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198-038
8650, 9990, 10370, 10835 Unknown, 9100, 10835(x3) 325-038 By Grace Christianson at 4:23 pm, Jan 28, 2025 Digitally signed by Sean McLaughlin (4311) DN: cn=Sean McLaughlin (4311) Date: 2025.01.28 16:02:52 - 09'00' Sean McLaughlin (4311) *Variance as per 20 AAC 25.112(i): Approved for alternate abandonment plug placement on parent well contingent upon fully cemented liner on upcoming sidetrack. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. DSR-1/31/25 10-407 SFD 2/7/2025 325-060 JJL1/29/25*&: 2/7/2025 Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.02.07 11:03:57 -09'00' RBDMS JSB 021025 12,169' 8,953' 8,953'8,953' To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt Drilling Engineer Date: January 28, 2025 Re:H-29A Sundry Request Sundry approval is requested to set a whipstock and mill a window in the H-29A wellbore as part of the drilling and completion of the proposed H-29B CTD lateral. Proposed plan for H-29B Producer: Prior to drilling activities, screening will be conducted to drift for whipstock, pull PX plug and MIT. E-line or coil will mill the XN-nipple. E-line will set a 4-1/2" packer whipstock. Coil will mill window pre-rig. If unable to set the whipstock or milling the window, for scheduling reasons, the rig will perform that work. See H-29B PTD request for complete drilling details - A coil tubing drilling sidetrack will be drilled with the Nabors CDR2 or CDR3 rig. The rig will move in, test BOPE and kill the well. If unable to set whipstock pre-rig, the rig will set the 4-1/2" packer whipstock. A single string 3.80" window will be milled. The well will kick off drilling in the Shublik and lands in Ivishak Zone 2. The lateral will continue in Zone 3 and 2 to TD. The proposed sidetrack will be completed with a 3-1/2"x3-1/4"x2-7/8” 13Cr solid liner, cemented in place and selectively perforated post rig (will be perforated with rig if unable to post rig). This completion will completely isolate and abandon the parent Prudhoe Pool perfs. 20 AAC 25.112(i) Variance Request: Hilcorp requests to plug the existing perforations via the packer whipstock, liner cement job and/or liner top packer, if the liner lap pressure test fails as an alternate plug placement. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. Pre-Rig Work: (Estimated to start in February 2025) x Reference H-29A Sundry submitted in concert with this request for full details. 1. Slickline : Dummy WS drift and pull PX plug 2. E-Line : Set 4-1/2" Packer Whipstock* at 8,953’ MD at 275 degrees ROHS 3. Fullbore : MIT-IA and/or MIT-T to 2,500 psi (min) 4. Coil : Mill XN nipple to 3.80" and Window (if window not possible, mill with rig). See attached procedure. 5. Valve Shop : Pre-CTD Tree Work 6. Operations : Remove wellhouse and level pad. *Window milling on service coil not approved on 10-403, refer to sidetrack PTD for approval. Rig Work: 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,323 psi). Give AOGCC 24hr notice prior to BOPE test. 2. Mill 3.80” Window (if not done pre-rig). 3. Drill build section: 4.25" OH, ~182' (30 deg DLS planned). 4. Drill production lateral: 4.25" OH, ~3,034' (12 deg DLS planned). 5. Run 3-1/2” x 3-1/4” x 2-7/8” 13Cr liner (swap to VBRs and test prior to running liner) 6. Pump primary cement job: 42 bbls, 14.8 ppg Class G, TOC at TOL*. 7. Only if not able to do with service coil extended perf post rig – Perforate Liner 8. Freeze protect well to a min 2,200' TVD. 9. Close in tree, RDMO. * alternate plug placement 20 AAC 25.112(i) variance request Post Rig Work: 1. Valve Shop : Valve & tree work 2. Service Coil : RPM log, perforate (~40’) 3. Slickline : Run GLVs, set LTP* (if necessary), set Nipple Reducer & TTP 4. Eline : Set patch over tubing leak @ 6090' MD 5. Slickline : MITT, pull TTP Trevor Hyatt CC: Well File Drilling Engineer Joe Lastufka 907-223-3087 Well Date Quick Test Sub to Otis -1.1 ft Top of 7" Otis 0.0 ft Distances from top of riser Excluding quick-test sub Top of Annular 2.75 ft C L Annular 3.40 ft Bottom Annular 4.75 ft CL Blind/Shears 6.09 ft CL 2-3/8" Pipe / Slips 6.95 ft B3 B4 B1 B2 Kill Line Choke Line CL 3.0" Pipe / Slip 9.54 ft CL 2-3/8" Pipe / Slips 10.40 ft TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level 3" LP hose open ended to Flowline CDR2-AC BOP Schematic CDR2 Rig's Drip Pan Fill Line from HF2 Normally Disconnected 3" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3-1/8" Pipe / Slip Well Date Quick Test Sub to Otis Top of 7" Otis Top of Annular C L Annular Bottom Annular CL Blind/Shears CL 2-3/8" Pipe / Slips B6 B5 B8 B7 Choke Line Kill Line CL 3" Pipe / Slip CL 2-3/8" Pipe / Slips TV1 TV2 T1 T2 Flow Tee Master Master LDS IA OA LDS Ground Level CDR3-AC BOP Schematic CDR3 Rig's Drip Pan Fill Line Normally Disconnected 2" HP hose to Micromotion Hydril 7 1/16" Annular Blind/Shear 2-3/8" Pipe/Slips 2 3/8" Pipe/Slips 2 3/8" Pipe/Slips 7-1/16" 5k Mud Cross 2-3/8" Pipe/Slips 3" Pipe / Slip neceeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeeee 7. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: PBU H-29A Attempt Cmt Squeeze, Attempt to Fish CT Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-038 50-029-21813-01-00 11050 Conductor Surface Intermediate Liner Liner 8944 80 2646 8492 550 2334 9100 20" 13-3/8" 9-5/8" 7" 4-1/2" 8714 30 - 110 30 - 2676 28 - 8520 8350 - 8900 8716 - 11050 30 - 110 30 - 2676 28 - 8231 8088 - 8564 8402 - 8944 Unknown, 9100, 10835 470 2670 4760 5410 7500 9990, 10370, 10835 1490 5380 6870 7240 8430 9156 - 10940 4-1/2" 12.6# 13cr80, L80 26 - 8718 8745 - 8938 Structural 4-1/2" Baker S-3 Packer 8661, 8352 8517, 8661 8229, 8352 Torin Roschinger Operations Manager Josh Stephens josh.stephens@hilcorp.com (907) 777-8420 PRUDHOE BAY, Prudhoe Oil Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: ADL 0028284 26 - 8404 9900 - 10370'MD Pumped 16-bbls of 15.8-ppg cement and attempted perforation squeeze. Final treating pressure = 2400-psi. 658 Well Not Online 50523 1656 627 1100 1415 190 323-321 13b. Pools active after work:Prudhoe Oil 4-1/2" Baker S-3 Packer 8517, 8229 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 3:46 pm, Sep 08, 2023 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.09.08 14:27:21 -08'00' Torin Roschinger (4662) RBDMS JSB 091123 DSR-9/12/23WCB 4-9-2024 ACTIVITY DATE SUMMARY 5/10/2023 CTU 9 - 1.75" CT - .156" wt - 16,250' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP MIRU on H-29A, Install Scaffold ***Continue WSR on 5/11/2023*** 5/10/2023 LRS Test Unit 6, Begin WSR on 5/10/23 IL H-29 / OL H-16, Assist CTU Cement Mill, Unit Move, Begin RU,PT, Continue WSR on 5/11/23 5/11/2023 CTU 9 - 1.75" CT - .156" wt - 16,250' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP MIRU on H-29A, Install Scaffold, RIH with BOT Milling Assembly 5 Blade Junk Mill 3.700" RIH, tag CIBP, mill plug at 2.5bpm, push plug down to 10850, (to top of CIBP at 10835') POOH ***Continue WSR on 5/12/2023*** 5/11/2023 LRS Test Unit 6, Continue WSR from 5/10/23 IL H-29 / OL H-16, Assist CTU Cement Mill, CTU Rig Up, Assist CTU, CTU RIH, Continue WSR on 5/12/23 5/12/2023 CTU 9 - 1.75" CT - .156" wt - 16,150' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP RIH with HES Depth Control Logging Assembly w/3.700" Drift DJN. Work Log tools down while Pumping On/Off. Jet at CBP setting depth. Make logging Pass 10800' - 9500'. Paint Yellow Flag @ 10300'. POH, Download log data. RIH with BOT CBP, set @ 10370'. ***Continue WSR from 5/11/2023*** 5/12/2023 LRS Test Unit 6, Continue WSR from 5/11/23 IL H-29 / OL H-16, Assist CTU Cement Mill, Continue to Assist CTU, Continue WSR on 5/13/23 5/13/2023 CTU 9 - 1.75" CT - .156" wt - 16,150' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP Attempt to get BOT Cement Stinger down to Retainer set @ 9990'. Tag @ 9671'. POOH to re-assess BHA and plan forward. RIH with BHOT venturi 3.70 mule shoe. Ventrui from 9100-9990 and then back to 9000. Dry drift down to retainer with no issues. POOH ***Continue WSR on 5/14/23*** 5/13/2023 LRS Test Unit 6, Continue WSR from 5/12/23 IL H-29 / OL H-16, Assist CTU Cement Mill, Continue to Assist CTU, Continue WSR on 5/14/23 Daily Report of Well Operations PBU H-29A Daily Report of Well Operations PBU H-29A 5/14/2023 CTU 9 - 1.75" CT - .156" wt - 16,100' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP Attempt to get BOT Cement Stinger down to Retainer set @ 9990'. No Issues. Perform injectivity test. Stack down on retainer, appear to be stung in. Pump 16 (of 25) bbls of cement away, attempt to un sting. Coil pulles heavy, 51K. Coil is stuck on retainer. Pump disco ball, on seat. Flowing well with GL. Will pump acid. launch disconnect ball, able to disconnect after pressuring up to 6500psi with MM bypassed. Not free, pump bottoms up while starting gas lift. Able to achieve 1.6bpm circulation at 4000psi after pumping mulitple gel sweeps. Still not free, Order acid, shower trailer and soda ash. ***Continue WSR on 5/15/23*** 5/14/2023 LRS Test Unit 6, Continue WSR from 5/13/23 IL H-29 / OL H-16, Assist CTU Cement Mill, Flowback to Free up Coil DH, Continue WSR on 5/15/23 5/15/2023 T/I/O = 200/1650/0. Temp = 130°. Bleed IAP to 700 psi ( CTU request). ALP = 2150 psi, SI @ CV. IA FL @ 7323' ( 464' above sta # 2, DMY). CTU in control of well upon arrival. Bled IAP through choke skid to OT from 1650 psi to 650 psi in 3 hrs. Monitored while rigging down. IA, OA, IA FL unchanged. CTU in control of well upon departure. 19:30 5/15/2023 LRS Test Unit 6, Continue WSR from 5/14/23 IL H-29 / OL H-16, Assist CTU Cement Mill, Flowback to Free up Coil DH, Acid FLow Back, SI H-29, Continue WSR on 5/16/23 5/15/2023 CTU 9 - 1.75" CT - .156" wt - 16,100' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP Continue with Acid pumping small pills, maximizing soak time bewtween pills. 15-20 minutes each. 33 cycles on coil @ 0400. allow last acid pill to soak 3 hours. bring AL back online Circulate acid out, pumped 10bbl gel sweep with no increase in circulation rate. Curculated for 45 min at 5k psi 2.6bpm with no change. Shut in IA, bleed down with DHD ***Job in Progress*** 5/16/2023 LRS Test Unit 6, Continue WSR from 5/15/23 IL H-29 / OL H-16, Assist CTU Cement Mill, RD hardline around H-29 for Eline Ops, Eline on LOC & begining Chem Cutter run inside Coil, Continue WSR on 5/17/23 5/16/2023 CTU 9 - 1.75" CT - .156" wt - 16,100' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP Kill well with seawater, follow with safelube. Work pump, choke, surface valves to surge coil with pressure. Kill well and CTC, perform No flow test on both, Freeze protect surface coil. Strip off, hot tap, install yellowjacket CTC. Stack down injector. E- line rig up to stack, PT. Make up Eline jet cutter. Stabbed on well RIH with Eline. Pump tool downhole, ***Continue WSR on 5/17/23*** Daily Report of Well Operations PBU H-29A 5/16/2023 ***COIL IN CONTROL OF WELL ON ARIVAL*** PRESSURE TEST PCE TO 200#LP-3,000#HP RIH W/ 1" CHD, 4 X 1" WB's, 1.188" JET CUTTER (1.188" MAX OD, 22' OAL) ATTEMPT TO PUMP TS DOWN FROM 9,660' @ .3 BPM WALK PUMP RATE UP TO 1 BPM PUMP TS DOWN TO 9,804' job continued 5/17/2023 5/17/2023 CTU 9 - 1.75" CT - .156" wt - 16,100' L Job Scope: Mill CIBP, Set CBP & Retainer, Cement, Mill Out Cement, Retainer and CBP RIH with EL jet cutter. Work cutter down from 9806' to CTC at 9975'. EL depth adjusted for Coil CTC depth. PUH 15' after weight back. Jet Cut Coil at 9960'. POOH, pumping 8.4 seawater down CTBS. Radio silence with cutter back @ 300'. TIW valve installed on coil stump. Recover Eline BHA. Jet Cutter Fired. Install TIW on Coil Stump. Confirm No Flow on Tbg & Coil. Remove TIW. Install Double Spoolable Dimple Coil Connector. Dump Traction & Strip over Coil & Stab on well. Re-apply Traction Pressure. Pull 36k. Open Pipe & Slip Rams. Pull 50k, Coil not free. Cycle pipe without putting the Connector below the chains. No movement, Coil still stuck. Discuss with OE. Good no flow on Coil & Tbg. Pull 37k. Close Slip & Pipe Rams and manual lock downs. Dump traction and unstab/strip off Coil. Hot tap/cut Coil directly below the spoolable connector. ***Job In Progress*** 5/17/2023 LRS Test Unit 6, Continue WSR from 