deg deg ft 944,66 35,33 197,10 -2386.00 1~)9,27 29,82 181,7i -2506,47 1049.3t 25,65 172,~ -2563,51 1070.52 22,80 1080.08 2i,26 i67,58 -2601,21 DEPARTURE DISPLACEMENT at E/-W ft ft -870.00 2539.66 -89!,2i 2660,20 -886.57 2713.14 -883,69 ?.736,44 -861,04 2746,37 AZIMUTH deg 200.03 199,57 199,12 198,7i DLS deg/ lOOft 0.00 4.90 5,78 5,18 8280.71 ~313.53 8336,6i 8368,09 8400,05 32,2 7407,73 32,8 7438,64 25,t 7462.4i 2%5 7490.48 32,0 7521.0.I 1089,4I 20,21 166.39 -2612.33 1098,67 19,01 162~88 -~..~,~X~ ~t~ 110~,~ 18.24 lt.~,o. -2630.59 1~,~ i61,37 -2639.15 1113,34 ~ ~ 1121,59 16,74 1~.,83 -2647,~5 -878.48 2756,08 198.59 -875.57 2765,22 198,46 -873.18 2771.72 198.36 -870,38 2778,97 198,25 -867,19 27~.,34 198.13 3,49 5.13 3,!7 3,24 2,97 843i.52 84d.2.71 8492,97 8525,45 8555,21 31,5 7551,29 31,2 758!,45 30.3 7610,84 o=.~ 7642.49 29.8 767i.53 i129,46 15,26 154,40 -2655,91 1!36.90 14,35 151,11 1143,77 I3,14 146,67 -2~49,16 1!50,89 12,~) 143,29 -2675,15 1157,30 12,23 135~4i -2680,06 -863.76 2792,84 198,02 -860,12 27?6,46 197,90 -856,42 2803,19 197,79 -~.~,a~ 2807,62 197.67 -848,02 2811,03 197,56 6,10 3.97 5,30 2,46 6,19 8586,07 86i6,68 87!2.78 8803,86 8~96,60 30.9 770i,70 30,6 77.31.63 96,1 7825,62 91,1 79i4,~ 9'2,7 8~5.2t 11.($,80 12,12 13i,82 -2684,55 I170,1~ 11,95 1~,41 -2&~8,53 I189,94 12.18 I19,14 -2699.~ 1208,78 12,25 120,46 -2708,81 1~8.~B I2,5~ 1~,30 -2719,19 -843,3! 2813,89 197,44 -838,34 28i6,20 197,32 -821,37 2821,44 196,92 -804.65 2825,79 196,54 -787.63 28~),97 196,15 2.48 4.40 1.38 0,31 0,56 8989.13 9083,65 '"I "'~' 7~.,,.1 , . 92,5 8095~48 94.5 8i87,59 91,4 8276,75 92,3 83E4,96 0 ~ .5.~ 8460,20 I246.46 12,79 123,24 -2730.20 lz4.L -274~,96 1269,45 13,!4 . ~ 128%39 t2,33 123.~ -2753,14 1308,&~ 12,29 123,34 -2763,95 1~,04 12,34 125.60 -2775,47 -770,54 2836.85 195,76 -752,90 2843.45 195,~ -736,13 2849,85 194,97 -719,68 2856.11 194,59 -702,90 2863,09 I94,21 0,31 0,43 0,9! 0,05 0,5I PRO,~CTED SL$:VEY 9424,00 6i,2 85!9,96 1342.02 12.30 125.60, -2783.07 -692,29 2867,88 193,97 0,06 AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PERMIT ar ~Z -tO~ WELL NAME p ~1~ if3r--. COMPLETION DATE \'7_ I~..~t~,, CO. CONTACT' ~ CheCk off or list data as it is re~eiV'~d.*gst.., received date for 407. if not required list as NR 407' I*?.~l~Jq~ drilling histow ~' S~eY'I',J ' =.tests o I core descripUod~ cored inte~a!~ .. Fore ~.nalysis ,~-. d~.ditch intc~als .. dioltal data .......... , LoG 1'Y'PE ' ' RUN INTERVALS SCALE ' ' NO. . (to the nearest foot) ..... [inchl100'! ii i i Jl i i i ii i i i I i . Jl[lll ii I I II I[111111 IIIII I I I II 3) . ~..L-.X~, J~C ..... x, ~~::) ,--, i~,O~5 ~S, . I I ii i I i I iii I I i I iii I I I II I ii I ~ 11 tu . I I i i I I I I I I i J Il Il III I II II - L I I L II II II I I II I I I I I I - iii I I I I I I I ~"il ..... __1[ L ' 111111 I iiiiii I I III II I I i I I .................................... i ii ii ii I I I I I I III BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/30/22 T# 84193 BP/ PBU CH (PRODUCTION) LOGS Enclosed is your copy of the materials listed questions, please contact BP Well Records at B-12 ~$'~{ PRODUCTION LOG D-16~/-/g/ PFC M-18 gZ-'~! CCL P-14 R-08 8/'" x- [ x-26~-3o P~ODUCT[ON LOG ~-3 [ ~/.~ ~D[-[00 CCL PRODUCTION LOG PFC PRODUCTION LOG PRODUCTION LOG PRODUCTION LOG CCL 12/26/92 #1 12/22/92 #1 12/20/92 #1 12/23/92 #1 12/23/92 #1 12/23/92 #1 12/19/92 #1 12/20/92 #1 12/19/92 #1 12/21/92 #1 12/24/92 #1 12/21/92 #1 12/19/92 #1 below. If you have any (907) 564-4004. 7570.00-10028.00 ATLAS 5 " 9000.00- 9350.00 ATLAS 5 " 9650.00- 9880.00 ATLAS 5 " 8220.00- 8320.00 ATLAS 5 " 9450.00- 9540.00 ATLAS 5 " 10100.00-10285.00 ATLAS 5 " 10830.00-11090.00 ATLAS 5 " 9900.00-10350.00 ATLAS 5 " 10050.00-10680.00 ATLAS 5 " 11350.00-12000.00 ATLAS 5 " 9020.00- 9107.00 ATLAS 5 " 500.00- 965'0.00 ATLAS 5 " 10200.00-10503.00 ATLAS 5 " Information Control Well Records RECEIVED JAN 0 4 199 Naska 011 & ~s Cons. BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard PO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/29/92 T# 84185 BP/PBU CH & OH TAPES W/LISTINGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. F-41ST CH/TDT-P FIN 11047 . 00-11842 . 50 1600BPI API#50029'2220399 9210->TP# 10/22/92 #1 SCH REF#92632 8181.50- 9667.00 1600BPI API#500292231000 9211->TP# A-18A ....' gH ?DLT, '~ ~"~%""~, FIN 12/10/92 9395.00-10108.00 1600BPI API#500292063001 9212->TP# 12/10/92 #1 SCH REF#92721 #1 ATLAS REF#5760 . 01 Information Control Well Records JAN 0 4 1993 Alaskm Oil & Oas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO, Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/17/92 T# 84192 BP ~H LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-18A SUB SEA VERTICAL DEPTH MU 12/10/92 #1 9380.00-10075.00 ATLAS 1/2" Information Control Well Records ' R CEIVED DEC 2 2 1992 Alaska 011 & Gas Cons. Commission Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 12/16/92 T# 84184 BP OH LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. a-18a BHC/~ ~/6~ 12/10/92 #1 9600.00-10108.00 ATLAS A-18A DLL/~ 12/10/92 91 9380.00-10075.00 ATLAS II Information Control Well Records RECEIVED DEC £ 2 ~992 Alaska 0tl & Gas Cons. Commission Anchorage ALASKA OIL AND GAS CONSERVATION COM~IISSION / .WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: .(907) 276-7542 October 23, 1992 Karen M. Thomas Workover Engineer Supervisor BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit A-18A BP Exploration (Alaska), Inc. Permit No: 92-107 Sur. Loc. 2043'NSL,lO14'WEL, Sec. 35, TllN, R13E, UM Btmhole Loc. 847'SNL, 1646'WEL, Seo. 2, TiON, R13E, UM Dear Ms Thomas: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Da BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,:-¢j pfif,ted or~ rr,~'¥'cled pal,r,r I) y C..' t't STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION coMMISSION PERMIT TO DRILL 20 AAC 25.005 Re-Entry [] DeepenI-II Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration KBE = 86. l feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchoraoe. Alaska 99519-6612 ADI ~ ~/4~ z~4~ 4. Location of well at surface 7. Unit or property Name 11. Type Bond(aaa 2o ^^c 2s.o25) 2043' NSL, 1014' WEL, SEC. 35, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 343' SNL, 1886' WEL, SEC. 2, TION, R13E, UM A-18A (34-2-10-13) 2S100302630-277 At total depth 19. Approximate spud date Amount 847' SNL, 1646' WEL, SEC. 2, TION, R13E, UM 11/21/92 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVO) property line ADL 28286~847'feet No Close Approach feet 2560 10096' MD/9182' TVD~eet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 2s.o3s (e)(2)) Kickoff depth 7~o~feet Maximum hole ancjleas, a3° Maximum surface 3330pslg At total depth (TVD) 8800'/4390pslg 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length M D TVD M D TVD (include stage data) 8-1/2" 7" 26# 13CR/ Fox/ 2601' 7495' 6737' 10096' 9182' 522 cu ft Class "G" L-80 NSCC 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) OCT 3 6 1992 true vertical feet Alaska.0JJ & Gas Cons. Cornmiss~o~ Effective depth: measured feet Junk (measured) ;Anchorage true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 20" 284 sx Permafrost 110' 110' Surface 2637' 13-3/8" 3627cu fl AS I! 2670' 2670' Intermediate Production 7462' 9-5/8" 1380 cu ft "G" 9904' 8705' Liner 1298' 7" 420 cu fl "G" 9408'- 10706' 8338'-9425" Perforation depth: measured 9920'-10137' true vertical 8723'-8709' 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program [] Time vs depth plot [] Refraction analysis• Seabed report[] 20 AAC 25.050 requirements• 21. I hereby c~ify that the foregoing is true and correct to the best of my knowledge Signe~'~ ,,~x~_ ~ ~ '~~--~, ~ -- Title Workover Engineer Supervisor Date/(~//~,,~/~"~__ .,/'~- ' ' - Commission Use Only ,/ / ' ' Permit Number IAPI number IAppr0val date_ _ _ ISee cover letter ?!s o- o.z~_ ~,-. ~ 0.8 $ ~ -. o / I //0 ----c;~,.~ -" ~for other requirements Conditions of approval Samples requir?d [] Yes ~i~'No Mud log required [] Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directiona_[I survey required ~ Yes [] No Required working pressure for BOPE []2M; 1-13M; I~5M; []10M; !-115M; Other: Original Signed 1~¥ by order of Approved by David W. Johnston Commissioner tne commission_ ....... Form 10-401 Rev. 12-1-85 Submit in trii PROPOSED REDRILL PROGRAM WELL A'18A OBJECTIVE: To sidetrack the well to the northeast, away from a fault trend, to optimally situate the wellbore for a Zone 4 frac treatment. As the well is SI due to CAP communication to surface, a sidetrack is preferred in lieu of a RWO to repair the leak in order to shut-off prolific Zn 3 water production and an improved Zn 4 benefit stream production profile. A 7-5/8" tieback liner should be run inside the existing 9-5/8" casing to eliminate the communication. The proposed sidetrack will tie-into existing production flowline facilities and the existing 4-1/2" 13CR tubing should be in sufficient mechanical integrity to be re- run in the side-tracked location. A combination Sag River and Ivishak frac strategy will ensue after the rig move, thus, a latched production packer and GLMs will be required in the completion. CURRENT STATUS: Well A-18 was drilled in 11/81 and tested at an oil rate of 8270 BOPD, 0% water cut, and a 762 GOR in 8/82. A Gearhart spinner was run on 8/29/82 and identified production from the 46P, 45P, and 44P as 71%, 12%, and 17% respectively. The 71% assigned to the 46P, however, was noted coming from a .-,15' interval in the 46P at .-.10038'-10053' MD. By 1/83, the oil rate had declined to 1680 BOPD with a noted increasing WC. The well was SI after an unsuccessful HCL wash due to Iow oil rate and high WC. Once LP production headers were available in 8/84, the well came back on at 2410 BOPD while the watercut had increased to approximately 60%. The well returned to production with anomalously high PI (--,5.0) and WC (60%) compared to offset pattern Zn 4 radial flow producers. Two HCL stimulations were pumped in 12/85 to increase oil rate, but were unsuccessful. A PITS obtained in 5/86 indicated that no down channel existed in A-18. During 1986 and 1987, production continued to remain relatively constant at 2000 BOPD, 4000 BWPD, and solution GOR. After 3/25/88, the well began declining at a rate of 4.7% per month (immediately after the first 2 corrosion inhibition treatments). Sag River perforations were added on 6/5/89 in conjunction with a 5/89 HCL wash. A suite of production logs was requested in 11/89 to quantify the results, but the logging attempt was canceled due to collapsed tubing at 2025' MD. A RWO was completed in 5/90 which replaced the tubing string with 4-1/2" 12.6#/ft NT 13CR-80 tubing. Production logs were run by SOS on 8/1/90 which showed the -,.15' interval in the 46P pers as the dominant Pi contributor in the profile (ref attchs 1-1b). Subsequent CAMCO logs were run on 8/15/90 to verify the These production profiles prompted a results which is also shown in attachment 2. mud acid stim in 4/91 to initiate flow from apparent non-contributing Zn 4 perfs. To divert from the thief, ,-450 lbs of 40/60 Divert 1 material was pumped first from the CTU followed by 4 additional di,certer stages. The memory RECEIVED OCT 1 2 1992 Alaska 0il & 6as Cons. Commission Anchorage PROPOSED REDRILL PROGFIAM WELL A-18A CURRENT STATUS cont'd: gauge revealed less than 1 psi of diversion was achieved. This prompted a PNL/Borax log in 6/91 to determine the source of prolific water production (6000 BWPD) and potential channels. Borax, also larger than pore throat diameter, was not detected in the perfs or channels, except for a TRACE amount over the 15' anomaly (ref att. 3). As 3D seismic became available in 6/92, it has been determined that this interval is likely a high perm streak (possibly fractured) that communicates to the aquifer in Zn 3 through the nearby fault plane. This would explain an unusually high Zn 4 PI (analogous to Zn 3 GDWFI wells), early life high WC production (in the absence of channels or breakthrough), the lack of diversion response in the acid treatment, and explain the anomalous disappearance of Borax in the PNL survey. As the well was SI in 6/92 due to a 9-5/8" casing leak to surface, the most prolific economic alternative has been forecasted as sidetracking the wellbore off the fault trend and stimulating Zn 4 with a frac treatment. PERMITTING: The attached sundry notice covers the plugback of the original well and the drilling permit covers the proposed drilling program. R'£CEIVED OCT 1 2 1992 2~la's~,Oil.& Gas Cons. ROPOSED REDRILL PROG,...M WELL A-I{IA A18-A AFE SUMMARY PROCEDURE REV. 1.3 . . 3. 4. 5. . 6b. 7. , , 11. 12. 13. 14. 15. 15a. 16. 17. 18. 