5/16/23 IL H-29 / OL H-16, Assist CTU Cement Mill,, Eline on LOC & Continuing Chem Cutter run inside Coil, END WSR on 5/17/23, Job Complete 5/17/2023 job continued from 5/16/2023 PUMP W/ SLB DOWN COIL @ 1 BPM, 1.25 BPM, & 1.5 BPM ABLE TO PUMP CUTTER DOWN TO COIL CONNECTOR @ 1.5 BPM CUTTER DIFFERENTIALLY STUCK @ COIL CONNECTOR PUMP DOWN BACK SIDE OF COIL TO FREE CUTTER PICK UP 15' FROM TAG DEPTH -33' CORRECTION TO CORRELATE TO CTMD @ COIL CONNECTOR FIRE CUTTER @ 9,960.0' CONFIRM CUTTER FIRED UNABLE TO MOVE COIL job continued 5/18/2023 5/17/2023 T/I/O = 0/840/0. Temp = 130°. Bleed IAP to 500 psi ( CTU request ). ALP = 900 psi SI @ CV. IA FL @ 7348' ( 439' above sta # 2, SO). CTU in contol of well. Bled IAP through choke to OT from 840 psi to 500 psi in 1.25 hrs. IA FL unchanged. No monitor. Final WHPs = 0/500/0. Upon departure CTU in contol of well. WV = C. SV, SSV, MV = O. IA, OA = OTG. 12:30 5/18/2023 LRS Test Unit 6, Begin WSR on 5/18/23, Begin Unit Maintenance, Begin Vessel Clean Out, Continue WSR on 5/19/23 Daily Report of Well Operations PBU H-29A 5/18/2023 CTU#9 1.75" CT. Job Scope: Cut & Recover Stuck Coil. Install External CTC / TIW to Coil stub. Continue to keep hole full. Rig up AK Eline. Eline RIH with 1" Wt-Bars & 7/8" RCT Cutter BHA. Cut Coil @ 9100'. Eline had overpull after cutting due part of BHA that is below the cut. Eline Pooh. RCT Cutter Fired, Left in Hole lower half of the RCT Nozzle and the PBA (pressure balanced anchor). Lost die grinder bit while removing Coil weld seam. Install double dimple connector. Open Pipe & Slip Rams. Coil is Free. Pull Coil OOH. FP tubing/38 bbls diesel. Swab Check from 400'. Blow down reel with N2. RDMO to SLB yard for pipe swap. ***Job Complete*** 5/18/2023 job continued from 5/17/2023 PRESSURE TEST PCE AGAINST CLOSED TIW ON COIL STUB TO 200#LP- 3,000#HP RIH W/ 3/4" CHD, 2 X 1" WB, 7/8" RCT (1" MAX OD, 19' OAL) CUT W/ RCT @ 9,100' GOOD INDICATION ON VOLTAGE & CURRENT, WIRE VIBRATION & NOISE & MOVEMENT ON WH FROM COIL RELAXATION PULL 100# OVER NORMAL UP TENSION TO MOVE TS OFF OF CUT LOWER SECTION OF RCT TORCH & PBA BROKEN OFF OF TS ***FISH LIH: LOWER PORTION OF NOZZLE=.875"OD X 1.5"LENGTH, PBA=.885"OD BODY X 48" LENGHT, PBA ROLLERS=1"OD (LOCATED 3", 5", 46", & 48" FROM TOP OF FISH), FISH OAL=49.5"*** ***CT LEFT IN CONTROL OF WELL*** 5/19/2023 LRS Test Unit 6, Cont WSR from 5/18/23, Cont Vessel Clean Out ( Cement Solids in multiple Lines), End WSR 5/19/2023 LRS Well Testing Unit #1. Begin WSR on 5/19/23. Continue RD on H-29. RD complete, End WSR 5/19/29 5/19/2023 LRS Test Unit #1. Continue from 5/18/23 WSR , Continue Standby. Continued to 5/19/23 WSR 7/8/2023 *****WELL S/I ON ARRIVAL**** RAN 3.50" LIB TO COIL CUT @ 9,085' SLM(good impression) RAN 3.50" MAGNET TO COIL FISH @ 9.085' SLM(no recovery) ****WELL LEFT S/I ON DEPARTURE, PAD-OP NOTIFIED OF STATUS*** 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-29A Fish Coiled Tubing, Mill CIBP Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 198-038 50-029-21813-01-00 341I ADL 0028284 11050 Conductor Surface Intermediate Liner Liner 8944 80 2646 8492 550 2334 9990 20" 13-3/8" 9-5/8" 7" 4-1/2" 8940 30 - 110 30 - 2676 28 - 8520 8350 - 8900 8716 - 11050 2480 30 - 110 30 - 2676 28 - 8231 8088 - 8564 8402 - 8944 10835 470 2670 4760 5410 7500 9990, 10370, 10835 1490 5380 6870 7240 8430 9156 - 10940 4-1/2" 12.6# 13cr80, L80 26 - 87188745 - 8938 Structural 4-1/2" Baker S-3 Packer 4-1/2" Baker S-3 Packer 8517, 8229 8661, 8352 Date: Torin Roschinger Area Operations Manager Michael Hibbert Michael.Hibbert@hilcorp.com (907) 303-5990 PRUDHOE BAY 6/14/2023 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov No SSSV Installed By Grace Christianson at 9:48 am, Jun 01, 2023 323-321 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2023.06.01 06:09:52 -08'00' Torin Roschinger (4662) MGR05JUN23 DSR-6/1/23SFD 6/5/2023 Approved to fish 1.75" coil tubing fish with 1.75" service coil. CO 341J SFD GCW 06/06/2023 JLC 6/6/2023 06/06/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.06.06 15:10:22 -08'00' RBDMS JSB 060723 H-29A PTD:198-038 Well Name:H-29A API Number:50-029-21813-01 Current Status:Natural Flow Producer Rig:CTU Estimated Start Date:6/14/2023 Estimated Duration:4days Regulatory Contact:Abbie Barker First Call Engineer:Michael Hibbert 907-903-5990 907-903-5990 Second Call Engineer:Josh Stephens 907-777-8420 (O)970-779-1200 (M) Current Bottom Hole Pressure:3250 psi @ 8800’ TVD 7.2 PPGE | Average Ivishak BHP Max. Anticipated Surface Pressure:2480 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2480 psi (Taken =1/2/2023) Min ID:3.725” ID @ XN NIP @ 8,706’ Angle:107° @ ~10,019’, 70° @ 9,240’ Brief Well Summary: H-29A is an operable natural flow Ivishak producer, located in the GDWFI-GD area. The sidetrack was completed in 1998 and targeted Zone 2B (25P).The well has competitive oil production in the heel and toe of the well, while the perforations in the belly of the lateral were perforated below the OWC. This program will isolate/squeeze these uncompetitive perf intervals and result in a more competitive well (hopefully shutting off ~3500 bwpd). On 5/14/23 while CT was executing this water shut-off program the coiled tubing became stuck while stung into the cement retainer. A disconnect ball was pumped, but still were unable to move pipe. Two cuts were made (15’ above CT BHA at 9960’ and again at 9100’). After the second cut the 9100’ of coiled tubing above the cut was recovered (see attached current wellbore schematic for detail). Current fish in hole include 860’ of 1.75” CT and a second fish of 15’ of 1.75” CT and CT BHA. Objective Fish stuck coiled tubing and CT BHA. Mill out retainer, cement, and CBP down to 10,835’. CTU Squeeze with Portable Test Separator 1. MIRU CTU and PT 2. MU milling BHA with 3.7” junk mill a. Dry tag Weatherford CIBP @ 9,734’ b. Mill CIBP and push below 10,800’ c. POOH 3. MU and RIH with memory flag BHA - GR/CCL in carrier – discuss if this flagging run is necessary or if tags with milling BHA were close enough to correct off of a. Provide Tie-In log to OE Michael Hibbert 907-903-5990 or GEO Ashlyn Murphy at 832-417-1640 for final confirmation of tie-in. 4. MU 4-1/2” CBP 5. RIH and set CBP at ~10,365’ MD 6. MU 4-1/2” cement retainer (use Baker composite if available). RIH and set @ ~9,990’MD. Discuss retainer selection, preferably one that holds pressure from both direction. If this type is not available then may need to load well with diesel to prevent overbalance condition. a. Come up-hole if needed to be certain the retainer set is above the top of the perf interval from 10,012’-10,032’ after accounting for coil elongation. Plenty of room to move up-hole, it will just mean more cement to mill. b. Consider doing an injectivity test prior to setting retainer - pump down CTBS and compare to injectivity after setting retainer. n operable natural flow Ivishak producer, H-29A PTD:198-038 c. Also perform injectivity down CT through the set retainer and potentially make cement volume adjustments if it low injectivity (this is unlikely since we believe the zones being shutoff are very high water producing zones). 7. Pump the following down CT: a. 5 BBls 60/40 mix b. 10 bbl freshwater spacer c. 25 BBL 15.8 ppg cement – see attached cement design i. Theoretical worst cast TOC is 8,717’ MD (bottom GLM @ 8438’) if no cement enters the perfs 1. 5.5 bbls between CBP and retainer 2. 19.5 bbls from retainer to 8,717’ d. 5 bbl FW spacer – increase this volume if needed operationally. e. Powervis or equivalent contaminant Coil volume of fresh water or diesel (depending on ambient temps) 8. If no squeeze pressure is built then; a. pump 24 bbls of cement through the retainer b. unstab from the retainer and lay in remaining 1 bbls of cement in 4-1/2” liner c. PUH to safety and bring well online through test separator with GL d. circulate bottoms up with contaminate/KCL 9. If squeeze pressure starts to build, then continue squeezing away until a sqz pressure of 2500 psi is seen or until 24 bbls of cement has been pumped to the retainer. Hold for 30 min. Unstab from retainer and lay in remaining cement above retainer. a. Bring well online through test separator with GL b. Pump contamination/KCL and circulate cement out of the well. 10. POOH and WOC. SL – D&T CT fish 1. RIH and tag fish. 2. Run LIB and confirm clean CT cut. 3. Run magnet to see if any debris or junk comes back. x Upper fish is from 9100’ down to 9960’ and is 1.75” CT, .156” wall. x Lower fish is cementing BHA and 15’ of coiled tubing stub @ 9960’ - ~15’ of 1.75” CT .156” wall - CTC 3.110" x .93', TJ Disco (3/4" ball) 3.130" x 2.28', Centralizer 3.620" x 1.23', XO 3.000" x .64', Knuckle Jt. 2.880" x 1.09', XO 3.000" x .43', Centralizer 3.620" x 1.02', XO 3.120" x .85', Pup Jt. 3.060" x 6.18', Stinger 3.680" x 2.75' Max OD = 3.680" OAL = 17.4') x Loose debris – EL left 26” PB Roller stem @ upper cut depth of 9100’ inside of CT. Die-grinder bit was dropped into CT from surface while dressing off weld seam for double – dimple connector. x See picture folder for pics of RCT cut and fish left in hole. CT – Fish CT and cementing BHA 1. MIRU 1.75” CTU. x Precise tree measurements are needed for proper space out. 2. RIH loaded for bear and latch coiled tubing fish with releasable pack-off overshot. x Pump gel pills as required. x Acid pills as required. 3. Recover 860’ of 1.75” CT. H-29A PTD:198-038 x With CT back at surface, coil fish across the BOP stack, and the overshot at a height that leaves a coil stub that you can stab a spoolable connector, note PU weight and then close pipe and slip rams. x Do a push/pull to confirm fish you’ve got it. x Pump KWF down the coil to ~25bbl past coil fish. x Once complete, continue pumping and get off of the fish. x Bullhead KWF x With a passing flow check, maintain hole fill. Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the potential open hole deployment 24-hour crew and WSS coverage is required. x The well will be killed and monitored prior to fish recovery operation. x *Perform drill by picking up external CTC with TIW valve and space out. Review well control steps with crew prior to breaking lubricator connection and commencing fish recovery operations. Once the external CTC and TIW valve have been spaced out, keep the external CTC/TIW valve readily accessible near the working platform for quick deployment if necessary. x Pop off, lay down fishing assembly, and install spoolable connector. i. Have a CTC, box x box XO, and FOSV ready to be installed if needed. ii. Standing orders for if flow is detected – stab external CTC and close TIW if possible. If not possible then open pipe/slip rams and drop fish and close SSV remotely and swab valve manually. Final contingency shear the pipe. x Push/pull to test spoolable connector x Open pipe and slip rams, recover coil i. Exercise caution with swab checks from an appropriate depth – fish is anticipated to be 860’ ii. Also, there is the risk that there may be cement on the backside of the coil fish and may not come through the brass. iii. If weights appear heavy. Stop pipe, close pipe/slip, bleed off pressure if necessary then uncollar and inspect coil fish. iv. If there is cement on the backside of the coil fish. Set up handling equipment, and recover fish with crane, lift nubbins and cut coil in pieces and discard in metal dumpster. 4. If no progress made, run piranha mill and attempt to mill or spin fish. Determine rop milling and discuss plan forward with OE. 5. If fish spins then run back in hole with fishing BHA and attempt to pull fish. 6. Once CT fish recovered, RU well testers. 7. POP well through PTS. Run 3.700” milling BHA and mill to clean out and remove any cement or formation sand taking returns to PTS. x Once down to the TBG stub, POOH chasing gel pill at 80%. 