19. Pre-rig work: Kill well. Lay cement plug across perforations to at least 100' above top perforation. Cut 4-1/2" tubing at 8000' MD. Freeze protect. MIRU workover rig. Test intermediate packoff to 3500 psi. Pull BPV. Circulate out freeze protection fluid. Set two-way check valve. ND tree. NU 11" §M x 13-5/8" 5M DSA and BOP's. Test BOP's to 5000 psi. Pull two-way check valve. Pull and lay down 4-1/2" tubing. RIH w/9-5/6" bridge plug and set at 7955' MD. Run casing inspection Icg from 100' below the planned section cut to surface. RIH with a 9-5/8" section mill and cut a 60' section in the 9-5/8" casing starting at +/- 7795' MD. RIH with open-ended DP. Mix and pump 150 sacks of cement to spot balanced kick-off plug from 100' below the base of the section to 200' above the top of the section. Replace intermediate packoff if necessary. RIH with 8-1/2" steerable drilling assembly and dress off cement to 5' below section. Kickoff well and directionally drill to align well with target. Drill with a 8-1/2" packed hole assembly to total depth of 10096" MD / 9182' TVD or 150' MD below the OWC at -8950' ss TVD. RU wireline and Icg with the DLL / Microlog / GR / SP / Sonic / Neutron. Make wiper trip depending on hole conditions and logging time. Run 7" 29# 13CR FOX x 7" 26# L80 NSC¢ standard liner assembly to TD with liner top packer and +/- 150' lap. Crossover from 13CR to L-80 at 9487'MD. Cement liner with 450 sacks based on 40% open hole washout, shoe volume, lap volume, and 200' excess on top of liner with DP. Clean out liner to PBTD and test to 3500 psi. Test intermediate casing packoff to 3500 psi and replace if necessary. RU wireline and perforate. RIH with 4-1/2" 12.6# X 3-1/2" 9.3# completion string w/7" packer. Circulate corrosion inhibitor down the annulus. Space out, land completion, and set packer at ~ based on 200' above TOP OF SADLEROCHIT'. Test down tubing to 4000 psi. Test tubing x casing annulus to 3500 psi. Set two-way check Valve. ND BOP's. NU and test the 4-1/2" 5M tree to 5000 psi with diesel. Pull two way check valve. Shear RP valve and freeze protect. Set BPV. Release rig. Anticipated BHP: 7.8 ppg equiv Drilling Fluid' 9.5 ppg Workover Fluid: 8.5 ppg. RECEIVED OCT 1 Alaska 0il & Gas Cons. CommissiOn Anchorage PRELIMINARY WELL PLAN WELL: APl No.: LOCATION: ESTIMATED A18-A Redrill P B U 50-029-20630-00 (on the original A-18 well) Surface: 2043' FSL, 1014' FEL, Sec. 35, T11N, R13E Target: 813' FNL, 1684' FEL, Sec. 2, T10N, R13E @ 8870' ssTVD BHL: 847' FNL, 1646' FEL, Sec. 2, T10N, R13E @ 9096' ssTVD START; 21 November, 1992 OPR. DAYS TO COMPLETE: 16 CONTRACTOR: Doyon Rig #16 DIRECTIONAL: Kickoff at 7800' MD. turn.) WELLBORE: (22.75 degree angle drop and 65.2 degree east Item TVD(BKB) MD(BKB) Mucl Wt. 20" CONDUCTOR 110' 110' N/A 13-3/8" SHOE 2670' 2670' N/A KOP 6987' 7800' 9.3 TOP SAG RIVER 8788' 9692' 9.5 TOP SHUBLIK 8808' 9712' 9.5 TOP SADLEROCHIT 8881' 9787' 9.5 TOTAL DEPTH 91 82' 10096' 9.5 LOGGING PROGRAM: 8-1/2" Hole: DIL / GR / BHCS / CNL / SP MUD PROGRAM: The milling/drilling fluid program will consist of a 9.3 - 9.8 ppg XCD polymer / KCI water based mud in the 6" hole. DEPTH DENSITY PV YP INT 10 MIN FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/FT) GEL GEL cc/30min (%) (%) TYpF 6987' 9.3 10 10 5 7 8 0 5 Water to to to to to to to to to Base °REZ-"u" CEIVt:u OCT 1 ~ 1992 Alask~t 0ii .& Gas Cons, /knchomge. MUD WEIGHT CALCULATIONS / WELL CONTROL: Mud Wt. (8-1/2" Hole): 9.5 ppg. Est. Pore Press. Sag River: Est. Pore Press. Sadlerochit: 2600 psi/8702' ss TVD. 3550 psi/8800' ss TVD. Overbalance Sag River: Overbalance Top Sadlerochit: 1740 psi. 800 psi. Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and will be capable of handling "worst case" situations as follows: Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based upon original reservoir pressure. Maximum possible surface pressure is 3330 psi based upon a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Fluids incidental to the drilling of a well will be removed by truck and disposed down CC-2A. LINER DETAILS: CASING 7" 29# 13CR-80 FOX 7" 26# L80 NSCC DEPTH BURST COLLAPSE TENSILE 9487' - 100~6 MD 8160 psi 7030 psi 676 klbs 7495' 9487' MD 7240 psi 5410 psi 604 klbs CEMENT CALCULATIONS: 7" LINER: Measured Depth: Basis: Total Cement Vol: 7495'MD (Hanger)- 10096'MD (Shoe) 40% open hole excess, 40' shoe joints, 150' liner lap and 200' excess above liner with DP. 514 cu ft or 450 sxs of Class G blend @ 1.16 Cu ft/Sk TUBING DETAILS: 4-1/2" 12.6# 13CR;80 Fox' (0'- 7395' MD) 3-1/2" 9.2 # 13CR-80 Fox (7395' MD - 9587' MD) · RECEIVED 0 CT 1 2 1992 Alaska Oil & Gas Cons. Commission Anchorage DOYON RIG #16 MUD & SOLIDS CONTROL EQUIPMENT _ Continental Emsco FA1300 mud pump Brandt shale shaker _ Alfa-Laval centrifuge Triflow mud cleaner Gas buster m I ~ ~ _ _ _ Burgess Magna-Vac degasser Sidewinder mud hopper 5 H P agitators Abcor 10 HP agitators 40 bbls trip tank Recording drilling fluid pit level indicator with both visual and audio warning devices at driller's console Drilling fluid flow sensor with readout at driller's console RECEIVED OCT 1 2 1992 Alaska 0il & Gas Coils. Commlss[o~ Anchorage " TO: 987 564 5193 .--~OCT 2, 1992 3:00PM P.82 GREAT LAND DIRECTIONAL DRILLING, INC. Corporate Office 1111 East 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for PRUDHOE BAY DRILLING Well ......... , A-iCA (P2) Field ........ : PRUDHOE BAY A-PAD Computation..: MINIMUM CURVATURE LEGAL DESCRIPTION ~urfaee ...... : 20~3 FSL 1014 FEL S35 TllN R13E UM Tie-in ....... : 343 FNL 1886 FEL S02 T10N R13E UM Target ....... : 813 FNL 1684 FEL S02 T10N R13E UM BHL..' ........ : 847 FNL 1646 FEL S02 T10N R13E UM Prepared ..... : 10/02/92 section a%...~ S,48.13,E KB elevation.: 86.10 X ASP ZONE 4 Y 654398.81 5947209.50 653578.21 5944806.62 653790.00 5944341.00 653828.27 5944308.02 PROPOSED WELL PROFILE ~m~mmmmm~=~ mmmmm ~; STATION IDENTIFICATION TIE-IN MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-OOORDINATES DL/ DEPTH ANGLE BKB SUB-S DIST B~ARING FROM-WELLHEAD 100 7800 35.33 6987 6900 945 S 17.10 W 2386 S 870 W <TIE 7900 31.65 7070 6984 969 S 14.25 W 2439 S 885 W 4.0 8000 28.05 7157 7071 993 S 10.74'W 2487 S 895 .W 4.0 8100 24.56 7246 7160 1018 S 6.31 W 2531 s 902 W 4.0 8200 21.24 7338 7252 1042 S 0.56 W 2570 S 905 W 4.0 END OF 4/100 CURVE SAG RIVER 8300 18.19 7433 7346 1065 S 7.11 E 2604 S 903 W 4.0 8400 15.55 7528 7442 1089 S 17.51 E 2632 S 897 W 4.0 8500 13.57 7625 7539 1112 S 31.41 E 2655 S 887 W 4.0 8597 12.58 7720 7634 1133 S 48.13 E 2672 S 873 W 4.0 9692 12.58 8788 8702 1371 S 48.13 E 2831 S 695 W 0.0 SHUBLIK TOP SADLEROCHIT TARGET OWC OOWC 9712 12.58 8808 8722 1376 S 48.13 E 2834 S 692 W 0.0 9787 12.58 8881 8795 1392 S 48.13 E 2844 S 680 W 0.0 9864 l~.Sa 8956 8870 1409 S 48.13 E 2856 S 667 W 0.0 9946 12.58 9036 89S0 1427 S 48.13 E 2868 S 654 W 0.0 9997 12.58 9086 9000 1438 S 48.13 E 2875 S 646 W 0.0 ZONE 3 ZONE 2 TD 9997 i2.58 9086 9000 1438 S 48.13 E 2875 S 646 W 0.0 10034 12.58 9122 9036 1446 $ 48.13 E 2880 S 640 W 0.0 10096 12.58 9182 9096 1459 S 48.13 E 2889 S 630 W 0.0 (GLDD CC)92 PA18A B1,35 2:00 OCT 199 (ill & Gas Cons, Commission Anchorage FROM'GREAT LAND DIR.DRILL~ TO: 564 5193 ""~OCT 2, 1992 P. D3 'ibR'UDHO'E ....... i Sect ion Oepartur'e , (CLDg [0)92 PMOA BJ.35 2:27 PN 2) BAY'-O"J:::{'I LLI NG .... ...... ,-- ...... . ........ ..... i.:...:..i:, ¢,,, - ~ Z ' i ~-, , ¥-x-.F-:z'' ::"~'"'~ , . ............ ' ; --'~ '-; .... ~ - . ~.~ -~ , .... t -I --i ......... ~, ~ ' 2.: . - - 1 , ~t~ --CE .................. ~ ........ ' ~:~': F'.F ........ .... ~-:¥,:'i;;-;-~:;;;`':--,,_ :::~:~' 1 ~ ~--~----~-~,.~ ~ ....... ~ . .... ~r .... -F-'~ -~-._,~_,~ ,~ ~ ~................ iBO0 8000 2200 A-iSA (P2) VERTICAL SECTION iiii _ t ill i ~1 Section at: S 48.13 E TVD Scale,' t ~nCh : 400 feet Dep Scale,' 1 inch ~ 400 feet Dpawn · 10/02/92 VIEW Great Land Directional D/'i]]Jng ' l~ . I I _LI... iiii , ifil- Marker Identification HD BKB SECTN [NCLN k} lIE-IN 7800 6987 g45 35,33 BI END OF 4/~00 CURVE 8597 7720 ~33 J2.58 D) TO lOOg6 9t82 1459 t2.5B RECEIVED OCT 1 2 1992 Alaska Oil & Gas Cons. Commissio° 'Anchorage FRE)M:GRERT LRND I)IR.I)RILL~. TO: 90? 56~ 519~ ?'",~CT~ I ...............PRUDHOE BAY ........]RILLIN G I~arker Identificatio~ MD N/$ E/~ A) TIE-IN 7800 2386 S 870 ~ END OF 4/t00 CURVE BSg7 2672S 873 ~ ~J lARGET . 9B64 2856S 667~ 2, 1992 3:01PM P.04 A-CSA PLAN VIEW CLOSURE ..... : 2§57 ft at $ t2,30 W DECLINATION.' 29.98 E SCALE ' ! inch · 500 feet DRAWN,. · t0/02/92 IL IllI ill Il __ Great Land D~rectJona] Dr~lljng I i. - ..... . ........... -- ......... ~ ....... --- - "i .... : .......... -tB ........... ......... ----~.-I ....... J-'J , ..... .-_ ......... ; . .............. ........... -. .......... ........... . ....~ .... _ _ ..... .... ,-. ...................... ~-_--'~ ............ ~ ~ .... _m ...... .....j I ............. * .......... i..',.-- ~- , , J , .......... 3250 3000 2750 2500 2250 2000 1750 I§00 i250 ]000 750 500 250 0 250 <- WEST ' EAS! -> (GLOD (¢)92 PAISA B~.35 2:30 PH 2) 10.15 , ~ .... . .._ '] __.RI; I FLC] ~R ~ .............. ~.4o 4.5 HYDRIL __ ,, . ./ 15.40 Variable 3,5" x 6" Pip~ Ram 5.02 17.60 ~1Illl I~ ..... II .i..' "'~ Iii Illll I Variable 4.5" x 7L" Pipe Ram ....... ! .... '"~ 20.710 ~ MUD" . ~ ...... cross Blind Ram 1,80 '-I--- " 2.35 TBG ..L SPOOL 0.25 TBG I .... SPOOL BASE GROUND FLG LEVEL 24.85 25,10 A18-A PERMIT INFORMATION Permit Purposes ~ Well A- 18 A Type REDRILL Date 1 0/8/92 Engineer i MKE COOK Approx Spud Date 21-Nov-92 RKB (Original) 86.1 Ground Level 33.2 Distance to Nearest Well No near ~vell proximity , Proposed Depth(md/tvd) 10096/9182 KOP, depth 78 00 Max Hole Angle 35.33 Liner .Lap(il) 15 o' Surfac...e' Location 2043'FSL~ 1014'FEL~ SEC 35~ T11N~ R13E~ UM Tie-in 343' FNL, 1886' FEL, SEC 2, T10N ,R13E,UM Target Location 813'FNL, 1684'FEL, SEC 2, T10N, R13E, UM Bottom Location 847'FNL, 1646'FEL, SEC 2, T10N, R13E, UM Top Top Bottom Bottom Hole Casing Weight Grade Coupling Length IVlD TVD ~ TVD Quantity of Cement 30" 20" 91.5# H-40 WELD 80' 33 33 110 110 284sx Permafrost cml ~t~,¢',~ ,, 17 1/2" 13 3/8" 72# N-80 BTC 2637 33 33 2670 2670 3900sxs ASI1=3627 cu.ft. ~sn'~, 12 1/4" 9 5/8" 47# L-80 BTC 7462 33 33 7495 6737 1200sx. Class G =1380 cu.ft. -Ex~:~ · 8-1/2" 7" 26# 13CR/L-80 FOX/NSCC 2601 7495 6737 10096 9182 450sx Class G = 522 cu.ft. ,,, A18-A REDRILL A.- 18A C'..SG .XL..S ~ Alask~ A-..~A Prudhoe Bey Date 10/16/'32 ItE'r~0r: M, Minder IA 2A 3A 5A 6A 7A 8A 9A 10A Casing Size '7 '7 0 0 0 0 0 0 0 0 Interval Bottom 8602 9182" 0 0 0 0 0 0 0 0 Interval 'Top 6714, 8602. 0 0 0 0 0 0 Desaription ]esaription 'T'ensian Length Lbs Grade Thread I....b s 609 26 L.-.80 NSCC: 0 992 2_9 13C:R-80 F:'o× 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 0 0 0 (3 0 0 O 0 0 0 0 }esaription lB 6B 7B 8B 9B 10B Mud Wieght PPg 9.8 9.8 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 Hydrolytia Gradient psi/ft 0,510 0.510 0,000 0.000 0,000 0.000 0.000 0,000 0,000 0.000 Maximum Minimum Pressure Cat, aged psi Yield 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 10 2C SC 5C 6C '7C 8C 9C '! 0C Tension K/Lbs 15,8:)4" 5'7.768 0 0 0 0 0 0 0 0 Stren¢~ K/Lbs 604. 6'76 0 0 0 0 () 0 0 0 }"DF 11.70 #D~O~ Collapse Collapse Pr-Dot-Psi Resist. 4.384. 54"'10 4,6'79 7020 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Page 1 ITEM (1) Fee _ (2) Loc .... CHECK LIST FOR NEW WELL PERMITS .... PROVE DATE [2 thru (3) Admin ,~___ ~ '['9 thru [10 & 13] [14 thru 22] [23 thru 28] (5) BOPE (6) Other ,~C"~ []29 thru' 31] (7) Contact._ eo 1.g~,.~9_D~: eng i neet i ng: gWd_,~ MTM ~.~, ~~ 25 RP~ BEW JDH~_~~ LAG rev 08/18/92 jo/6.011 4 5 6 7 8 9~ 10. 11. 12. 13. 14 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. 30. 31. 32. Lease & Well NO ,, Company Is permit fee attached ............................................... 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 ..................... Is sufficient undedicated acreage available in this pool ............. Is well to be deviated & is wellbore plat included ........... ........ Is operator the only affected party .................................. Can permit be approved before 15-day wait ............................ Does operator have a bond in force ................................... Is a conservation order needed ....................................... Is administrative approval needed .................................... Is 1 ease n~nber appropriate ....................................... Does well have a unique name Is conductor string provided. Will surface casing protect al 1 zones reasonably expected to serve as an underground source of drinking water ................... Is enough cement used to circulate on conductor & surface ............ Will cement tie in surface & intermediate or production strings ...... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension, and burst. Is well to be kicked off from an existing wellbore ................... Is old wel lbore abandonment procedure included on 10-403 ............. Is adequate wel l bore separation proposed ............................. Is a diverter system required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... Are necessary diagrams & descriptions Does BOPE have sufficient pressure rating -- test to ~:~psig ..... Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... FOR EXPLORATORY & STRATIGRAPHIC WELLS' Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions O~esented... Name and phone ntmber of contact to supply weekly progress data ...... 