8. Shut in well and RIH with venturi burn shoe to recover loose fish/debris and potentially dress off coil stub at 9960’ (lower cut was made with jet-cutter). ID of burnshoe needs to be such that it will dress off the likely flared end of the 1.75” sticking up. Compare to the uphole end of the cut. 9. MU releasable packoff overshot and jar lower fish and attempt to recover – call and discuss with OE. x Once at surface attempt to close lower master valve. If lower master closes then breakdown BHA/fish as per normal. H-29A PTD:198-038 x If unable to close lower master then perform flow check and proceed with open hole operation to recover fish. i. With a passing flow check, maintain hole fill. ii. Make up slip bowl and single pick BHA. iii. Close tree valves as soon as fish clear of tree. Notes: x Remote gas monitoring for H2S and LELs are required for Open Hole Deployment Operations x Due to the potential open hole deployment 24-hour crew and WSS coverage is required. x The well will be killed and monitored prior to fish recovery operation. x *Perform drill by picking up external CTC with TIW valve and space out. Review well control steps with crew prior to breaking lubricator connection and commencing fish recovery operations. Once the external CTC and TIW valve have been spaced out, keep the external CTC/TIW valve readily accessible near the working platform for quick deployment if necessary. 10. If lower fish recovered POP well to PTS, then PU motor and 3.70” mill and mill retainer, cement and CBP down to 10,800’. Prior to milling the CBP, chase debris above the upper perfs at 9156’-9166’ MD and circulate gel pill to surface. 11. Mill CBP. 12. FP well and RDMO CTU. CTU w/ Portable testers 11. Once cement reaches 800-1000 psi compressive strength then MU 2-7/8” motor and ~3.7” junk/PDC mill. 12. RIH and mill retainer, cement, and CBP down to ~10,800’. Bring well online through test separator with GL to maintain returns. 13. Pump final sweep and circulate bottoms up while POOH. 14. FP tubing with ~ 38 bbls diesel. 15. POOH. 16. RDMO and handover to Operations to POP well. Attachment 1. Current Wellbore Schematic 2. Proposed Schematic 3. Tie In Log/Perf Sheet 4. CT BOP Schematic 5. Standing Orders for Service Coiled Tubing Operations with Extended Length BHAs 6. Sundry Change Form H-29A PTD:198-038 Current Wellbore Schematic CBP set at 10,370’ Retainer set at 9990’ 1.75” CT with RCT cut end @ 9100’ – 860’ of 1.75” CT Jetcut @ 9960’ - 15’ of 1.75” CT with cementing BHA stung into retainer at 9990’ Cement from 9990’-10,370’ H-29A PTD:198-038 Proposed Wellbore Schematic Squeeze high water-cut perfs – 10,012’-10,032’ & 10,300’-10,350’ H-29A PTD:198-038 H-29A Tie-In Log H-29A PTD:198-038 CBP – Set at ~10,365’ Retainer – Set at ~9,990’ H-29A PTD:198-038 BOP Schematic H-29A PTD:198-038 Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Work Over Sundry ProcedureDate: May 31, 2023Subject: Changes to Approved Sundry Procedure for Well H-29ASundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the workover (WO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.StepPageDate Procedure ChangeHNSPreparedBy (Initials)HNSApprovedBy (Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date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y Samantha Carlisle at 4:52 am, Feb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• ALIDA OIL AND GAS CONSERVATION COMMION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon❑ Repair Well ❑ Plug Perforations ❑ Perforate Other 0 Mill CIBP Performed: Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program Cl Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended WE 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: BP Exploration(Alaska),Inc Name: Development El Exploratory❑ 198-038-0 3.Address: P.O. Box 196612 Stratigraphic ❑ Service III 6.API Number: Anchorage,AK 99519-6612 50-029-21813-01-00 7. Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 PBU H-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 11050 feet Plugs measured 10835 fee "'V t true vertical 8944.27 feet Junk measured See Attachment feet JAN 062015 Effective Depth measured 10835 feet Packer measured See Attachment feet true vertical 8934.05 feet true vertical See Attachment feet Ar1^/1�1 Casing Length Size MD TVD Burst t Collapse a Structural None None None None None None Conductor 80 20"Conductor 30.48-110.48 30.48-110.48 0 0 Surface 2644.78 13-3/8"72#L-80 29.98-2674.76 29.98-2674.39 4930 2670 Intermediate 8495.95 9-5/8"47#L-80 25.88-8521.83 25.88-8233.01 6870 4760 Production None None None None None None Liner 2330.4 4-1/2"12.6#L-80 8719.48-11049.88 8405.23-8944.27 8430 7500 Perforation depth Measured depth 10012-10032 feet 10300-10320 feet 10320-10350 feet 10660-10800 feet 10870-10940 feet True Vertical depth 8933.85-8927.9 feet 8901.35-8902.58 feet 8902.58-8905.18 feet 8920.49-8931.04 feet 8935.67-8938.48 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SUNNEDJAN 1 3 2015Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 32 512 6127 1900 200 Subsequent to operation: 910 18305 7588 1860 441 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory ❑ Development E Service ❑ Stratigraphic El Daily Report of Well Operations X 16.Well Status after work: Oil III Gas ❑ WDSP❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCI 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.CatronBP.Com Printed Name Garry Catron Title PDC PE Signature jjecPhone 564-4424 Date 1/6/2015 r ABC MS JAN .- '...5 Vit. i/g// J Form 10-404 Revised 10/2012 Submit Original Only • • H-29A 198-038-0 Junk Attachment SW Name MD Date Description H-29A 10835 7/1/2014 Milled CIBP H-29A 10835 12/11/2014 MILL CIBP • i Packers and SSV's Attachment ADL0028284 SW Name _ Type MD TVD Depscription H-29A PACKER 8518.86 8230.55 4-1/2" Baker S-3 Packer H-29A PACKER 8663.15 8354.4 4-1/2" Baker S-3 Packer H-29A PACKER 8726.88 8411.94 5-1/2" BAKER ZXP PACKER i • c. CD/CD 00oo • CO.O N- '— O O r- LO () Trcco � O ti N r U y 0 0 0 0 0 0 i f- M CO Tr co co 7 00 V CD N v v m O 00 Tr r- co 00 N CO • O N CO O CO 0 Nr M 4 ti 00 10 O_ co TY N N co O N O) CO M Tr co co N co 00 CI I I I I— () M 00 00 N 00 00CA O O Tr 00 O O O O N- co co N Tr N N N co 00 co GD ON LO Ln CO N O I - 00 V N LO CO N CO I— ` CO N CO O C.▪ ) p coi 4-1 00 Q co CD LO co O O V 00 Tr �N CO N M N N g3 = � o - 3 J F' 0 o000 • Q ocoO coo0 co co U J J J J J = 01 -p CSO N J 0 0 N C C � UC - N- U O N M N N • i r CD I M T t 4a CD LO 00 D)0 0) M co • 00 Tr co CO CO N- J CO N N O LL I Q' Q C:O U w w pcu_ ZZZ Z W w m m O ~ Z D D D D • 6 % / I Q . i 0 i 3 g E O ? Cl) \ co co ••? .6-.) / \ w \\ / ) p O �. // br f k oo C•4 / - o . % _ CO. 0- ( 60 � a \ > -c , > c & g ) \ ƒ - R © ® — \ 2 \0Ef // / G * p Gk / Gpo / / o / 3 b / / / - / \ % / / E ; U 2 ±'t # # 7 \ / \ \ TREE= 6"CtW FLS • H 29A S TBG*** WEILHEAO= McEVOY ,.. SA NOTES: WELL ANGLE>70° ` 9243'. ACTUATOR= BAKER 4-112 CHROME OKB B_EV= 73.9g I I BF.B-EV= 46.49' KOP= 5598' t , 2198' H4-1/2"NES X NP,D=3.813' Max Angie= 107°ft 10019' Datum MD= 9546' GAS LFT MAMXIB.S Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 113-3/8"CSG,72#,L-80,D=12.347" H 2676' 5 3059 3058 1 CAM MY RK 0 01129/13 4 4087 4087 1 CAM DONE RK ' 16 01/29/13 9-5/8"X 7"TACK SLV,D= H $350' 3 6080 6060 22 M AG-M DOME RK r 16 01/29/13 9-5/8'X 7"BKR ZXP PKR&HGR,D= ' H 8364' 2 7787 75951263 KBG2LS SOMY BK r 0 04/18/02 1 8438 8163 33 SO BK 22 01/29/13 Minimum ID =3.725" @ 8706' 4-1/2" HES XN NIPPLE 1 I $506' —{4-in"HES XMP,D=3.813" 9-5/8"WiPSTOCK(xx/xx/xx) H 8520' $ 851T N7"X 4-1/T BKR S-3 PKR D=3.675" 9-5/8"CSG,47#,L-80,D=8.681" H —8520 MLLOUT WINDOW(H-28A)8520'-8558' ' ' 8680' —j4-1/2"HES X NP,D=3.813' 4-1/2"TBG,12.6#,13CR..0152 bpf,D=3.958" H 8631' I--/ 1 I 8637' —19-5/8"X 4-1/2"UNIQUE OVERSHOT I I 8650' 1H4-1/2"IES X M,D=3.813" S 8661' —{r X 4-112"BKR S-3 PKR,D=3.875" I I( 8684` —I4-112"HES X NP,D=3.813" ' , 8706' 1--14-112 I-ES XN NP,D=3.725' TOP OF 4-1/2"LNR — $716` 8716' H 9-5/8"X 7"BKR TEBACK SLV,D= " 4-1/2"TBG,12.6#,L-80,.0152 bpf,D=3.958" —{ 8718' A8718' —14-1/2"W_EG,D=3.958" - --1—{H.MD TT NOT LOGGED 7"LNR,26#,L-80,.0383 bpf,ID=6.276" 8g0Q• \ , 8723' 7'X 5"BKR ZXP LTP&HGR,D= " PERFORATION SUMMARY y RB`LOG:SPERRY SUN MND GR ON 04/07/98 I ANGLE AT TOP PERF:107°CO 10012' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SI-UT SOZ 2-7/8" 6 10012-10032 O 07/03/14 2-7/8' 6 10300-10320 O 11/06/12 10835' —'FISH-CBP A .0 PUSHB)DH(12/11/14) 2-7/8" 6 10320-10350 0 09/01/13 10836' --I FISK COP HUED(7/1/14) 2-3/4" 4 10660-10800 0 04/11/98 .44 2-314" 4 10870-10940 C 04/11/98 10835'CTM H4-1r2'CBP(05/31/11) FBTD —j 10942' . 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.953" H 11048' ` DATE REV BY COMuENTS DATE REV BY COMVINTS PRUDHOEBAY UNIT 06/04/88 ORIGINAL COMPLETION 02/06/13 DJS/JM)GLV C/O(01/29/13) WB-L: F$-29A 04/12/98 SIDETRACK COMPLETION 09/12/13 LVJND ADPERFS(09/01/13) PBZMT No:'1980380 0418102 PHIKAK RWO 07/08/14 GIB/.101D MLUSEF CBRADPERF(7/3/14) API No: 50-029-21813-01 03/09/02 RN/TP CORRECTIONS 12/11/14 ATO/PJC MLLCBP&PUSH TO BTM SEC 21,T11 N,R13E,1005'FNL&1264'FE. 11/07/12 RMFYJMJ SETCIBP/ADPERFS(11/05-06/12) 11/12/12 .NuD URA 1 EU PERF BOX BP Exploration(Alaska) STATE OF ALASKA r ALC OIL AND GAS CONSERVATION COMMON • REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon u Repair Well a Plug Perforations Li Perforate U Other Li Mill CIBP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc ment Develo Exploratory❑ P lorato ry ❑ 198-038-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21813-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 PBU H-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: 17 ', Total Depth measured 11050 feet Plugs measured 10240, 10835 feet true vertical 8944.27 feet Junk measured 10835 feet AUG € 201 Effective Depth measured 10240 feet Packer measured See Attachment feet # , true vertical 8899.86 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 28-108 28-108 0 0 Surface 2648 13-3/8"72#L-80 28-2676 28-2675.63 4930 2670 Intermediate None None None None None None Production 8493 9-5/8"47#L-80 27-8520 27-8231.49 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10012-10032 feet 10300-10320 feet 10320-10350 feet 10660-10800 feet 10870-10940 feet True Vertical depth 8933.85-8927.9 feet 8901.35-8902.58 feet 8902.58-8905.18 feet 8920.49-8931.04 feet 8935.67-8938.48 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED OCT 2 0 2014, Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 769 29449 2403 0 1198 Subsequent to operation: 266 10764 904 0 192 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPLu GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUGO 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Nita Summerhays Email Nita.Summerhays ci bp.com Printed NamejiNitaSummerhh Title Petrotechnical Data Engineer Signa r- ;! 40, Phone 564-4035 Date 8/5/2014 �� RBCS AUG - 6 lou 5111114 Form 10-404 Revised 10/2012 it ,, `dy Submit Original Only • • Daily Report of Well Operations ADL0028284 .e pppp�/ %, SUMMAR.( 10, ' w v= Objective: Mill CIBP&Set higher CiBP,Add Perls ` Rig up in progress ' , fr 6/30/2014 ***Continued on WSR 07-01-14*** ***Continued from 06-30-14*** CTU#3 w/ 1.75" CT(CTV=33.3) Objective: Mill CIBP's & Set higher CIBP,Add Perfs. MIRU from H-28. Liquid pack wellbore w/SafeLube. RIH w/burnover shoe assy w/ Venturri to top CIBP found at 10629' CTM. Milled slips and pushed to 10836' CTM which is the top of the second CIBP. POH. Recovered numerous pieces of slips, rings and other material from CIBP in Venturri. Recovered a 2" long steel ring from the top of the CIBP in the burnover shoe. RBIH w/new burnover shoe assy, saw minimal mill work. Milled for 3 hours. 7/1/2014 ***Continued on WSR 07-02-14*** •***Continued from 06-30-14*** �� CTU#3 w/ 1.75"CT(CTV=32.7) '� Objective: Mill CIBP's&Set higher CIBP,Add Perfs. MU new burnover shoe Ran in hole to 10846' Saw minimal mill work, milled for 3 hours, no stalls, no movement, POOH. Saw 4k over pull coming through top perfs (fluid going into perfs). On surface,tattle tail in burn shoe are bent upward, no indication of milling work on the opti cut carbide chips. Called town engineer, decision made to continue on with the other steps. Ran PDS GR/CCL in a 2 3/8"carrier. Logged 10500-8300'. POH w/no data. Rehead due to chrome(3 run limit)and cut 100'of CT. Rerun PDS GR/CCL and logged 10500-8300'. POH. RIH wI BTT 4-1/2" CIBP and set w/top at 10240'. POH 7/2/2014 In progress ***Continued from WSR 07-02-14*** CTU#3 w/1.75"CT(CTV=32.7) Objective: Mill CIBP's &Ste higher CIBP,Add Perfs. Ran 20'x 2.80" Perf gun (2906 PJ HMX). Sat down on CIBP @ 10253' picked up and got weight back @ 10249', Corrected to 10239.4' Pulled up into position. At depth, top shot= 10012', Bottom shot= 10032'. Launch ball, positive indication guns fired. Freeze protect while pulling out of the hole. Out of hole, all shots fired. Ball recovered. 7/3/2014 ***Job Complete*** FLUIDS PUMPED BBLS 46 50/50 METH 697 SLICK KCL 510 KCL W/SAFELUBE 1253 TOTAL • • 0' O O O O O O O QO CO I" r O O !a LC) N- (O ' O tO C LO N N L() I— N- C.) 17; Oo Ooo0O I- co co V co co 3 N V O 6) N *Cr �Y CO ti CO O I,- CO CO I� N CO N O) CO A— CO N I� CO O O d7 CO CO CO O co O N Cr) M O I- co N CO O M co co O co O) N N co cr) co N CO CO CO O CO CO CO CO CO N CO CO f� O) O) O co O CO O O L[) CO ci 0 0 A- CO a) NC NCO Cr) N N CO CO CO CO CO CO CO CO CO CO 0 CO • 03) O 0 I- r LO O CO V co O O O co in co O N O) CO CO I� LO CO CO CO I- _ O CO CO CO CO CO CO N CO CO V cagitai i i I . 00 2 art N CO COCCOOOoCLUCO0 ONOv C) (V NcococococoCO00 MCO � Q 0 J I— Q O a) O O co a) a) a) a) O co CO CO LSI ° O J fl Q C1 Q Q 00 o COJ O J J Q _Q _Q o Z J (O It * d -a J O Z Z Z Z *k N J CO CO N oco � XXXXXv � C � U C'.4 ivOZON = N O I- r r r = — IC) CI N. N , V CA co 7 a d co co co C CO M M r CO O CO CO J O N CO N CO Z O CD wwwwwDUC7OCD ClS 0 C[ C' J J J J J Z Z Z UZZaa d � cLOWE 007 OZ D D D U J J Z Z Z Z Z a CO I— H • • Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H-29A PACKER 8364 8028.04 7" Baker ZXP Packer H-29A PACKER 8517 8156.64 4-1/2" Baker S-3 Packer H-29A PACKER 8661 8280.1 4-1/2" Baker S-3 Packer H-29A PACKER 8723 8336.05 4-1/2" Baker ZXP Packer 1 REE= , 6'CIW R.S • WELLI-EAD= McEVOY _29A SA NOTES: WELL ANGLE>70°@ 9243'. .._ 41/2-CHROMETBG A,rTUATOR= BAK62C' "*"4-1/2- ,• OKB.ELEV= 73.99'' BF.ELEV= 46A9 KOP= 5598" Max Angle= 107'@ 10019' Datum MD= 9546�,!I 2198' --14-1/2' PD HES X N , =3.813" Datum ND 8800' 13-3/8"CSG, 72#,L-80,D= 12.347" — 2676' GAS LFT MANCRRS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3059 3058 1 CAM DMY RK ' 0 01/29/13 4 4087 4087 1 CAM DOME RK ' 16 01/29/13 3 6080 6060 22 CAM MMGM DOME RK r 16 01/29/13 2 7787 7595 26 GAM MMGM DMY RK r 0 04/18/02 1 8438 8163 33 CAM KBG2LS SO BK r 22 01/29/13 8350' —TEBAO<SLV TOP OF 7"LNR — 8364' 9-5/8"X 7'BKR ZXP LNR/HGR PKR w/T€BI. 8506' 41/2'HES X NP,D=3.813" 4 851r 7"X 4-1/2'BKR S-3 PKR,D=3.875' 4-1/2'TBG, 12.6#,13 CR.0152 bpf,D=3.958" J— 8631' 8580' —4-1/2"FES X NP,D=3.813' I —� 863T —UNIQUE OVERSHOT I 8650' —4-12"HES X NP,D=3.813" Minimum ID = 3.725" @ 8706' Z Z , 8661' —7"X 4-1/2'BKR S-3 PKR,D=3.875" 14-1/2" HES XN NIPPLE I I 8684' —4-12"I-ES X NP,D=3 813" I I 8706' H -1/2"I IES XN NP,D=3 725' 8716' —TIEBACK SLV 1 4-12"TBG, 12.6#,L-80,.0152 bpf,D=3.958" -1 8718' / \ 8718' —4-12"WLEG,D=3.958' [ —E..10 TT NOT LOGGBD PERFORATION SIJMIAARY REF LOG:SPERRY SUN MWD GR ON 04/07/98 8723' —7"X 5'BKR ZXP LNR TOP PKR , ANGLE AT TCW FEW 107°@ 10012' Note:Refer to Production DB for historical pert data 8730' —17"X 5'BKR HMC LNR FiGR SIZE SPF INTERVAL Opn/Sqz I SHOT SOZ 2-7/8" 6 10012-10032 0 07/03/14 MLLOUT WIDOW 8520'-8558' 2-7/8' 6 10300-10320 C 11/06/12 2-7/8' 6 10320-10350 C 09/01/13 2-3/4" 4 10660- 10800 C 04/11/98 2-3/4" 4 10870.- 10940 C 04/11/98 -_. __ 10244 0' —412"WFD C8P(07/02114) rr Nk 1•=;.35' —FISH:CEP MLLBD(7/1/14) TOP OF WHPSTOCK — 8560' * ilip 10835' 4112"CEP(05/31/11) TOP OF OLD 7'LNR — _ a645' pro ,0942. 1 9-5/8"CSG,47#,L-80,D=8.681" H 8889' 4111p+- .14% TOP OF CEMENT — 9036' ``` 4444644 -.7 7'LN ,26#,L-80, 0383 bpf,D=6.276"J— 8900' 4-1/2"LP, 12.6#,L-80, 11048' i 0152 bpf,D=3.953" DATE REV BY COM RENTS DATE REV BY O PJETYTS PRUOFDE BAY LNf 06/04/88, ORIGINAL COMPLETION 02/06/13DJS/JMD,GLV 00(01/29/13) _ WL I-I-29A 04/12/98 _SIDETRACK COMPLETION 09/12/13 LVJM D ADM/FS(09/01/13) PERK No: 1980380 04118/02 PWKAK RWO 07/08/14 GJB/JMD MILL/SET C38RADPERF(7/3/14) AFI No. 50-029-21813-01 03/09/02 RWfP CORRECTIONS TIONS SERs 21,T11 N,R13E, 1005'FNL 8 1264'FEL 11/07/12 RMWJMD SET C ERADPERFS(11/05-06/12) 11/12/121 JMD UPCJATED FERF BOX - - BP Exploration(Alaska) i RRecisiveD STATE OF AIL OIL AND GAS CON ER AKTION COMMI. ON REPORT OF SUNDRY WELL OPERATIONS SEFSER1 5 20I3 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U . Other U ;{_( (ea: * Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time ExtensionExtension"' ��- Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development• Exploratory ❑ 198-038-0 • 3.Address: P.O.Box 196612 Stratigraphic Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21813-01-00 . 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028284 • PBU H-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL ' 11.Present Well Condition Summary: Total Depth measured 11050 - feet Plugs measured See Attachment feet true vertical 8944.27 • feet Junk measured None feet Effective Depth measured 10615 feet Packer measured See Attachment feet true vertical 8918.69 feet true vertical See Attachment feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 80 20"Conductor . 28-108 28-108 Surface 2648 13-3/8"72#L-80 28-2676 28-2675.63 4930 2670 Intermediate None None None None None None Production 8493 9-5/8"47#L-80 27-8520 27-8231.49 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10300-10320 feet 10320-10350 feet 10660-10800 feet 10870-10940 feet True Vertical depth 8901.35-8902.58 feet 8902.58-8905.18 feet 8920.49-8931.04 feet 8935.67-8938.48 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED N O r./ . 1 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 256 2342 • 501 • 0 1108 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorE Development Q Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil U Gas U WDSPLJ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.CatronCa)_BP.Com Printed Name Garry Catron Title PDC PE Signature 79-1 04^1-- G(t_' Phone 564-4424 Date 9/24/2013 rY! 1,7t/ r RBFAMS OCT liar 41 10//t07/ RIGINAL �,�� Form 10-404 Revised 10/2012 Submit Original Only . • • H-29A 198-038-0 Plugs Attachement SW Name Date MD Description H-29A 11/6/2012 10615 4-1/2"WFD CIBP H-29A 6/1/2011 10835 4-1/2" CIBP Packers and SSV's Attachment ADL0028284 SW Name Type MD _ TVD Depscription H-29A PACKER 8364 8028.04 7" Baker ZXP Packer H-29A PACKER 8517 8156.64 4-1/2" Baker S-3 Packer H-29A PACKER 8661 8280.1 4-1/2" Baker S-3 Packer H-29A PACKER 8723 8336.05 4-1/2" Baker ZXP Packer r • Q 0 0 0 0ffs 0 0 0 vLUN- (ov (0 �n U 0 0 0 0 0 0 0 co r- co co co N co O) N V �t CO N- CO CO V I- CO CO N- O) co co N V CO CO CO p O (h a 6 co M M O 00 O) N CO CO CO CO N CO CO H r � � �i O 10 00 O N f— 00 N O �j N O O N N N CO co CO CO CO OO N O CO co O 00 CO N CO CO V 4.0 • CO N CN CO CO C(OO O N- CO N O N N CO CO N N N CO CO C O C � J - Q o O 0 0 0 CO COU OJ J O J J U 00 J CO 4:k 47k d J co N J CO CO • 'p N N. *k N CU 0 U NO0 N U _ _ o _ - O r- N M N N N ' (h 15 co co co C)O O CO O) ' (O C Cb Cr) CO CO (O N- G) In N CO N CO J Z O w N D D V 0 0 0 coo a p LL Z Z Z V Z W W O C m m m O Z Z EtD D D j 0 J J (n H • Daily Report of Well Operations ADL0028284 CTU#9 1.75" Coil. Job Objective: Drift,Adperfs 8/30/2013 ***Job Continued on 8/31/2013*** CTU#9 1.75" Coil. Job Objective: Drift,Adperf Performed weekly BOP test. RIH w/ PDS GR/CCL logging tools and carrier w/3.2" NZ tag WFD plug and log up to 8300'. 8/31/2013 ***Job Continued From 8/30/13*** CTU#9 1.75" Coil. Job Objective: Drift,Adperf Perforated 10320'-10350'with2 7/8"2906 PJ HMX 6 spf, correlated to Sperry MWD 4/7/1998. Fired guns top shot 10320' bottom shot 10350'. Confirmed guns fired & recovered 1/2" ball. ( RDMO ) 9/1/2013 ***Job Complete*** TREE_"' 6"CNV FLS • v WELLHEAD= Mc EVOY El SA NOTES: W ELL ANGLE>70°@ 9243'. ACTUATOR BAKER C __.. �� I **•4-1/2"CHROME TBG*** . OKB.ELEV= 73.99' BF.ELEV= 46.49' KOP= 5598' Max Angle= 1070 @ 10019'' 2198' -14-1J2"FES X NP,D=3.813" Datum MD= 9546'''. Datum TVD= 8800'SS'' 13-3/8°CSG,72#,L-80,13=12.347" --I 2676' 11 GAS LFT MASS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 5 3059 3058 1 CAM DMY FE O 01/29113 4 4087 4087 1 CAM DOME RK r 16 01/29/13 3 6080 6060 22 CAM MMG-M DO14E RK ' 16 01/29/13 2 7787 7595 26 CAM MMG-M DMY RIC r 0 04/18/02 1 8438 8163 33 CAM KBG2LS SO BK r 22 01/29/13 $350• TACK SLV TOP OF 7"Lhfi H 8364• k-1 8364' H 9-5/8"X 7"BKR ZXP LNR/HGR FKR w/TISK 8606' -4-112"IESXNP,13=3.813- 8517' _7"X4-1/2"BKR S-3 PKR,D=3.85" 7 .4 4-1/2"TBG,12.6#,13-CR,.0152 bpf,D=3.958' H 8631' 85$0' H4-1/2"FES X NP,D=3.813' -�— 8637' H UNIQUE OVERSHOT I I 8650' H4-1/2"HES X NP,D=3.813" Minimum ID = 3.725" @ 8706' z E 8661' H7"x 4-112-BKR S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE I I 8684' H4-1/2"HE'S X NP,D=3.813" I I 8706' H4-1/2"FES XN N P,D=3.725' 8716' HTE BACK SLV 4-1/2'TBG,12.6#,L-80,.0152 bpf,D=3.958" -I 8718' / 8718' -14-1/2"WLEG,D=3.958" '� -\ ELMD TT NOT LOGGED PERFORATION SUMMARY REF LOG:SPERRY SUN IMOD GR ON 04/07/98 8723" H 7"X 5'BKR ZXP LNR TOP PKR ANGLE AT TOP PERF:870©10300' 8730' --17"X 5"BKR I4AC LNR HGR Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn!Sgz SHOT SQZ 2-7/8" 6 10300-10320 0 11/06/12 M-LOUT VVI DOW 8520'-8558' 2-7/8" 6 10320-10350 0 09/01/13 2-3/4" 4 10660-10800 C 04/11/98 2-3/4" 4 10870-10940 C 04/11/98 10615 --14-1/2"WFDCBP(11/05/12) 10835' -I4-1/2"CBP(05/31/11) TOP OF NA STOCK -i 8560' /` PBTD H 10942' TOP OF OLD 7"LNR - 4 I 8645' i ..s. 9-5/8"CSG,47#,L-80,D=8.681" -I 8889' W.t • T H kTOP OF CEMEN9035' 111111♦ V 111111111111111 .1...1.x. 7"LW,26#,L-80,.0383 bpf,D=6.276" H 8900' 41/2"LNR,12.6#,L-80, - 11048' .0152 bpf,D=3.953" DATE REV BY COPA&NTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 06/04/88 ORIGINAL COMPLETION 11/07/12 RMFVJMD SET CBRADFERFS(11/05-06/12) WELL: H-29A 04/12/98 SIDETRACK COMPLETION 11/12/12 AID UPDATED PERF BOX PERIM No:'1980380 04/18/02 PHIKAK RWO 02/06/13 DJS/JM) GLV G0(01/29/13) AR No: 50-029-21813-01 03/09/02 Rr1TP CORRECTIONS 09/12/13 LVJMD ADFERFS(09/01/13) SEC 21,T11N,R13E,1005'FNL&1264'FEL 07/15/03 C2MO/TLP KB ELEVATION CORRECTION 04/28/11 PJFVPJC FEW REF LOG CX)RRECTIONBP Exploration(Alaska) RECE1VEU STATE OF ALASKA .. ANOKA OIL AND GAS CONSERVATION COMMON NOV 2 9 2012 ` REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 198-038-0 3.Address: P.O.Box 196612 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99519-6612 – 50-029-21813-01-00 7.Property Designation(Lease Number): — 8.Well Name and Number: „ ADL0028284 PBU H-29A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): To Be Submitted PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 11050 feet Plugs measured See Attachment feet true vertical 8944.27 feet Junk measured None feet Effective Depth measured 10615 feet Packer measured See Attachment feet true vertical 8918.69 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 28-108 28-108 0 0 Surface 2648 13-3/8"72#L-80 28-2676 28-2675.63 4930 2670 Intermediate None None None None None None Production 5493 9-5/8"47#L-80 27-8520 27-8231.49 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 10300-10320 feet 10660-10800 feet 10870-10940 feet True Vertical depth 8901.35-8902.58 feet 8920.49-8931.04 feet 8935.67-8938.48 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): ED MAR 11 2°13' Treatment descriptions including volumes used and final pressure: SCpHN 13. RepresentativelDaily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 662 28129 723 0 1561 Subsequent to operation: 946 5164 2307 0 172 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratorf Development ," Service❑ Stratigraphic 0 Daily Report of Well Operations X 16.Well Status after work: Oil _ ❑✓ Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catrorl(a.BP.Com Printed Name Garry Catron Title PDC PE Signature ,l" c2/, _ Phone 564-4424 Date 11/29/2012 efej:42 1.'01':. r.Vil NO V 3 0 ii]li 7% /2 1g/2-- Form YiLForm 10-404 Revised 10/2012 /' �y � Submit Original Only • • H-29A 198-038-0 Plugs Attachement SW Name Date MD Description H-29A 11/6/2012 10615 4-1/2"WFD CIBP H-29A 6/1/2011 10835 4-1/2" CIBP • • Packers and SSV's Attachment ADL0028284 SW Name Type MD TVD Depscription H-29A PACKER 8364 8028.04 7" Baker ZXP Packer H-29A PACKER 8517 8156.64 4-1/2" Baker S-3 Packer H-29A PACKER 8661 8280.1 4-1/2" Baker S-3 Packer H-29A PACKER 8723 8336.05 4-1/2" Baker ZXP Packer • • CD CA, 0 0 0 0 0 0 0 • - OnOc� - Oo 1 N CC) N- U N▪ 0 0 0 0 0 0 0 CO C` CO V CO CO • N d- CO O N V �7 CO C` co CO 00 00 N- C3) co r 00 N V CO CO CO p V tri O M 4 c7 1-- co co O • CT N co M 0o co N CO 00 Ci I 1 H ✓• O If) 00 p N 0o N O CCj N p p N N N C7 Ch N- CO 4-+ 00 CO CO C co 00 O O 00 = O c) O LO CO CO CO N- O CO N CO CO V • W r 1 I I I I I 1 I N CO CO CSO N- N- CO N O V N N CO r-N N N co co C pCO ▪ 0 ill � J ~ Q o p o 0 a} J 0 Q I 00 I J J U COfp J CO • N -6 J CO N J CO CO N 0 co � ItN N VNUN - ao °X° N - - N 1 (I 1 v v t +r �t co co v D)cjc a) v r- o C CO Ch CO 4 CO Cb (fl N- o C1) N co N co J Z O �� w � occowzzz ✓ z w w O CC m m m O z Z c J D D D UJJdU) F- HI- • • 3 / �\ 01 »o � » I 7:13 -02z \ § >T- -co c \ % ( � % § � �\ � I I Get ,,- f \ f / < k\ 0 \ . D- an = n ± - o 0 t 0/ I . ¥ = e : - a 2 e < z z \ a R % § / \ § / b • & a \ v- O / / k/ / O a -) a / § $ § _ , � = = gw6 C▪IS to� �CO / � 0_ ® 2 / CD / 2 ; IL _ N 4- 727 < 2 < km — < y % q 7i £ $ c ° 73 C % 6 / \ 0_ 0 I - _ = n@ m - co 2 \ E 0 _j i / \ •/t i ./ % / 01-- o < \ E D 0 » \ \ % O \ O « \ : I \ o 1 «2. ) O = / G $ ) O = / � s « 0 CO w \ � 7 CO / wCO \ 0 \ § a CC k E I < k b 0.