33. Additional requ i rements ............................................. Additional INITIAL GEOL UNIT ON/OFF POOL CLASS STATUS AREA # SHORE \ REMARKS / / remarks' 0 -cZ ---! c~rrl m Z Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special'effort has been made to chronologically organize this category of information. ~ ~77/ A - 18A PRUDHOE BAY MICJ IL Run 1' 29 - July - 1993 PDK-100/GR Borax Log t925 Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RA~NGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD A - 1SA 500292063001 B.P. EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 07-SEP-93 5820.02 K. BRUNNER C. HUGHES 35 liN 13E 2043 1014 86.10 51.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 9.625 9855.0 3RD STRING 7.625 7621.0 PRODUCTION STRING 7.000 10136.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR UNKNOWN BASELINE DEPTH 9525.0 9585.0 9613.0 9668.5 9677.5 9679.5 9690.5 9695.5 9697.5 9699.5 9717.0 9724.0 9727.5 GRCH 9525.0 9585.0 9613.0 9668.5 9678.0 9680.0 9690.5 9695.5 9697.5 9699.5 9717.0 9724.0 9727.5 EQUIVALENT UNSHIFTED DEPTH 47.00 29.70 26.00 9743..0 9747.0 9750.0 9757.0 9766.5 9767.5 9769.0 9769.5 9786.0 9786.5 9787.5 9790.0 9795.5 9802.5 9812.5 9813.5 9818.5 9823.5 9824.0 9832.5 9846.5 9851.5 9876.0 9876.5 9881.5 9925.0 $ REMARKS: 9743.0 9747.0 9750.0 9757.0 9766.5 9767.0 9768.5 9769.5 9786.5 9787.0 9787.5 9790.0 9795.5 9802.0 9812.5 9813.0 9818.0 9823.0 9824.0 9832.5 9846.5 9851.5 9876.0 9876.5 9881.5 9925.0 PDK-100/GR Borax Log. LOG TIED INTO BHCS RUN 10-DEC-1992. LOG CONDITIONS WHILE FLOWING: OIL = 950 BOPD WATER = 4830 BWPD GAS = 2.25 MMSCFD LIFT GAS = 2.55 MMSCFD FWHT = 185 DEGF FWHP = 279 PSI LOGGING PROGRAM ORGANIZATION: 1. LOGGED FLOWING PDK PASS. 2. LOGGED 2 SEAWATER BASE PASSES. 3. LOGGED BORAX PASS 1 - 20 BBLS AWAY. 4. LOGGED BORAX PASS'2 - 60 BBLS AWAY. 5. LOGGED FLUSHED PASS - 40 BBLS SEAWATER FLUSH. 6. LOGGED 1 HOUR POST PUMP IN TEMPERATURE. PULLED OUT OF HOLE BECAUSE OF FAULTY BALL VALVE CLOSING. OPEN HOLE GAMMA RAY FOR DEPTH MATCHING SUPPLIED BY BP EXPLORATION (ALASKA) INC. ON 24-AUG-93. 1. FIRST PASS GAMMA RAY DEPTH MATCHED TO OPEN HOLE GAMMA RAY. 2. FIRST PASS SGMA DEPTH MATCHED TO "SHIFTED" FIRST GAMMA RAY. 3. ALL SUBSEQUENT GAMMA RAY PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS GAMMA RAY. 4. ALL SUBSEQUENT SGMA (PDK) PASSES DEPTH MATCHED TO "SHIFTED" FIRST PASS SGMA. $ FILE HEADER FILE NUMBER: 1 EDITED CURVES PASS NUMBER: 1 DEPT}{ INCREMENT: 0. 5000 FILE SUMMARY TOOL CODE START DEPTH GRCH 9581.0 PDK 9593.0 $ STOP DEPTH 9894.0 9906.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH SGMA 9525.0 9525.0 9594.0 9594.0 9650.5 9651.0 9698.0 9698.0 9699.5 9699.5 9717.0 9717.0 9727.5 9727.5 9737.0 9737.0 9743.5 9743.0 9757.5 9757.5 9793.0 9792.0 9818.5 9818.5 9832.5 9832.5 9846.5 9846.5 9851.5 9851.5 9872.5 9872.0 9881.0 9882.0 9902.5 9903.0 9925.0 9925.0 REMARKS: CN WN FN COUN STAT EQUIVALENT UNSHIFTED DEPTH FLOWING PASS. ALL PDK CURVES WERE SHIFTED WITH SGMA. GAMMA RAY WAS DEPTH MATCHED TO OPEN HOLE GAMMA RAY. $ : B.P. EXPLORATION : A- 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 2 BIF PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU $ RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS 4 00 201 24 1 4 00 201 24 1 4 00 201 24 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) Total Data Records: 51 966 BYTES * Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12016 datums Tape Subfile: 2 224 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 9584.0 9596.0 BASELINE DEPTH GRCH 9691.0 9692.5 9744.5 9745.5 9746.0 9746.5 9766.5 9767.0 9768.5 9768.5 9777.0 9778.0 9778.5 9778.5 9780.5 9781.0 9786.0 9785.5 9786.5 9786.0 9787.0 9787.0 9793.0 9798.0 9798.0 9799.0 9798.5 9801.0 9802.0 9802.5 9812.5 9812.5 9814.0 9814.0 9822.0 9821.5 9823.0 9822.5 9824.0 9823.0 9826.5 9826.5 9856.0 9856.0 9856.5 9856.5 9858.0 9877.0 9879.5 9881.0 9896.5 9899.5 9900.0 STOP DEPTH 9898.0 9910.0 (MEASURED DEPTH) -- EQUIVALENT UNSHIFTED DEPTH SGMA 9691.5 9692.0 9744.0 9744.5 9745.0 9746.0 9766.0 9767.0 9777.0 9777.5 9780.0 9781.0 9792.0 9801.0 9801.5 9802.0 9812.5 9858.0 9876.5 9879.0 9882.0 9896.5 9899.5 9900.0 $ REMARKS: CN WN FN COUN STAT SEAWATER PASS 1. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : B.P. EXPLORATION : A- 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 1 1 1 1 1 1 1 1 1 1 1 1 1 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 51 Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 12016 datums Tape Subfile: 3 118 records... Minimum record length: 62 bytes Maximum ~ecord length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 EDITED CURVES PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 9584.0 9596.0 STOP DEPTH 9898.0 9910.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 9525.0 9525.0 9588.0 9588.0 9650.5 9650.0 9652.5 9651.5 9668.5 9668.0 9675.0 9675.0 9691.0 9691.5 9692.5 9692.0 9696.0 9695.5 9699.0 9699.0 9700.0 9699.5 9704.5 9704.0 9709.5 9709.5 9710.5 9710.5 9711.5 9711.0 9717.0 9716.5 9722.0 9722.0 9724.0 9723.5 9727.5 9727.0 9739.0 9738.5 9740.5 9739.5 9744.0 9744.0 9753.0 9752.0 9753.5 9753.0 9758.5 9758.0 9759.5 9759.5 9762.5 9762.5 9767.5 9767.0 9769.5 9768.5 9778.5 9778.5 9781.5 9781.5 9786.0 9785.5 9785.0 9787.0 9785.5 9793.0 9793.0 9793.5 9792.5 9797.0 9795.5 9797.5 9796.5 9799.0 9798.5 EQUIVALENT UNSHIFTED DEPTH SGMA 9525.0 9802:5 9804.0 9812.5 9818.5 9819.0 9822.5 9823.5 9824.0 9826.0 9826.5 9827.5 9828.5 9832.5 9837.0 9837.5 9841.0 9846.0 9850.5 9851.5 9852.0 9856.0 9856.5 9858.0 9860.0 9867.0 9872.5 9878.0 9881.0 9899.5 9900.0 9902.0 9925.0 $ REMARKS: CN WN FN COUN STAT 9802.0 9803.0 9812.5 9812.0 9818.5 9819.0 9822.5 9823.0 9823.5 9825.5 9826.5 9826.5 9827.5 9828.0 9832.0 9832.5 9836.5 9837.5 9840.5 9845.5 9850.5 9851.5 9852.0 9856.0 9856.5 9857.5 9859.5 9866.0 9872.5 9878.0 9881.0 9899.5 9900.0 9902.0 9925.0 9925.0 SEAWATER PASS 2. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : B.P. EXPLORATION : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units Size API API API API Log Crv Crv Length Typ Typ Cls Mod 1 GRCH PDK 68 2 BIF PDK 68 3 BKL PDK 68 4 BKS PDK 68 1 GAPI 1 1 CPS 1 CPS 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 11 RIN PDK 68 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 51 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 4 56 966 BYTES * 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 00 201 24 00 201 24 00 201 24 00 201 24 00 201 24 00 201 24 Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24032 datums Tape Subfile: 4 150 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 EDITED CURVES PASS NUMBER: 4 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 9584.0 9596.0 BASELINE DEPTH GRCH 9600.0 9600.0 9628.5 9628.0 9650.0 9652.5 9651.0 9668.5 9668.0 9675.0 9675.0 9710.0 9712.0 9722.5 9723.0 9734.5 9735.5 9770.0 9770.0 9779.5 9780.5 9797.5 9797.5 9798.5 9798.0 9799.0 9798.5 9809.0 9810.0 9810.5 9812.5 9812.5 9823.5 9823.5 9824.0 9824.5 9824.0 9826.0 9826.5 9826.5 9827.0 9828.0 9855.5 9855.5 9856.0 9856.0 9869.5 9873.0 9877.5 9878.0 9896.0 9897.0 9899.5 STOP DEPTH 9898.0 9910.0 (MEASURED DEPTH) -- EQUIVALENT UNSHIFTED DEPTH SGMA 9650.0 9711.0 9711.5 9722.0 9723.0 9734.5 9735.0 9779.0 9779.5 9808.0 9808.5 9809.0 9812.5 9824.0 9826.5 9827.5 9828.0 9856.0 9869.0 9872.5 9877.5 9878.5 9896.5 9897.0 9899.5 9900'.0 REMARKS: CN WN FN COUN STAT 9900.0 BORAX PASS 1. 