-LI / ® £ $ » - 0 2 2 ƒ ƒ 0 % o / i & / E \ % ▪as CI / 2 Lor § / 2 c(h) 2 \ \ \ \ \ k \ Lr) C / k } i ) \ $ 2 5 « = 2 2 / a ® E E m Cl) \ / k \ \ ± / / / m ƒe » 0 c \ co /aC C e. g F- 2 , - ./ .2 F- 2) 0 O / c\ UIo ± « o ± OCoOO : ae 2 % 2 r \ \ / \ / / / $ •ice 6"aWF1_S • WEt.LFEAD= McEVOY lk NOTES: WELL ANGLE>70°t 9243'. ACTUATOR_ BAKER C ��v SAFE***4-1/2"CHROME TBG*** iB.F3EV= 72.4' BE ELEV= 46.49' KOP= 5598' Max Angle= 6- —107°_ 10019' Datum M =D — —9546' I I 2198' ---14-1/2"FES X NP,D=3.813" Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H 2676' A GAS LET MANDRELS ST M) TVD DEV TYPE VLV LATCH PORT DATE L 5 3059 3058 1 4 4087 4087 1 CAM DOME RK r 16 10/27112 CAM DOME RIC ' 16 10/27/12 3 6080 6060 22 CAM MMG-M DMY RK r 0 04/18/02 2 7787 7595 26 CAM MMG-M DMY RIC ' 0 04/18/02 1 8438 8163 33 CAM KBG2LS DMY BK-5 ' 0 04/18/02 8350' TACK SLV T1_21,2_7"OF LNR H 8364' 1 8364' —1-19-5/8"X 7"BKR ZXP LNR/HGR PKR w/TRK 4 _ 8506' —4-112"HES X NP,D=3.813" 8517' —7"X 4-1/2"BKR S-3 PKR,D=3.875" I 4-112"TBG,12.6#,13-CR, H .0152 bpf,D=3.958" — 8631' I ( "1 8580' —14-1/2"F-ES X NP,D=3,813" 8637' H UNIOL E OVERSHOT I I 8650' —4-1/2"FES X NP,II)=3.813" Minimum ID = 3.725" @ 8706' Z g, 8661' H7"X 4-112"BKR S-3 PKR,D=3.875" 4-1/2" HES XN NIPPLE I I �7-1-14-1/2"IES X NP,D=3.813' I I 8706' —{4-112"FDS XN MP,D=3.725" 8716' —HTE BACK SLV 4-1/2"TBG,12.6#,L-80,.0152 bpf,0=3.958" —I 8718' Li 8718' I-4-1/2"WLEG,D=3.958" —{ELM)TT NOT LOGGED PERFORATION SUMMARY Fill MV LOG:SPERRY SUN V)GR ON 04/07/98 8723' —1 7"X 5"BKR ZXP LNR TOP PKR ANGLE AT TOP PERF:87°@ 10300' 8730' --17"X 5"BKR HMC LNR HGR Note:Refer to Production DB for historical perf data SIZE SPF NTHR'VAL Opn/Sqz SEDT SOZ MLLOtJT 1MDOW 8520 -8558' 2-7/8" 6 10300-10320 0 11/06/12 2-3/4" 4 10660-10800 C 04/11/98 2-3/4" 4 10870-10940 C 04/11/98 10615' H4-112"WFDCEP(11/05/12)� TOP OF W-*STOCK H 8550' "` 10835' H4-112"CEP(05/31/11) �(. PST!) - 10942' TOP OF OLD 7"LNR }— 8645 f O'li.9-51$"CSG,47#,L-80,D=8.681" H 8889' `;� TOP of CEMENT' --I 9035' 1/4 1111111 ` 111111111111111 7"LHR,26#,L-80,.0383 bpf,D=6.276" H 8900' 4-1/2"LHR,12.6#,L-80, — 11048' .0152 bpf,D=3.953" DATE REV BY 0014,4ENTS DATE REV BY COMMENTS FRl DHOE BAY UNIT 06/04/88 ORIGINAL COMPLETION 04/28/11 PJFYPJC PERF REF LOG CORRECTION WELL H-29A 04/12/98 SIDETRACK COM PLETION 06/01/11 RLM'PJC SET CEP(05/31/11) PERAKNo.'1980380 04/18/02 PWKAK (MO 10/30/12 CDJ/JMD GLV CIO(10/27/12) AR No: 50-029-21813-01 03/09/02 RWTP CORRECTIONS 11/07/12 RM-VJMD SET CBP/ADPERFS(11/05-06/12) SEC 21,T11N,R13E,1005'FNL&1264'FT_ 07/15/03 CM)/TLP KB FiEVAT1ON CORRECTION 11/12/12 AO UPDATH)FERE BOX 04/09/09 TO/SV GLV CORRECTION BP Exploration(Alaska) S bp BP Exploration (Alaska) Inc. Attn:Well Integrity Coordinator, PRB-20 Post Office Box 196612 O Anchorage, Alaska 99519-6612 May 18, 2012 Mr. Jim Regg Alaska Oil and Gas Conservation Commission SLANNED AUG 0 8 LUII 333 West 7t" Avenue C� Anchorage, Alaska 99501 -- 0 V Subject: Corrosion Inhibitor Treatments of GPB H-Pad rl Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Date: 03/17/2012 Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# API# cement pumped cement date inhibitor sealant date ft bbls ft na gal H-01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H-02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H-03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H-04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H-05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H-06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H-07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H-08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H-09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H-10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H-11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H-12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H-13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H-14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18/2010 H-15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H-16 2000650 50029205920200 0 NA NA NA NA NA H-17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H-18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 1-1-196 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H-20 1830070 50029208960000 6,7 NA 6.7 NA 47.60 2/22/2010 H-21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H-22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H-23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H-24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H-25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 H-26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 H-27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 •'~44p H-29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H-30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H-31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H-32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 1-1-33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 H-34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 H-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H-36A 2000250 50029226050100 1.3 NA 1.3 NA 11.90 2/17/2010 H-37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 H-38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 • • 0) 0 N- N cc o E E O O 0 U d CD C C 7 o CO U R N ON) 0 a) 2ma) cQY to o Y ( 7 Q m (21• - .0g6 c 2 M Q ) CV • LCV• 15- 03 ° .Cyi 0 C] (n o a) -Id L U 0 0 CI C fAQQMQ 0.5 W Cd 6 a cC Oo m m CI N 0 CO E U r ca N0 C Z U Q c`\i J M s.: 0 '- ff. 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Operations performed: 0 Operation Shutdown 0 Stimulate 0 Plugging 0 Perforate Pull Tubing 0 Alter Casing ® Repair Well 0 Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ® Development KBE=72.37' 3. Address El Exploratory 7. Unit or Property Name ❑Stratigraphic Prudhoe Bay Unit P.O. Box 196612,Anchorage, Alaska 99519-6612 0 Service 4. Location of well at surface 8. Well Number 1006'SNL, 1265'WEL, SEC. 21,T11N, R13E, UM H-29A At top of productive interval 9. Permit Number/ Approval No. 78' NSL, 1501'WEL, SEC. 16,T11N, R13E, UM 198-038 10. API Number At effective depth 50-029-21813-01 916' NSL, 617'WEL, SEC. 16,T11N, R13E, UM 11. Field and Pool At total depth Prudhoe Bay Field/Prudhoe Bay 1002' NSL, 598'WEL, SEC. 16, T11N, R13E, UM Pool 12. Present well condition summary Total depth: measured 11050 feet Plugs(measured) true vertical 8944 feet Effective depth: measured 10960 feet Junk(measured) true vertical 8940 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds concrete 110' 110' Surface 2648' 13-3/8" 3723 cu ft Arctic Set II & III 2676' 2676' Intermediate 9-5/8" 1970 cu ft Class'G' 8520' 8231' Production Liner 536' 7" 130 cu ft Class'G' 8364'-8900' 8100'-8564' Liner 2334' 4-1/2" 297 cu ft Class'G' 8716'- 11050' 8402'-8944' Perforation depth: measured 10660'- 10800', 10870'- 10940' true vertical 8921'-8931', 8936'-8939' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, 13Cr to 8644'; 4-1/2", 12.6#, L-80 to 8716' Packers and SSSV(type and measured depth) 7"x 4-1/2"Baker'ZXP'Liner top packer at 8723'; 7"x 4-1/2"Baker'S-3'packer at 8661'; 7"x 4-1/2"Baker 5-3'packer at 8517; 9-5/8"x 7"Baker'ZXP'liner/hanger packer at 8364'; 4-1/2"HES'X'Nipple at 2198' 13. Stimulation or cement squeeze summary Intervals treated (measured) M,'','' o 9 2002 Treatment description including volumes used and final pressure Alaska Oil&Gas Coos.U0r(lf(&slur, Anchorage 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 1458 26994 168 Subsequent to operation: 1294 14555 526 15.Attachments 16. Status of well classifications as: 0 Copies of Logs and Surveys run ®Oil ❑Gas 0 Suspended Service ®Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble •• � (,( Title Technical Assistant Date OS-00-0 1 Prepared By Name/Number: Terrie Hubble,564-4628 Form 10-404 Rev. 06/15/88 R 4 @ Submit In Duplicate • Well: H-29A, RWO Rig Accept: 04/10/02 Field: Prudhoe Bay Unit Rig Release: 04/15/02 API: 50-029-21813-01 Permit: 198-038 Drilling Rig: Doyon 16 PRE-RIG WORK 03/03/02 MITOA TO 1000 PSI PASSED. PPPOT-IC FAILED.TBG& IC LDS FUNCTION OK. 03/11/02 DUMPED 3.5" X 11' BAILER OF CACO3 ON TOP OF TAIL PLUG @ 8698'WLM. 03/12/02 DUMPED TOTAL OF 100#OF CACO3. ON TOP OF TT PLUG. DRIFTED W/3.625 X 10' DUMMY CHEMICAL CUTTER TO 8571'WLM. UNABLE TO PASS. NO PROBLEMS W/3.625" CENTRALIZER. DRIFT TBG W/3'X 3.625" STEM. PASSED THRU RESTRICTION @ 8571'SLM. NO PROBLEM. SID@ 8681'SLM. RDMO. RIH W/STRING SHOT TO CLEAR SCALE FOR CHEMICAL CUTTER. TIE INTO TUBING TALLY AND SHOOT 8 FT STRING SHOT CENTERED OVER DESIRED CUTTING DEPTH OF 8644'. INTERVAL OF STRING SHOT 8640'-8648'. SMALL INDICATION AT SURFACE. RIH W/CHEMICAL CUTTER. LEFT SAFETY BLEED SCREW OPEN AND PARTIALLY FLOODED CUTTER DURING PRESSURE TESTING. DECISION MADE TO R/D. PAD OPER NOTIFIED OF STATUS- LEAVE WELL SHUT IN. 03/14/02 ATTEMPTED TO CHEM CUT TBG @ 8640 W/3 5/8 CUTTER. CUTTER MALFUNCTIONED RESULTING IN FAILED RUN.JOB WAS ABORTED,WILL RETURN @ A LATER DATE. LEAVE WELL SI FOR UPCOMING RIG WORK. 03/16/02 CHEM CUT 4.5"TBG @ 8642'. 03/24/02 CIRC-OUT WELL WITH 850 BBLS OF WATER AND 170 BBLS OF DIESEL.PASSED MIT TXIA COMBO TO 3000 PSI. • • qi u NiIJi BP EXPLORATION Page 1 of 2 a � q 4.1016t , 4.41j' operations Summary Re ort Legal Well Name: H-29A Common Well Name: H-29A Spud Date: 5/22/1988 Event Name: WORKOVER Start: 4/3/2002 End: Contractor Name: DOYON Rig Release: 4/15/2002 Rig Name: DOYON 16 Rig Number: 16 Date From -To Hours Activity Code NPT Phase Description of Operations 4/10/2002 00:00-01:30 1.50 MOB P PRE PJSM.MOVE RIG OFF WELL. LAY OVER DERRICK. 01:30-02:00 0.50 MOB P PRE CONDUCT PRE MOVE SAFETY MEETING WITH ALL ASSOCIATED PARTIES. DISCUSS ROUTE OF TRAVEL& POTENTIAL HAZARDS. 02:00-19:30 17.50 MOB P PRE MOVE RIG F/DS 03 TO H PAD. 19:30-23:00 3.50 MOB P PRE RAISE DERRICK. R/U BALES, ELEVATORS. SPOT RIG OVER WELL&LEVEL UP. SPOT CUTTINGS TANK. RIG ACCEPTED @ 23:00 HRS,04-10-02. 23:00-00:00 1.00 MOB P PRE CONDUCT DERRICK INSPECTION FOR POTENTIAL FALLING OBJECTS. 4/11/2002 00:00-02:00 2.00 KILL P DECOMP PJSM. PULL BPV. HAMMER UP SECONDARY VALVE ON ANNULUS. 02:00-05:00 3.00 KILL P DECOMP RIG UP MANIFOLD,TEST LINES&CIRCULATE DOWN ANNULUS,TAKING DIESEL RETURNS FROM TUBING TO OUTSIDE TANK. (NO GAS).AFTER CLEAN RETURNS, TURN IT AROUND&CIRC DOWN TUBING,TAKING DIESEL RETURNS UP ANNULUS&OUTSIDE. SHUT DOWN& MONITOR. 05:00-06:00 1.00 KILL P DECOMP SLIGHT FLOW UP ANNULUS W/OIL IN RETURNS. CIRCULATE(50)BBLS DOWN TUBING TO CLEAN UP BACKSIDE. 06:00-07:00 1.00 KILL P DECOMP MONITOR WELL, SLIGHT TRICKLE UP BACKSIDE, NO OIL. 07:00-08:30 1.50 KILL P DECOMP COMPLETE BOTTOMS UP, MONITOR,WELL STABLE. 08:30-09:30 1.00 BOPSUR P DECOMP BLOW DOWN LINES,SET TWO WAY CHECK VALVE. 09:30-12:00 2.50 BOPSUR P DECOMP N/D TREE&ADAPTER FLANGE. CHECK THREADS IN TUBING HANGER,GOOD SHAPE. 12:00-18:00 6.00 BOPSURP DECOMP N/U 13 5/8"X 5M BOPE. FUNCTION TEST, OK. 18:00-21:30 3.50 BOPSURP DECOMP CONDUCT FULL TEST ON ALL BOPE COMPONENTS. WITNESSING OF TEST WAIVED BY WINTON AUBERT. 24 HOUR NOTICE GIVEN TO JEFF JONES ON 4-10 @ 05:00 HRS. NO FAILURES. DRAWDOWN TEST ON ACCUMULATOR,OK. 21:30-22:30 1.00 BOPSURP DECOMP RIG UP&PULL TWO WAY CHECK VLV. 22:30-00:00 1.50 PULL P DECOMP PJSM. ESTABLISH PARAMETERS.SCREW INTO TUBING HANGER&PULL TO 111K, HANGER FREE, 111K UP WT, & PULLED THRU ROTARY TABLE, NO HANGUPS. BREAK OUT HANGER&LAY DOWN, R/U TO CIRC DOWN TUBING. 4/12/2002 00:00-01:30 1.50 PULL P DECOMP CIRCULATE WELL,650 BBLS @ 7.5 BPM/650 PSI SPP, & RIG UP CAMCO SPOOLING UNIT.WELL STABLE. 01:30-04:30 3.00 PULL P DECOMP POOH W/4 1/2"IBT TUBING&C-LINES. UD SSSV.(55) C-LINE BANDS RECOVERED. 04:30-13:00 8.50 PULL P DECOMP CONTINUE TO POOH&UD 4 1/2"IBT COMP STRING.205 JTS+ 12.5'OF#206.CUT LOOKS CLEAN. 13:00-14:00 1.00 PULL P DECOMP RUN TP,TEST LOWER PIPE RAMS @ 250/3500 PSI,OK. SET WEAR BUSHING. 14:00-19:00 5.00 REST P DECOMP P/U&M/U(6)4 3/4"DCs, RTTS&RIH TO 96'.SET RTTS& PRESSURE TEST I/A ABOVE RTTS TO WELLHEAD @ 3000 PSI/30 MINUTES, CHARTED,OK. L/D RTTS&DCs. 19:00-20:00 1.00 REST P DECOMP M/U CLEANOUT/DRESS OFF BHA. 20:00-00:00 4.00 REST P DECOMP P/U&RIH W/3 1/2"DP&CLEANOUT BHA. 4/13/2002 00:00-04:00 4.00 REST P DECOMP PJSM.CONTINUE TO P/U 3 1/2"DP F/4989'-8615'. KELLY UP,TIGHTEN CONNECTIONS&M/U KELY HOSE. 04:00-04:30 0.50 REST P DECOMP ESTABLISH PARAMETERS: 137K UP WT, 130K DN WT, & Printed 4/22/2002 11 50 03 AM • q11 ` BP EXPLORATION Page 2 of 2 --rations Summary Report Legal Well Name: H-29A Common Well Name: H-29A Spud Date: 5/22/1988 Event Name: WORKOVER Start: 4/3/2002 End: Contractor Name: DOYON Rig Release: 4/15/2002 Rig Name: DOYON 16 Rig Number: 16 DateFrom-To Hours Actiiyi ,Code NPT Phase Description of Operations 4/13/2002 04:00-04:30 0.50 REST P DECOMP 135K ROT WT.TAG STUB @ 8643'PUMPING 5 BPM @ 925 PSI.SWALLOW STUB TO 8649'&DRESS OFF ROTATING @ 50-60 RPM W/3-5K WOB&MAINTAINING LESS THAN 7000 FT/LBS OF TORQUE AT SURFACE. 04:30-07:00 2.50 REST P DECOMP CIRCULATE(2)20 BBL HI VIS SWEEPS AROUND @ 8 BPM /1900 PSI. BLOW DOWN, BREAK CONNECTIONS&SET BACK KELLY. 07:00-15:30 8.50 REST P DECOMP POOH&LD 3 1/2"DP. 15:30-16:00 0.50 REST P DECOMP UD CLEANOUT BHA. 16:00-17:00 1.00 REST P DECOMP CLEAR RIG FLOOR&PULL WEAR BUSHING. 17:00-00:00 7.00 RUNCOMP COMP LOAD PIPESHED W/4 1/2"COMP STRING,STRAP, DRIFT &CLEAN THREADS ON SAME. 4/14/2002 00:00-06:00 6.00 RUNCOMP COMP CONTINUE TO LOAD,TALLY, DRIFT&CLEAN THREADS ON 4 1/2", 12.6#, 13cr Vam Ace TUBING&JEWELRY. PJSM ON RUNNING COMPLETION, EMPHASIS ON HAND PLACEMENT. 06:00-00:00 18.00 RUNCOMP COMP PICK UP&RIH W/4 1/2"COMPLETION STRING,GATOR HAWKING EACH CONNECTION TO 5000 PSI,TORQUE TURNING EACH CONNECTION TO 3620 FT/LBS. NO FAILURES, NO JOINTS LAID DOWN. 4/15/2002 00:00-01:30 1.50 RUNCOMP COMP CONTINUE IN HOLE W/4 1/2"COMPLETION STRING. M/U HEAD PIN ON JT#202&RIH SLOWLY PUMPING @ 2.5 BPM/100 PSI.SEE PRESSURE INCREASE TO 170 PSI W/ 4'OF#202 BELOW TABLE, (TOP OF STUB). BLEED PRESSURE&SWALLOW(6')OF STUB, LOCATE OUT W/ 10'OF#202 BELOW TABLE. 01:30-05:00 3.50 RUNCOMP COMP PICK UP ABOVE TUBING STUB, R/U CIRC HOSE& REVERSE CIRCULATE 500 BBLS OF 150 DEG SEAWATER/ CORRSION INHIBITOR DOWN I/A @ 3 BPM/140 PSI. 05:00-08:00 3.00 RUNCOMP COMP SLACK OFF&LOCATE OUT W/(9')OF#202 BELOW TABLE,(1')EXPANSION DUE TO HEATED FLUID.SPACE OUT. LAY DOWN#202,201 &200,M/U(2)PUPS, (17.8' TOTAL LENGTH),&M/U JT#200.M/U HANGER&LANDING JOINT&DROP ROD/BALL. 08:00-09:30 1.50 RUNCOMP COMP DRAIN STACK, LAND HANGER, RILDs.WITH I/A OPEN, PRESSURE TUBING TO 3000 PSI, SET S-3 PACKER& TEST TUBING, 30 MINUTES,CHARTED,OK. BLEED TUBING TO 1500 PSI, PRESSURE I/A TO 3000 PSI,30 MINUTES,CHARTED,OK. BLEED TUBING PRESSURE& SHEAR RP VALVE. 09:30-12:00 2.50 WHSUR P COMP SET TWO WAY CHECK&TEST, N/D BOPE. 12:00-15:00 3.00 WHSUR P COMP N/U ADAPTER FLANGE&TREE,TEST BOTH TO 5000 PSI, OK. 15:00-20:00 5.00 WHSUR P COMP R/U LINES&FREEZE PROTECT BY PUMPING 155 BBLS DIESEL DOWN I/A&ALLOWING TO U-TUBE BACK TO TUBING.SET BPV&R/D LINES. 20:00-21:30 1.50 WHSUR P COMP REMOVE SECONDARY ANNULUS VALVE, EMPTY SLOP TANK,SECURE WELL. RIG RELEASED @ 21:30 HRS, 4-15-2002. 21:30-00:00 2.50 RIGD P POST MOVE RIG OFF WELL, LAY OVER DERRICK. PRE MOVE SAFETY MEETING W/ALL ASSOCIATED PARTIES PRESENT. BEGIN MOVING RIG TO J PAD. Printed: 4/22/2002 11:50:03 AM • • Well: H-29A, RWO Rig Accept: 04/10/02 Field: Prudhoe Bay Unit Rig Release: 04/15/02 API: 50-029-21813-01 Permit: 198-038 Drilling Rig: Doyon 16 POST RIG WORK 04/22/02 PULL B&R-SET GENERIC GL DESIGN (STA#4 PULLED CA RD RK-STA#5 PULLED RP SHEAR VLV RK- STA#5 SET DOME/1500 TRO/RK-STA#4 SET DUAL CHECK OGLV/RK) - PULL RHC PLUG BODY. BAIL 100# OF SLUGGIT OFF XN PLUG @ 86801'SLM. 04/23/02 AIL SLUGGETS AND PULL XXN PLUG FROM XN NIPPLE. 04/24/02 PULL XXN PLUG FROM XN NIPPLE @ 8706'WLMD. 04/25/02 BAIL OFF XXN PLUG--OPEN LOCK ON PLUG W/GR-WELL LEFT SI - PLUG STILL IN HOLE. 04/27/02 RIN 4 1/2" GS. PICKED UP 4 1/2" XXN PLUG IN STA#1 @ 8416'WLM. 04/28/02 PULLED 4 1/2" XXN PLUG. RETURNED WELL TO PROD. NOTIFIED OPER. icier oz MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, DATE: April 22, 2001 Commissioner THRU: Tom Maunder, geiy?owitcb-r P. 1. Supervisor y FROM; Lou Grimaldi, SUBJECT: SVS Misc. tests Petroleum Inspector BPX H pad Prudhoe Bay Field Sunday, April 22, 2001; I witnessed the first of the one-month retests of the SVS systems on BPX H pad wells in the GC-2 area of the Prudhoe Bay Field. Mery Liddelow (BP Rep.) performed the SVS tests today. All components functioned properly and held their pressure tests. The new style pilot boxes were installed on most of the wells, which combined with the reliability of the electronic pilots helped to produce these great results. The well houses were all clean with pilot valves in proper position. SUMMARY: I witnessed the SVS test on twenty BPX H pad wells in the Prudhoe Bay Field. 20 wells, 40 components, No failures. Wellhouse Inspections; 33 wellhouses, No problems noted. Attachments: SVS PBU H-pad 4-22-01 LG.XLS NON-CONFIDENTIAL SVS PBU H-pad 4-22-01 LG r M • . Alaska Oil and Gas Conservation Commission ' Safety Valve System Test Report Operator: BPX Submitted By: Lou G. Date: 22-Apr Operator Rep: Mery Liddelow Field/Unit/Pad: Prudhoe Bay field, H-pad AOGCC Rep: Lou Grimaldi Separator psi: LPS 157 HPS 650 Well Data Pilots SSV SSSV Retest Well Type Well Permit Separ Set LIP Test Test Test Date Oil,WAG,GINJ, Number Number PSI PSI Trip _ Code Code Code Passed GAS or CYCLE H-01A 1951100 H-02 1710160 H-04 1710220 H-05 1710240 650 550 550 P P OIL H-06 1770020 157 125 125 P P OIL H-07A 2001280 H-08 1770230 H-11 1800680 157 125 100 P P OIL H-12 1800670 H-13 1810170 650 550 525 P P OIL H-14A 1980680 11-15 1810610 157 125 125 P P OIL H-16B 2000650 H-17A 1971520 650 550 510 P P OIL H-18 1822100 H-19B 1980940 650 550 540 P P OIL H-20 1830070 H-21 1860710 650 550 525 P P OIL H-22A 1970480 157 125 125 P P OIL H-23A 1950850 650 550 550 P P OIL 11-24 1853050 157 125 115 P P OIL H-25 1852680 650 550 550 P P OIL 11-26 1852770 157 125 95 P P OIL H-27 1852360 H-28 1880440 H-29A 1980380 650 550 530 P P OIL H-30 1880350 650 550 525 P P OIL H-31 1940140 11-32 1940250 157 125 100 P P OIL H-33 1940380 650 550 515 P P OIL H-34 1971640 157 125 125 P P OIL 11-35 1951490 650 550 515 P P OIL H-36A 2000250 11-37 1971020 157 125 125 P P OIL Wells: 1/16/01 20 Components: p eAal es: 0 Fj( e,feen pad049�0_ T&Y a 1110 Well Data Pilots SSV SSSV Retest Well Type Well Permit Separ Set LIP Test Test Test Date Oil,WAG,GM, Number I Number PSI PSI Trip Code Code Code Passed GAS or CYCLE Remarks: Great test, no failures. RJF 1/16/01 Page 2 of 2 SVS PBU H pad 4-22-01 LG • F-03s) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ?` �AoN DATE: March 28, 2001 Commissioner NI THRU: Tom Maunder, � v� rv?„ rvi or` -c\ P. I. Supe C�s � FROM: Lou Grimaldi, SUBJECT: SVS Misc. tests Petroleum Inspector BPX `3. H v Prudhoe Bay Field Mondavi March 12, 2001; I witnessed the four of the Semi-Annual SVS tests on BPX welts H-15,16B,23A,29A in the GC-2 area of the Prudhoe Bay Field. I had to leave before completion of the pad due to a Exploratory wells Diverter function test. Mery Liddelow (BP Rep.) performed the SVS tests today. All components functioned properly and held their pressure tests with the exception of the Surface Safety Valve on H-15 which had a slow internal leak. This was greased, cycled and retested "OK". The well houses were all clean with pilot valves in proper position. SUMMARY: I witnessed the SVS test on four BPX wells in the Prudhoe Bay Field. 4 wells, 11 components, One failure. Wellhouse Inspections; 4 wellhouses, No failures Attachments: SVS PBU H-pad 3-28-01 LG.XLS NON-CONFIDENTIAL SVS PBU H-pad 3-28-01 LG • Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Lou Grimaldi Date: 28-Mar Operator Rep: Mery Liddelow Field/Unit/Pad: Prudhoe Bay field, H pad AOGCC Rep: Lou Grimaldi Separator psi: LPS 150 HPS 685 Well Data Pilots SSV SSSV Retest Well Type Well Permit Separ Set L/P Test Test Test Date oil,WAG,GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE H-01 A 1951100 H-02 1710160 H-04 1710220 H-05 1710240 H-06 1770020 H-07A 2001280 H-08 1770230 H-11 1800680 H-12 1800670 H-13 1810170 H-14A 1980680 H-15 1810610 150 125 120 P 4 H-16B 2000650 685 550/125 525/120 P P H-17A 1971520 H-18 1822100 H-19B 1980940 H-20 1830070 H-21 1860710 H-22A 1970480 H-23A 1950850 685 550/125 560/125 P P H-24 1853050 H-25 1852680 H-26 1852770 H-27 1852360 H-28 1880440 H-29A 1980380 685 550/125 570/140 P P H-30 1880350 H-31 1940140 H-32 1940250 H-33 1940380 H-34 1971640 H-35 1951490 RJF 1/16/01 Page 1 of 2 010328-SVS PBU H-pad-LG • 411 A Well Data Pilots SSV SSSV Retest Well Type Well Permit Separ Set LIP Test Test Test Date Oil,WAG,GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE H-36A 2000250 H-37 1971020 Wells: 4 Components: 11 Failures: 1 Failure Rate: 9.09% ❑90 Day Remarks: Partial pad results. Dual pilots tested on above wells. RJF 1/16/01 Page 2 of 2 010328-SVS PBU H-pad-LG 4 e Well Compliance Report File on Left side of folder 198-038-0 PRUD E BAY UNIT H-29A 50- 029-21813-01 ARCO MD 11050' TVD 08944 ompletion Date: 47-12/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D V';� 11 S Rh WR4 OH 4/29/98 4/30/98 L 8700 `-'4SPERRY MPT/GR/EWR4/CNP/SLD OH 8/26/98 8/26/98 L CAL 91‘: 8290-8902 I31 i g CH 5 4/16/98 4/21/98 L DGR/EWR4-MD ,/FI///NAL 8558-11050 OH 9/2/98 9/2/98 L NGP/DGR/CNP/SLD LINAL 8262-8944 OH 9/2/98 9/2/98 L NGP/DGR/CNP/SLD ky/INAL 8558-11050 OH 9/2/98 9/2/98 L NGP/DGR/EWR4-TVD 1�INAL 8262-8944`26OH 9/2/98 9/2/98 Daily Well Ops3/ �J/A/'�o Are Dry Ditch Samples Required? yes ifiD And Received?--yes--no Was the well cored? yes — Analysis Description Re j .e—gra Sample-Set-#------- - -_ Comments: I Monday,May 01,2000 Page 1 of 1 • sperry-sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska September 2, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs-H-29A, AK-MM-80173 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a _ signed copy of this of this transmittal letter to the attention of Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,#G, Anchorage, AK 99518 H-29A: 2" x 5"MD Resistivity&Gamma Ray Logs: 1 Blueline 50-029-21813-01 1 Rev Folded Sepia 2" x 5" TVD Resistivity& Gamma Ray Logs: 1 Blueline 50-029-21813-01 1 Rev Folded Sepia 2"x 5" MD Neutron&Density Logs: 1 Blueline 50-029-21813-01 1 Rev Folded Sepia 2" x 5" TVD Neutron& Density Logs: 1 Blueline 50-029-21813-01 1 Rev Folded Sepia a tre0 • .4 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 563-3256 • Fax (907) 563-7252 A Division of Dresser Industries, Inc. a sperry-sun DRILLING SERVICES WELL LOG TRANSMITTAL To: State of Alaska August 26, 1998 Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. 0451 Anchorage, Alaska 99501 : $'" WI D0 RE: MWD Formation Evaluation Logs H-29A, AK-MM-80173 1 LDWG formatted Disc with verification listing. API#: 50-029-21813-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services BP Exploration(Alaska)Inc. Attn: Ali Turker Petro-technical Data Center,MB3-3 5631 Silverado Way, Suite G. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99519-6612 k f,C �_6 '998 I ,, Date:'`'' Signed. 5-1A-I L ,.,1.;-:moi '-rit Qiage 5631 Silverado Way, Suite G • Anchorage, Alaska 99518 • (907) 563-3256 • Fax (907) 563-7252 A Division of Dresser Industries, Inc. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION 1 &!yip WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well S Oil ❑Gas ❑Suspended ❑Abandoned ❑Service Cf;n'fi7fg5rrr 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 98-38 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21813-01 4. Location of well at surface 9. Unit or Lease Name 1006' SNL, 1265'WEL, SEC. 21,T11N, R13E, UM Ilsr Prudhoe Bay Unit At top of productive interval 10. Well Number 78' NSL, 1501'WEL, SEC. 16,T11N, R13E, UM H-29A At total depth � ' 11. Field and Pool 1002' NSL, 598'WEL, SEC. 16,T11N, R13E, UM Prudhoe Bay Field/Prudhoe Bay 5. Elevation in feet(indicate KB, DF, etc.) 6. Lease Designation and Serial No. Pool KBE=72.37' ADL 028284 12. Date Spudded 13. Date T.D. Reached 14. Date Comp.,Susp.,or Aband. 15.Water depth, if offshore 16. No. of Completions 3/30/98 4/7/98 4/12/98 N/A MSL One 17.Total Depth(MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21.Thickness of Permafrost 11050 8944 FT 10960 8940 FT E Yes ❑No (Nipple) 2190' MD 1900' (Approx.) 22.Type Electric or Other Logs Run MWD,4-Arm Caliper, NEU, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" Insulated Conductor Surface 110' 8 cu yds concrete 13-3/8" 68# L-80 Surface 2676' 17-1/2" 3723 cu ft Arctic Set II & III 9-5/8" 47# L-80 Surface 8520' 12-1/4" 1970 cu ft Class 'G' 7" 26# L-80 8364' 8900' 8-1/2" 130 cu ft Class 'G' 4-1/2" 12.6# L-80 8716' 11050' 6" 297 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET(MD) PACKER SET(MD) 2-3/4" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 8716' 8657' MD TVD MD TVD 10660'-10800' 8920' -8931' 10870'- 10940' 8936' -8939' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) AMOUNT&KIND OF MATERIAL USED Freeze Protect with 160 Bbls of Diesel 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift,etc.) A April 16, 1998 Flowing G+� L Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-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. Form 10-407 Rev. 07-01-80 Submit In Duplicate s • 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids Depth Depth recovered and gravity, GOR,and time of each phase. Sag River 8864' 8534' Shublik 8896' 8561' Sadlerochit 8988' 8637' Zone 2 9620' 8893' 31. List of Attachments Summary of Daily Drilling Reports,Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone - r Title Engineering Supervisor Date s H-29A 98-38 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection,water injection, steam injection, air injection, salt water disposal,water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference(where not otherwise shown)for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 16,and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL)or other elevation(DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 • BP Progress Report Facility PB H Pad Well H-29A Page 1 Rig Doyon 16 Date 06 May 98 Date/Time Duration Activity 24 Mar 98 10:00-06:00 20 hr Rig waited:Whiteout/Phase 2 25 Mar 98 06:00-13:00 7 hr Rig waited:Whiteout/Phase 2 13:00-18:00 5 hr Rig moved 90.00% 18:00-18:30 1/2 hr Held safety meeting 18:30-00:30 6 hr Rigged up Drillfloor/Derrick 26 Mar 98 00:30-01:30 1 hr Rigged up Fluid system 01:30-06:00 4-1/2 hr Rigged up Flowline valve 06:00-06:05 0 hr Rigged up Flowline valve(cont...) 06:05-07:00 3/4 hr Held safety meeting 07:00-07:30 1/2 hr Removed Hanger plug 07:30-10:30 3 hr Circulated at 8550.0 ft 10:30-11:00 1/2 hr Installed Hanger plug 11:00-14:30 3-1/2 hr Rigged down Xmas tree 14:30-18:00 3-1/2 hr Rigged up All functions 18:00-18:30 1/2 hr Held safety meeting 18:30-20:30 2 hr Rigged up All functions 20:30-02:30 6 hr Tested All functions 27 Mar 98 02:30-03:30 1 hr Removed Hanger plug 03:30-04:30 1 hr Installed Tubing retrieval string 04:30-06:00 1-1/2 hr Circulated at 8550.0 ft 06:00-06:05 0 hr Circulated at 8550.0 ft(cont...) 06:05-06:30 1/4 hr Held safety meeting 06:30-07:30 1 hr Retrieved Tubing landing string 07:30-08:30 1 hr Set Retrievable packer at 30.0 ft with 1000.0 psi 08:30-09:00 1/2 hr Retrieved Seal assembly 09:00-12:00 3 hr Rigged down BOP stack 12:00-13:15 1-1/4 hr Installed Seal assembly 13:15-14:30 1-1/4 hr Tested BOP stack 14:30-16:00 1-1/2 hr Rigged down Hanger plug 16:00-17:00 1 hr Circulated at 8550.0 ft 17:00-18:00 1 hr Laid down 500.0 ft of Tubing 18:00-18:30 1/2 hr Held safety meeting 18:30-20:30 2 hr Laid down 2000.0 ft of Tubing 20:30-03:00 6-1/2 hr Laid down 6000.0 ft of Tubing 28 Mar 98 03:00-03:30 1/2 hr Rigged down Tubing handling equipment 03:30-06:00 2-1/2 hr Made up BHA no. 1 06:00-06:05 0 hr Made up BHA no. 1 (cont...) 06:05-06:30 1/4 hr Held safety meeting 06:30-07:30 1 hr R.I.H.to 50.0 ft 07:30-08:00 1/2 hr Tested M.W.D.tool-Via string 08:00-10:30 2-1/2 hr R.I.H.to 3950.0 ft 10:30-12:00 1-1/2 hr Tested Kelly/top drive hose 12:00-18:00 6 hr R.I.H.to 7000.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-20:30 2 hr R.I.H.to 8550.0 ft 20:30-21:00 1/2 hr Took MWD survey at 8550.0 ft 21:00-22:00 1 hr Tested Casing-Via annulus and string 22:00-22:30 1/2 hr Set Permanent packer at 8550.0 ft with 0.0 psi 22:30-23:00 1/2 hr N Circulated at 8550.0 ft 23:00-06:00 7 hr Milled Casing at 8520.0 ft 29 Mar 98 06:00-06:05 0 hr Milled Casing at 8520.0 ft(cont...) 06:05-06:30 1/4 hr Held safety meeting 06:30-12:00 5-1/2 hr Milled Casing at 8558.0 ft 12:00-14:00 2 hr Circulated at 8558.0 ft • BP Progress Report Facility PB H Pad Well H-29A Page 2 Rig Doyon 16 Date 06 May 98 Date/Time Duration Activity 14:00-18:00 4 hr Pulled out of hole to 900.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-19:00 1/2 hr Pulled BHA 19:00-21:00 2 hr Made up BHA no.2 21:00-02:30 5-1/2 hr R.I.H.to 8546.0 ft 30 Mar 98 02:30-03:00 1/2 hr Reamed to 8558.0 ft 03:00-06:00 3 hr Drilled to 8675.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-09:30 3 hr Drilled to 8835.0 ft 09:30-10:30 1 hr Circulated at 8835.0 ft 10:30-11:30 1 hr Drilled to 8867.0 ft 11:30-12:30 1 hr Circulated at 8867.0 ft 12:30-14:00 1-1/2 hr Drilled to 8900.0 ft 14:00-15:00 1 hr Circulated at 8900.0 ft 15:00-15:30 1/2 hr Pulled out of hole to 8520.0 ft 15:30-16:30 1 hr Circulated at 8900.0 ft 16:30-18:00 1-1/2 hr Pulled out of hole to 8520.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-23:00 4-1/2 hr Pulled out of hole to 0.0 ft 23:00-04:30 5-1/2 hr Conducted electric cable operations 31 Mar 98 04:30-06:00 1-1/2 hr Ran Liner to 500.0 ft(7in OD) 06:00-06:30 1/2 hr Held safety meeting 06:30-07:00 1/2 hr Ran Liner to 1000.0 ft(7in OD) 07:00-07:30 1/2 hr Circulated at 1000.0 ft 07:30-12:00 4-1/2 hr Ran Liner to 8520.0 ft(7in OD) 12:00-13:00 1 hr Serviced Block line 13:00-14:00 1 hr Ran Liner to 8900.0 ft(7in OD) 14:00-15:30 1-1/2 hr Mixed and pumped slurry-23.500 bbl 15:30-17:00 1-1/2 hr Reverse circulated at 8300.0 ft 17:00-18:00 1 hr Circulated at 8300.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-01:00 6-1/2 hr Retrieved downhole equipment-Liner hanger 01 Apr 98 01:00-03:15 2-1/4 hr Made up BHA no. 3 03:15-03:45 1/2 hr Held safety meeting 03:45-04:00 1/4 hr R.I.H.to 160.0 ft 04:00-06:00 2 hr R.I.H.to 2500.0 ft 06:00-06:05 0 hr R.I.H.to 2500.0 ft(cont...) 06:05-06:30 1/4 hr Held safety meeting 06:30-10:30 4 hr R.I.H.to 8704.0 ft 10:30-11:30 1 hr Tested Liner-Via annulus and string 11:30-16:00 4-1/2 hr Drilled cement to 8900.0 ft 16:00-18:30 2-1/2 hr Drilled to 8920.0 ft 18:30-06:00 11-1/2 hr Drilled to 9220.0 ft 02 Apr 98 06:00-06:30 1/2 hr Drilled to 9220.0 ft(cont...) 06:30-18:30 12 hr Drilled to 9503.0 ft 18:30-01:00 6-1/2 hr Drilled to 9684.0 ft 03 Apr 98 01:00-03:30 2-1/2 hr Circulated at 9684.0 ft 03:30-06:00 2-1/2 hr Pulled out of hole to 9684.0 ft 06:00-09:00 3 hr Pulled out of hole to 210.0 ft(cont...) 09:00-09:15 1/4 hr Held safety meeting 09:15-10:30 1-1/4 hr Pulled BHA 10:30-11:00 1/2 hr Retrieved Wear bushing 11:00-14:30 3-1/2 hr Tested All functions 14:30-15:00 1/2 hr Retrieved BOP test plug assembly • BP Progress Report Facility PB H Pad Well H-29A Page 3 Rig Doyon 16 Date 06 May 98 Date/Time Duration Activity 15:00-16:45 1-3/4 hr Made up BHA no.4 16:45-17:00 1/4 hr Functioned M.W.D.tool 17:00-21:00 4 hr R.I.H.to 9595.0 ft 21:00-21:30 1/2 hr Took MWD survey at 9595.0 ft 21:30-22:00 1/2 hr Reamed to 9684.0 ft 22:00-06:00 8 hr Drilled to 9915.0 ft 04 Apr 98 06:00-07:30 1-1/2 hr Drilled to 9946.0 ft(cont...) 07:30-09:30 2 hr Circulated at 9946.0 ft 09:30-15:00 5-1/2 hr Pulled out of hole to 210.0 ft 15:00-16:30 1-1/2 hr Pulled BHA 16:30-19:00 2-1/2 hr Made up BHA no. 5 19:00-19:15 1/4 hr Functioned downhole tools at 320.0 ft 19:15-23:00 3-3/4 hr R.I.H.to 9593.0 ft 23:00-23:30 1/2 hr Took MWD survey at 9593.0 ft 23:30-00:00 1/2 hr R.I.H.to 9946.0 ft 05 Apr 98 00:00-06:00 6 hr Drilled to 10071.0 ft 06:00-06:00 24 hr Drilled to 10616.0 ft 06 Apr 98 06:00-15:30 9-1/2 hr Drilled to 10844.0 ft 15:30-17:00 1-1/2 hr Circulated at 10844.0 ft 17:00-18:30 1-1/2 hr Pulled out of hole to 8900.0 ft 18:30-23:00 4-1/2 hr Pulled out of hole to 210.0 ft 23:00-23:30 1/2 hr Downloaded MWD tool 23:30-00:00 1/2 hr Pulled BHA 07 Apr 98 00:00-01:15 1-1/4 hr Downloaded MWD tool 01:15-01:45 1/2 hr Made up BHA no.6 01:45-02:15 1/2 hr Made up BHA no.6 02:15-02:30 1/4 hr Tested M.W.D.tool-Via string 02:30-06:00 3-1/2 hr R.I.H.to 8350.0 ft 06:00-07:00 1 hr Serviced Block line 07:00-08:00 1 hr R.I.H.to 10844.0 ft 08:00-14:00 6 hr Drilled to 11050.0 ft 14:00-16:00 2 hr Circulated at 11050.0 ft 16:00-17:00 1 hr Pulled out of hole to 8900.0 ft 17:00-17:15 1/4 hr Rest hole at 8900.0 ft 17:15-18:30 1-1/4 hr R.I.H.to 11050.0 ft 18:30-20:45 2-1/4 hr Circulated at 11050.0 ft 20:45-01:00 4-1/4 hr Pulled out of hole to 3532.0 ft 08 Apr 98 01:00-03:30 2-1/2 hr Laid down 2600.0 ft of 5in OD drill pipe 03:30-04:00 1/2 hr Pulled out of hole to 230.0 ft 04:00-04:30 1/2 hr Pulled BHA 04:30-04:45 1/4 hr Held safety meeting 04:45-06:00 1-1/4 hr Downloaded MWD tool 06:00-06:15 1/4 hr Held safety meeting 06:15-06:30 1/4 hr Pulled BHA 06:30-08:00 1-1/2 hr Rigged up Casing handling equipment 08:00-08:15 1/4 hr Held safety meeting 08:15-11:30 3-1/4 hr Ran Liner to 1400.0 ft(4-1/2in OD) 11:30-13:30 2 hr Repaired Block line 13:30-14:30 1 hr Ran Liner to 2305.0 ft(4-1/2in OD) 14:30-15:00 1/2 hr Rigged up Tubing handling equipment 15:00-15:15 1/4 hr Held safety meeting 15:15-19:45 4-1/2 hr Ran Tubing to 2187.0 ft(2-7/8in OD) 19:45-20:00 1/4 hr Space out tubulars 20:00-20:30 1/2 hr Installed Liner hanger • • BP Progress Report Facility PB H Pad Well H-29A Page 4 Rig Doyon 16 Date 06 May 98 Date/Time Duration Activity 20:30-21:15 3/4 hr Circulated at 2430.0 ft 21:15-03:00 5-3/4 hr Ran Liner in stands to 8821.0 ft 09 Apr 98 03:00-03:15 1/4 hr Rigged up Cement head 03:15-05:00 1-3/4 hr Circulated at 8821.0 ft 05:00-06:00 1 hr Ran Liner in stands to 9200.0 ft 06:00-06:15 1/4 hr Ran Liner in stands to 11050.0 ft 06:15-08:15 2 hr Circulated at 11050.0 ft 08:15-08:20 0 hr Pumped Brine spacers-volume 20.000 bbl 08:20-08:25 0 hr Tested High pressure lines 08:25-08:40 1/4 hr Pumped Synthetic based mud spacers-volume 50.000 bbl 08:40-08:50 0 hr Mixed and pumped slurry-53.000 bbl 08:50-08:55 0 hr Cleared Chicksan lines 08:55-09:30 1/2 hr Displaced slurry- 150.000 bbl 09:30-09:35 0 hr Functioned Liner hanger 09:35-09:40 0 hr Functioned Tie back packer 09:40-09:45 0 hr Functioned Setting tools 09:45-12:30 2-3/4 hr Circulated at 10948.0 ft 12:30-18:00 5-1/2 hr Pulled Drillpipe in stands to 8716.0 ft 18:00-18:30 1/2 hr Rigged down sub-surface equipment- Setting tools 18:30-20:00 1-1/2 hr Pulled Tubing in stands to 0.0 ft 20:00-20:45 3/4 hr Tested Liner-Via annulus and string 20:45-21:00 1/4 hr Held safety meeting 21:00-21:45 3/4 hr Rigged up sub-surface equipment-TCP 21:45-00:30 2-3/4 hr Ran Tubing in stands to 2000.0 ft 10 Apr 98 00:30-01:30 1 hr Installed Retrievable packer 01:30-06:00 4-1/2 hr Ran Drillpipe in stands to 10900.0 ft 06:00-06:30 1/2 hr Held safety meeting 06:30-07:30 1 hr Ran Drillpipe in stands to 10948.0 ft 07:30-08:00 1/2 hr Held safety meeting 08:00-08:30 1/2 hr Rigged up High pressure lines 08:30-08:45 1/4 hr Space out tubulars 08:45-09:00 1/4 hr Functioned Retrievable packer 09:00-09:05 0 hr Perforated from 10660.0 ft to 10940.0 ft 09:05-10:30 1-1/4 hr Circulated at 8615.0 ft 10:30-11:30 1 hr Monitor wellbore pressures 11:30-18:00 6-1/2 hr Pulled Drillpipe in stands to 2266.0 ft 18:00-18:30 1/2 hr Held safety meeting 18:30-22:30 4 hr Laid down 2000.0 ft of Tubing 22:30-23:30 1 hr Retrieved TCP 23:30-00:00 1/2 hr Removed Wear bushing 11 Apr 98 00:00-01:15 1-1/4 hr Rigged up Tubing handling equipment 01:15-04:30 3-1/4 hr Ran Tubing to 2665.0 ft(4-1/2in OD) 04:30-06:00 1-1/2 hr Repaired Tubing handling equipment 06:00-09:00 3 hr Repaired Tubing handling equipment(cont...) 09:00-09:15 1/4 hr Held safety meeting 09:15-13:00 3-3/4 hr Ran Tubing to 6521.0 ft(4-1/2in OD) 13:00-14:00 1 hr Installed SCSSSV control line 14:00-17:00 3 hr Ran Tubing to 8716.0 ft(4-1/2in OD) 17:00-18:00 1 hr Space out tubulars 18:00-18:30 1/2 hr Held safety meeting 18:30-19:30 1 hr Installed Tubing hanger 19:30-20:00 1/2 hr Ran Tubing on landing string to 8716.0 ft 20:00-20:30 1/2 hr Installed Tubing hanger 20:30-23:30 3 hr Reverse circulated at 8716.0 ft BP Progress Report Facility PB H Pad Well H-29A Page 5 Rig Doyon 16 Date 06 May 98 Date/Time Duration Activity 23:30-00:00 1/2 hr Functioned Permanent packer 12 Apr 98 00:00-00:45 3/4 hr Tested Tubing-Via string 00:45-01:30 3/4 hr Tested Permanent packer-Via annulus 01:30-02:00 1/2 hr Retrieved Tubing landing string 02:00-02:15 1/4 hr Installed Hanger plug 02:15-02:30 1/4 hr Tested Hanger plug 02:30-05:45 3-1/4 hr Rigged down BOP stack 05:45-06:00 1/4 hr Installed Tubing bonnet 06:00-08:00 2 hr Installed Tubing bonnet(cont...) 08:00-09:30 1-1/2 hr Installed Xmas tree 09:30-10:30 1 hr Removed Hanger plug 10:30-11:00 1/2 hr Rigged up High pressure lines 11:00-12:00 1 hr Circulated at 3074.0 ft 12:00-14:00 2 hr Circulated at 3074.0 ft 14:00-14:30 1/2 hr Installed Hanger plug 14:30-15:30 1 hr Rigged down High pressure lines 15:30-16:00 1/2 hr Skid rig • • T 1 w J Y co n1 3 a cp m_ co co cDwcfl (D cD co (D co Co CO CO CO co co co co co co co co co p y M..