20 BBLS AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : B.P. EXPLORATION : A- 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PDK 68 1 GAPI 4 2 BIF PDK 68 1 4 3 BKL PDK 68 1 CPS 4 4 BKS PDK 68 1 CPS 4 5 CSLS PDK 68 1 CU 4 6 LS PDK 68 1 CPS 4 7 MSD PDK 68 1 CU 4 8 RATO PDK 68 1 4 9 RBOR PDK 68 1 4 10 RICS PDK 68 1 4 11 RIN PDK 68 1 4 12 SGMA PDK 68 1 CU 4 13 SGMB PDK 68 1 CU 4 14 SS PDK 68 1 CPS 4 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 51 Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 24032 datums Tape Subfile: 5 119 records... Minimum record length: Maximum record length: 62 bytes 966 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 EDITED CURVES PASS NUMBER: 5 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 9584.0 9596.0 BASELINE DEPTH GRCH 9525.0 9645.5 9646.0 9648.0 9651.0 9690.0 9690.5 9691.0 9691.0 9691.5 9692.5 9693.0 9693.5 9694.0 9703.5 9704.0 9710.5 9712.0 9720.5 9721.0 9738.0 9743.0 9749.5 9750.0 9750.5 9751.5 9754.5 9755.0 9764.0 9765.0 9768.5 9768.5 9785.5 9786.5 9786.0 9787.0 9786.5 9787.5 9787.5 9803.5 9816.0 9818.5 9823.0 9823.0 9824.0 9823.5 STOP DEPTH 9898.0 9910.0 (MEASURED DEPTH) -- EQUIVALENT UNSHIFTED DEPTH SGMA 9525.0 9646.0 9646.5 9648.0 9651.0 9691.0 9691.5 9692.5 9693.0 9694.0 9703.5 9704.5 9711.0 9711.5 9720.0 9721.0 9738.0 9742.5 9749.0 9750.0 9750.5 9751.0 9754.0 9755.0 9764.0 9764.5 9785.0 9785.5 9802.5 9816.0 9818.5 9823.0 9826~5 9830.0 9832.5 9833.5 9837.0 9839.0 9841.0 9843.0 9845.0 9846.5 9850.0 9851.0 9856.0 9857.0 9861.5 9874.5 9894.0 9902.5 9918.0 9925.0 $ REMARKS: CN WN FN COUN STAT 9826.5 9830.5 9832.5 9834.0 9837.0 9839.0 9841.0 9843.0 9845.0 9846.0 9850.0 9851.5 9856.5 9857.0 9861.5 9874.5 9894.5 9902.5 9918.0 9925.0 BORAX PASS 2. 60 BBLS AWAY. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : B.P. EXPLORATION : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 10 11 12 13 14 GRCH PDK 68 1 GAPI BIF PDK 68 1 BKL PDK 68 1 CPS BKS PDK 68 1 CPS CSLS PDK 68 1 CU LS PDK 68 1 CPS MSD PDK 68 1 CU RATO PDK 68 1 RBOR PDK 68 1 RICS PDK 68 1 RIN PDK 68 1 SGMA PDK 68 1 CU SGMB PDK 68 1 CU SS PDK 68 1 CPS 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 1 4 00 201 24 i 56 * DATA RECORD (TYPE# 0) Total Data Records: 51 966 BYTES * Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36048 datums Tape Subfile: 6 138 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 EDITED CURVES PASS NUMBER: 6 DEPTH INCREMENT: 0.5000 FILE SUMMARY TOOL CODE GRCH PDK $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS CURVE CODE: GRCH PASS NUMBER: 1 START DEPTH 9579.0 9591.0 STOP DEPTH 9898.0 9910.0 (MEASURED DEPTH) BASELINE DEPTH GRCH 9525.0 9525.0 9575.5 9573.5 9585.0 9583.0 9587.5 9585.5 9597.0 9595.0 9645.5 9642.5 9646.0 9643.5 9650.5 9648.5 9652.0 9649.0 9668.5 9666.0 9675.0 9672.5 9679.0 9677.5 9685.5 9683.0 9691.5 9689.0 9692.5 9689.5 9696.0 9693.5 9698.0 9695.5 9699.5 9696.5 9704.0 9701.0 9705.5 9702.5 9710.5 9708.0 9708.0 9717.0 9714.5 9717.5 9715.0 9722.0 9719.5 9722.5 9720.0 9727.5 9725.0 9728.0 9725.0 9728.5 9726.0 9735.5 9733.0 9736.5 9733.5 9745.0 9742.0 9742.5 9746.0 9743.0 9746.5 9744.0 9753.5 9750.5 9754.0 9751.5 9758.0 9755.5 9758.5 9756.0 9763.5 9761.0 EQUIVALENT UNSHIFTED DEPTH SGMA 9525.0 976410 9764.5 9776.5 9783.0 9784.0 9786.0 9787.0 9787.5 9793.0 9799.0 9803.0 9812.5 9813.5 9815.5 9818.0 9818.5 9821.0 9833.0 9846.0 9851.0 9855.5 9856.0 9858.0 9873.5 9878.5 9881.5 9883.0 9884.5 9886.0 9893.0 9894.0 9899.5 9900.0 9902.5 9925.0 REMARKS: CN WN FN COUN STAT 9761.5 9761.5 9774.5 9780.0 9780.5 9783.0 9784.0 9785.0 9789.5 9796.5 9799.5 9809.5 9810.5 9813.0 9815.5 9816.0 9818.5 9830.5 9830.5 9843.0 9848.5 9853.0 9853.5 9855.0 9870.5 9876.5 9879.0 9881.0 9883.0 9884.5 9890.5 9891.5-- 9897.0 9897.5 9900.0 9925.0 9925.0 FLUSH PASS. 40 BBLS SEAWATER FLUSH. ALL PDK CURVES WERE SHIFTED WITH SGMA. $ : B.P. EXPLORATION : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units GRCH PDK 68 1 GAPI Size API API API API Log Crv Crv Length Typ Typ Cls Mod 4 00 201 24 1 2 'BIF~PDK 68 1 3 BKL PDK 68 1 CPS 4 BKS PDK 68 1 CPS 5 CSLS PDK 68 1 CU 6 LS PDK 68 1 CPS 7 MSD PDK 68 1 CU 8 RATO PDK 68 1 9 RBOR PDK 68 1 10 RICS PDK 68 1 11 RIN PDK 68 1 12 SGMA PDK 68 1 CU 13 SGMB PDK 68 1 CU 14 SS PDK 68 1 CPS * DATA RECORD (TYPE# 0) Total Data Records: 51 966 BYTES * 56 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 4 00 201 24 Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 36048 datums Tape Subfile: 7 153 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. Pulsed Neutron: Unaveraged edited Pass 1 gamma ray and background counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT: 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS PDK GRCH $ REMARKS: CN WN FN COUN STAT 2, 3 1 AVERAGED PASS. BASE SEAWATER PASSES WERE AVERAGED. $ : B.P. EXPLORATION : A- 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GRCH PNAV 68 1 GAPI 4 2 BKLS PNAV 68 1 CPS 4 3 BKSS PNAV 68 1 CPS 4 4 BIF PNAV 68 1 4 5 CSLS PNAV 68 1 CU 4 6 LS PNAV 68 1 CPS 4 7 MSD PNAV 68 1 CU 4 8 RATO PNAV 68 1 4 9 RBOR PNAV 68 1 4 10 RICS PNAV 68 1 4 11 RIN PNAV 68 1 4 12 SGMA PNAV 68 1 CU 4 13 SGMB PNAV 68 1 CU 4 14 SS PNAV 68 1 CPS 4 4 16 470 06 1 4 71 784 90 5 4 30 969 81 0 4 96 505 81 0 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 4 71 784 90 5 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 51 Tape File Start Depth = 9925.000000 Tape File End Depth = 9525.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 48064 datums Tape Subfile: 8 73 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 9 is type: LIS FILE HEADER FILE NUMBER: 8 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9580.0 PDK 9592.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9895.0 9907.0 29-JUL-93 FSYS REV. J001 VER. 1.1 1218 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10136.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 'TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: FLOWING PASS. $ CN WN FN COUN STAT : B.P. EXPLORATION : A- 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 06 511 09 0 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 120 Tape File Start Depth = 9925.000000 Tape File End Depth = 9566.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 66226 datums Tape Subfile: 9 196 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 10 is type: LIS FILE HEADER FILE NUMBER: 9 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9583.0 PDK 9595.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9907.5 9919.5 29-JUL-93 FSYS REV. J001 VER. 1.1 1353 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL NUMBER 2725XA 2324NA 2120XA 0.000 10136.0 0.0 PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE · TOP 'NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: SEAWATER PASS 1. $ CN WN FN COUN STAT : B.P. EXPLORATION : A- 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 06 511 09 0 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 O0 201 24 1 4 52 386. 28 5 4 05 626 89 6 8O * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 118 Tape File Start Depth = 9923.000000 Tape File End Depth = 9570.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 77738 datums Tape Subfile: 10 194 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 11 is type: LIS FILE HEADER FILE NUMBER: 10 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9583.0 PDK 9595.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9909.0 9921.0 29-JUL-93 FSYS REV. J001 VER. 1.1 1412 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10136.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 'TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: SEAWATER PASS 2. $ CN WN FN COUN STAT : B.P. EXPLORATION : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 i CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 06 511 09 0 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 118 Tape Fil'e Start Depth = 9924.000000 Tape File End Depth = 9572.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 95816 datums Tape Subfile: 11 194 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 12 is type: LIS FILE HEADER FILE NUMBER: 11 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9584.0 PDK 9596.0 $ LOG HEADER DATA 'DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9907.0 9919.0 29-JUL-93 FSYS REV. J001 VER. 1.1 1457 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10136.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): ~%TRI X: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 'TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: BORAX PASS 1. 20 BBLS AWAY. $ CN WN FN COUN STAT : B.P. EXPLORATION : A- 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 .7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 4 39 705 61 4 74 169 61 4 92 630 79 4 00 201 24 4 00 201 24 4 35 975 96 4 36 631 32 4 06 511 09 4 00 201 24 4 71 162 89 4 00 201 24 4 23 260 40 4 23 260 40 4 23 260 40 4 23 260 40 4 96 761 61 4 00 201 24 4 52 386 28 4 05 626 89 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 118 Tap~ Fil~ Start Depth = 9922.000000 Tape File End Depth = 9570.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 107328 datums Tape Subfile: 12 194 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 13 is type: LIS FILE HEADER FILE NUMBER: 12 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9583.0 PDK 9595.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 9908.0 9920.0 29-JUL-93 FSYS REV. J001 VER. 1.1 1527 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ TOOL NUMBER 2725XA 2324NA 2120XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10136.0 0.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE 'TOP ~ORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN) : 0.0 REMARKS: BORAX PASS 2. 60 BBLS AWAY. $ CN WN FN COUN STAT : B.P. EXPLORATION : A- 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 06 511 09 0 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 O0 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 118 Tap~ Fil~ Start Depth = 9923.000000 Tape File End Depth = 9571.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 125406 datums Tape Subfile: 13 194 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 14 is type: LIS FILE HEADER FILE NUMBER: 13 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 6 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9578.0 PDK 9590.0 $ LOG HEADER DATA STOP DEPTH 9904.0 9916.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR PDK PDK-100 CCL CASING COLLAR LOC. TEMP TEMPERATURE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 29-JUL-93 FSYS REV. J001 VER. 1.1 1614 29-JUL-93 9921.0 9922.0 9600.0 9911.0 1500.0 YES TOOL NUMBER 2725XA 2324NA 2120XA 0.000 10136.0 0.0 PRODUCED / SW-BORAX 0.00 0.0 223.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE ~TOP ~ORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): 0.0 0.0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 600 FAR COUNT RATE HIGH SCALE (CPS): 3100 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 60000 TOOL STANDOFF (IN): 0.0 REMARKS: FLUSH PASS. 40 BBLS SEAWATER FLUSH. $ CN WN FN COUN STAT : B.P. EXPLORATION : A - 1SA : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 20 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 BIF PDK 68 1 4 2 BKL PDK 68 1 CPS 4 3 BKS PDK 68 1 CPS 4 4 CCL PDK 68 1 4 5 CSLS PDK 68 1 CU 4 6 CSS PDK 68 1 CPS 4 7 G1 PDK 68 1 CPS 4 8 G2 PDK 68 1 CPS 4 9 GR PDK 68 1 GAPI 4 10 ISS PDK 68 1 CPS 4 11 LS PDK 68 1 CPS 4 12 MSD PDK 68 1 CU 4 13 RATO PDK 68 1 4 14 RBOR PDK 68 1 4 15 RICS PDK 68 1 4 16 RIN PDK 68 1 4 17 SGMA PDK 68 1 CU 4 18 SGMB PDK 68 1 CU 4 19 SPD PDK 68 1 F/MN 4 20 SS PDK 68 1 CPS 4 4 00 201 24 1 4 39 705 61 6 4 74 169 61 6 4 92 630 79 6 4 00 201 24 1 4 00 201 24 1 4 35 975 96 1 4 36 631 32 1 4 06 511 09 0 4 00 201 24 1 4 71 162 89 6 4 00 201 24 1 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 23 260 40 0 4 96 761 61 6 4 00 201 24 1 4 52 386 28 5 4 05 626 89 6 80 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 118 Tape File Start Depth = 9920.000000 Tape File End Depth = 9567.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 137002 datums Tape Subfile: 14 194 records... Minimum record length: 44 bytes Maximum record length: 1014 bytes Tape Subfile 15 is type: LIS O1 **** REEL TRAILER **** 93/ 9/ 7 01 Tape Subfile: 15 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 7 SEP 93 3:56p Elapsed execution time = 30.59 seconds. SYSTEM RETURN CODE = 0 A - 18A PRUDHOE BAY IdlCI OFILIdED Run 1' 10 - December - 1992 DLL/ACIGR rOlO8 RECEIVED JAN 0 4 1993 Alaska 011 & Gas Cons. Commlssh /~p~horafle Tape Subfile 2 is type: LIS TAPE HEADER PRUDHOE BAY UNIT OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD A - 18A 500292063000 BP EXPLORATION (ALASKA) INC. ATLAS WIRELINE SERVICES 18-DEC-92 RUN1 RUN2 RUN3 5760.01 JOHN DAHL M. WARREN H. HAYWOOD N. SCALES 35 liN 13E 2043 1014 86.10 51.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 8.500 REMARKS: 9.625 7794.0 DLL/AC/GR CIRCULATION STOPPED: 11:00 10-DEC-92. LOG TIED TO ORIGINAL LOGS AT CASING POINT: CNL-FDC 11-22-81/SWS. DRILLING DEPTH MEASURED FROM CURRENT R.K.B. OF 77.4' ABOVE M.S.L. REPEAT SECTION LOGGED TO TD. MAIN PASS LOGGED FROM 10100' DUE TO POSSIBLE STICKING ON BOTTOM. ACOUSTIC CYCLE SKIPPING ON REPEAT PASS FROM 9790'-9795' $ RECEIVED JAN 0 4 1995 Alaska 011 & (~as GODS. Gommlsslon Anchorage FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS All tool strings; depth shifted and clipped curves; hole data. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR BCS DLL $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA 0.5000 START DEPTH STOP DEPTH 9395.0 10087.5 9608.0 10108.0 9395.0 10075.0 GR (MEASURED DEPTH) BASELINE DEPTH DT 9395.0 9395.0 9398.0 9531.0 9531.5 9565.0 9582.0 9616.0 9616.5 9647.0 9650.0 9651.0 9675.0 9698.0 9710.5 9716.0 9716.5 9721.5 9727.0 9727.5 9735.5 9737.5 9741.5 9743.0 9747.5 9757.5 9771.0 9780.0 9787.5 9798.0 9801.0 9818.0 9820.5 9828.0 9833.0 9834.0 9845.0 9847.5 9850.0 9861.5 9871.5 9872.5 9616.5 9647.0 9650.5 9675.0 9710.5 9717.0 9722.0 9727.5 9736.5 9741.5 9747.5 9771.0 9787.0 9818.0 9832.0 9847.0 9850.0 9872.0 all runs merged; EQUIVALENT UNSHIFTED DEPTH LL3 LLD 9395.0 9395.0 9398.5 9398.5 9531.0 9531.5 9565.5 9582.5 9616.5 9616.5 9647.0 9650.0 9650.0 9675.0 9675.0 9698.0 9716.5 9722.0 9722.0 9727.0 9727.0 9736.5 9736.5 9743.0 9743.0 9747.0 9794.5 9756.5 9777.5 9785.0 9797.5 9818.0 9818.5 9826.5 9832.5 9844.0 9872.5 9861.0 no case 9882.0 9882.5 9882.5 9896.0 9896.5 9896.5 9902.0 9902.0 9911.0 9916.5 9940.0 9946.5 9946.5 9967.5 10005.0 10056.5 10137.0 10137.0 10137.0 $ MERGED DATA SOURCE PBU TOOL CODE RUN NO. PASS NO. GR 1 5 GR 1 4 BCS 1 5 BCS 1 4 DLL 1 5 DLL 1 4 $ REMARKS: CN WN FN COUN STAT 9882.0 9896.0 9911.0 9916.5 9940.0 9967.5 10005.0 10056.5 10137.0 MERGE TOP MERGE BASE 9395.0 10058.0 10058.0 10087.5 9608.0 10089.5 10089.5 10108.0 9395.0 10064.0 10064.0 10075.0 THE BOTTOM PORTION OF THE REPEAT PASS WAS SPLICED ONTO THE MAIN PASS FOR COMPLETE DATA COVERAGE. NO DATA WAS RECORDED TO TAPE FOR INTERVAL FROM 9380' - 9395' AS IS SHOWN ON BLUE LINE. DATA COVERAGE IS FROM 9395' TO T.D. TENS, TEND, & MTEM WERE SHIFTED WITH LL3. SP WAS SHIFTED WITH LLD. $ : BP EXPLORATION (ALASKA) : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod GR BCS 68 1 GAPI DT BCS 68 1 US/F TEND BCS 68 1 LB TENS BCS 68 1 LB LL3 DLL 68 1 OHMM LLD DLL 68 1 OHMM SP DLL 68 1 MV MTEM DLL 68 1 DEGF 4 67 465 06 6 4 84 653 71 5 4 20 789 90 0 4 20 789 90 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 54 32 Tape File Start Depth = 10137.000000 Tape File End Depth = 9395.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13366 datums Tape Subfile: 2 197 records... Minimum record length: Maximum record length: 42 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 for Sadlerochit run presented first (primary depth control string used to depth shift the Sadlerochit interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 5 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9395.0 9600.0 9395.0 AC DLL $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): STOP DEPTH 10081.0 10100.0 10070.0 10-DEC-92 FSYS REV. J001 VER. 1.1 1100 10-DEC-92 1942 10-DEC-92 10150.0 10116.0 9395.0 10108.0 1500.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 8.500 7794.0 0.0 KCL POLYMER 9.90 48.0 8.5 4.8 185.0 0.141 0. 057 71.0 185.0 MUD FILTRATE AT MT: MUD FILTRATE AT BHT: MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: MAiN PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A- 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.104 68.0 0.000 0.0 0.178 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 RS DLL 68 1 OHMM 4 8 RD DLL 68 1 OHMM 4 9 ES DLL 68 1 MV 4 10 ED DLL 68 1 MV 4 11 IS DLL 68 1 A 4 12 ID DLL 68 1 A 4 13 SP DLL 68 1 MV 4 14 TEMP DLL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 179 Tape File Start Depth = 10107.000000 Tape File End Depth = 9395.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 42736 datums Tape Subfile: 3 256 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 4 DEPTH INCREMENT: 0.2500 FILE S~RY VENDOR TOOL CODE START DEPTH GR 9674.0 AC 9694.0 DLL 9662.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): STOP DEPTH 10111.0 10131.0 10100.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CHT TEMP PCM MIS DLL GR MIS AC $ CABLEHEAD TENSION TEMPERATURE PULSE CODE MODULATOR MASS ISOLATION SUB DUAL LATEROLOG GAMMA RAY MASS ISOLATION SUB BHC ACOUSTILOG BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT MT: MUD FILTRATE AT BHT: 10-DEC-92 FSYS REV. J001 VER. 1.1 1100 lO-DEC-92 1925 10-DEC-92 10150.0 10116.0 9395.0 10108.0 1500.0 TOOL NUMBER 3974XA 2806XA 3506XA 3967XA 1229MA/1229EA 1309XA 3967XA 1603MA/1609EB 8.500 7794.0 0.0 KCL POLYMER 9.90 48.0 8.5 4.8 185.0 0.141 0.057 0.104 0.000 71.0 185.0 68.0 0.0 MUD CAKE AT MT: MUD CAKE AT BHT: NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : REMARKS: REPEAT PASS. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : A - 18A : PRUDHOE BAY : NORTH SLOPE : ALASKA 0.178 68.0 0.000 0.0 0.00 0.000 2.0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 14 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR AC 68 1 GAPI 4 2 AC AC 68 1 US/F 4 3 ACQ AC 68 1 4 4 CHT AC 68 1 LB 4 5 TTEN AC 68 1 LB 4 6 SPD AC 68 1 F/MN 4 7 RS DLL 68 1 OHMM 4 8 RD DLL 68 1 OHMM 4 9 ES DLL 68 1 MV 4 10 ED DLL 68 1 MV 4 11 IS DLL 68 1 A 4 12 ID DLL 68 1 A 4 13 SP DLL 68 1 MV 4 14 TEMP DLL 68 1 DEGF 4 4 06 969 49 6 4 48 852 89 1 4 81 285 47 0 4 95 558 30 1 4 95 558 30 1 4 61 094 30 1 4 40 514 81 0 4 39 859 45 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 30 739 95 0 4 23 415 80 5 4 84 503 82 1 56 * DATA RECORD (TYPE# 0) 966 BYTES * Total Data Records: 129 Tape File Start Depth = 10137.000000 Tape File End Depth = 9625.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 44102 datums Tape Subfile: 4 204 records... Minimum record length: 62 bytes Maximum record length: 966 bytes Tape Subfile 5 is type: LIS 92/12/17 01 **** REEL TRAILER **** 92/12/21 01 Tape Subfile: 5 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 21 DEC 92 8:15a Elapsed execution time = 25.76 seconds. SYSTEM RETURN CODE = 0