(0 AcoW () coNiNiN © 0 0 O Oco -4 J CO0) W CT (T coW -+ -+ -a 0 0 (D coCb Co(DO 0 t0 co (T -+ Co Cn N co O co O O A O V A -+ Co A -+ J A co Co CT N (D .D CA 0 t0 CO A. 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P 0 Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit H-29A BP Exploration (Alaska) Inc. Permit No.: 98-038 Sur. Loc: 1006'SNL, 1265'WEL, Sec. 21, T11N, R13E, UM Btmhole Loc: 4369'SNL, 611'WEL, Sec. 16, T11N, R13E, UM Dear Mr. Smith: 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) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 1111111614111111111k 4141141111111111111 1111"16 David W. Johnston Chairman BY ORDER OF TH e ' ISSION dlf'enclosures cc: Department of Fish&Game.Habitat Section wio encl. Department of Environmental Conservation wio encl. 0 STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Z Abandon ❑Suspend M Plugging TiTime Extension ❑Perforate ❑Alter Casing ❑Repair Well ❑Pull Tubing ❑Variance (Z Other ❑Change Approved Program ❑Operation Shutdown LI Re-Enter Suspended Well ❑Stimulate Plug Back for Sidetrack 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. IZ Development KBE = 73.99' AMSL 3. Address illExploratory 7. Unit or Property Name P.O. Box 196612,Anchorage, Alaska 99519-6612 ❑SServiceice phic Prudhoe Bay Unit ❑ 4. Location of well at surface 8. Well Number H-29 1006' SNL, 1265' WEL, SEC. 21,T11N, R13E, UM 9. Permit Number At top of productive interval 88-53 104' NSL, 2281'WEL, SEC. 16,T11N, R13E, UM 10.API Number At effective depth 50-029-21813 397' NSL, 2466'WEL,SEC. 16,T11N, R13E, UM 11. Field and Pool At total depth Prudhoe Bay Field/Prudhoe Bay 433' NSL,2488'WEL, SEC. 16,T11N, R13E, UM Pool 12. Present well condition summary Total depth: measured 9700 feet Plugs(measured) true vertical 9211 feet Effective depth: measured 9628 feet Junk(measured) Fill at 9628' MD(05/89) true vertical 9153 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds concrete 110' 110' Surface 2648' 13-3/8" 3723 cu ft Arctic Set II&III 2676' 2676' Intermediate 8861' 9-5/8" 1970 cu ft Class 'G' 8889' 8539' Production Liner 1041' 7" 363 cu ft Class 'G' 8659' -9700' 8347' -9211' Perforation depth: measured 9316' -9356' ' fW ` , true vertical subsea: 8823' - 8856' Tubing (size, grade, and measured depth) 5-1/2", L-80 to 2496'; 4-1/2", L-80 2496' -8600' with tailpipe to 8704' Packers and SSSV(type and measured depth) 9-5/8"TIW packer at 8600'; 5-1/2" SSSV at 2114' 13.Attachments ®Description summary of proposal ❑Detailed operations program ❑BOP sketch 14. Estimated date for commencing operation 15. Status of well classifications as: March 5, 1998 16. If proposal was verbally approved ®Oil Gas ❑Suspended Service Name of approver Date approved Contact Engineer Name/Number: C.Michael Jackson,564-5480 Chris Brown,564-5582 Prepared By Name/Number: Terrie Hubble,564-4628 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed _James Smithh ;� �'— /477:--- Title Engineering Supervisor Date /, -5/ .6"- ,/,/ Commission Use Only � y8—�/i Conditions of Approval: Notify Commission so representative may witness Approval No. Plug integrity BOP Test Location clearance Mechanical Integrity Test Subsequent form required 10- Approved by order of the Commission ti-J Commissioner Date,g 7` g Form 10-403 Rev. 06/15/88 Submit In Triplicate STATE OF ALASKA ALA OIL AND GAS CONSERVATION AV1MISSION PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ❑Drill ®Redrill 1 b. Type of well 0 Exploratory ❑Stratigraphic Test ®Development Oil ❑Re-Entry ❑Deepen ❑Service ❑Development Gas ❑Single Zone ❑Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan KBE= 70.99' Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612,Anchorage,Alaska 99519-6612 ADL 028284 4. Location of well at surface 7. Unit or Property Name 11.Type Bond (See 20 MC 25.025) 1006' SNL, 1265'WEL, SEC. 21, T11N, R13E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 25100302630-277 5090' SNL, 1132'WEL, SEC. 16, T11N, R13E, UM H-29A At total depth 9. Approximate spud date Amount $200,000.00 4369' SNL, 611'WEL, SEC. 16,T11N, R13E, UM 03/19/98 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028281,4369' No Close Approach 2560 10920' MD/8985' TVD 16.To be completed for deviated wells 17. Anticipated pressure(see 20 AAC 25.035(e)(2)) Kick Off Depth 8500' MD Maximum Hole Angle 89° Maximum surface 2849 psig, At total depth(TVD) 8450'/3365 psig 18. Casing Program Setting Depth Size Specifications Top Bottom - Quantity of Cement Hole Casing Weight Grade Coupling _ Length MD TVD MD TVD _ (include stage data) 8-1/2" 7" 26# L-80 BTC-Mod 518' 8350' 8088' 8868' 8538' 112 cu ft Class 'G' 6" 4-1/2" 12.6# L-80 BTC-Mod 2225' 8718' 8386' 10943' 8985' 331 cu ft Class 'G' 19.To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9700 feet Plugs(measured) true vertical 9211 feet Effective depth: measured 9628 feet Junk(measured) Fill at 9628' MD(05/89) true vertical 9153 feet Casing Length Size Cemented MD TVD Structural Conductor 110' 20" 8 cu yds concrete 110' 110' Surface 2648' 13-3/8" 3723 cu ft Arctic Set II& III 2676' 2676' Intermediate 8861' 9-5/8" 1970 cu ft Class 'G' 8889' 8539' Production Liner 1041' 7" 363 cu ft Class 'G' 8659' -9700' 8347' -9211' RECEIVED Perforation depth: measured 9316' -9356' ORIGINAL ,U€}4 true vertical subsea: 8823' -8856' Alaska 20.Attachments Z Filing Fee El Property Plat ❑BOP Sketch ❑Diverter Sketch ®Drilling Program ®Drilling Fluid Program ❑Time vs Depth Plot El Refraction Analysis ❑Seabed Report ❑20 MC 25.050 Requirements Contact Engineer Name/Number: C.Michael Jackson,564-5480 Chris Brown,564-5582 Prepared By Name/Number: Terrie Hubble,564-4628 21. I hereby certify that the foregoing is rue and correct to the best of my knowledge Signed5/2� James Smith n � /� Title Engineering Supervisor Dated-4572(f- / Commission Use Only Permit Number API Number Approval D e See cover letter 32 50-029-21813-01 .3 - 5� for other requirements Conditions of Approval: Samples Required ❑Yes 2N Mud Log Required ❑Yes INNo Hydrogen Sulfide Measures ®Yes ❑No Directional Survey Required EYes ❑No Required Working Pressure for BOPE ❑2M; jg1,3M; ❑5M; ❑10M; ❑15M Other: OrialEal Sigr1C0 ti' _ Approved ByDavid W. Johnston the order i C pp Commissioner commission Date 1 - Form 10-401 Rev. 12-01-85 Submit In Triplicate Well Name: PBU H-29A Redrill Plan Summary Type of Redrill (producer or injector): Producer Surface Location: 1006' FNL, 1265' FEL, SEC. 21 , T11N, R13E Target Location: 5090' FNL, 1132, FEL, SEC. 16, T11N, R13E Bottom Hole Location: 4369' FNL, 611' FEL, SEC. 16, T11N, R13E AFE Number: 4P1070 Rig: Doyon 16 Estimated Start Date: 3/19/98 Operating days to complete: 20 MD: 10,920' TVD: 8985' KBE: 70.99' Well Design (conventional, slimhole, etc.): Horizontal Sidetrack Objective: Target Ivishak Zone 2 oil reserves with a horizontal wellbore Mud Program: Sidetrack Mud Properties: LSND 8 1/2" hole section Density (ppg) Funnel Vis Yield Point 10 sec gel 10 min gel pH Fluid Loss 10.2-10.5 40-55 3-10 4-10 15-25 8.5-9.5 6-10cc Production Mud Properties: 6" hole section Quickdril-n Density (ppg) Funnel vis_ LSRV LSR YP pH 8.6-8.8 50-65 40,000 cP 10-20 8.5-9.0 Directional: KOP: 8500' MD / 8214' TVD / 8144' TVDss Maximum Hole Angle: 89° Close Approach Well: NONE Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 8.5" 7" 26# L-80 BTC-M 518' 8350' / 8088' 8868' / 8538' 6" 4 1/2" 12.6# L-80 BTC-M 2225' 8718' / 8386' 10,943' / 8985' Tubing 4 1/2" 12.6# L-80 BTC-M 8718' Surface 8718' / 8386' 1 • • Cement Calculations: Liner Size: 7" Basis: Calculations based on 80' shoe track, 368' of open hole w/ 30% excess and 150' of liner lap. Total Cement Volume: 20 Bbl/ 112 cu.ft/98 sks of Class 'G' tail at 15.8 ppg and 1.14 yld. Liner Size 4 1/2" Basis: Calculated based on 80' shoe track, 2075' of open hole with 50% excess, 150' of liner lap and 200' of DP x casing annulus. Total Cement Volume: 59 Bbl/331 cu.ft/278 sks of Class `G' tail(acid resistant) at 15.7 ppg and 1.19 yld. Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. • Maximum anticipated BHP: 3365 psi @ 8450'TVDss (7.7 ppg EMW) • Maximum surface pressure: 2849 psi @ 8380'TVDss (8.5 ppg EMW in Kingak JC thru JA). • Planned Completion Fluid: 8.5 ppg filtered sea water/diesel freeze protection. Drilling Hazards/Contingencies INTERMEDIATE SECTION: • Exposure to the Kingak Shales will be minimal(368' open hole) affecting the bottom three sections JC, JB and JA. • Tight hole conditions have been encountered in the Kingak shales at -7355 TVDss and will be controlled with appropriate mud weights. Mud weights as high as 10.5 ppg may be required. Shale stabilization products will be added before entering the Kingak. "" 13 n 5 l''g • Partial loss returns have been reported in the Kingak below 7400 TVDss. Any losses encountered will follow the LCM decision tree for non-productive zones. aska�i �asCons.COU • Maximum estimated formation pressure: 3687 psi @ 8380 TVDss(8.5 ppg EMW) Anct►orage PRODUCTION SECTION: H Pad reservoir pressures are lower and therefore more sensitive to mud weights. The H�aPad area is moderately faulted in the central part and highly faulted in the south. Faults may pose a potential problem with loss circulation. • H Pad is a H2S pad. The reported level of H2S is 105 ppm on H-22. Conduct H2S drills on a regular basis. • Losses have been encountered drilling the Sag River formations on other H-Pad wells. Pump LCM as necessary to control losses following the LCM decision tree for non-productive zones until reaching the Ivishak. • Lost circulation has been reported since 1995 on H Pad. If losses are encountered refer to the Production Zone LCM decision tree. • The highest formation pressure is estimated at 3365 psi(8450 TVDss) from offset well data. The overbalance while drilling with 8.8 Quickdril will be 501 psi and 369 psi with 8.5 seawater. 2 r • SUMMARY REDRILL PROCEDURE: Pre-Riq Procedure 1. Test the 9-5/8" mandrel packoff to 5000 psi. Notify the Operations Drilling Engineer if the packoff fails. Cycle the lockdown screws and insure the packing gland nuts are tight. 2. CMIT 9-5/8" casing to 3,500psi if not recently tested. Drift tubing to plug back TD of 9659'. 3. P+A existing open perforations (from 9200' - 9659'). Spot 20 bbls (112 cf) Class G cement with coil unit from PBTD to 9200'. Pull back inside completion, and squeeze 3 bbls to perforations (desired TOC at 9200' MD, minimum for AOGCC compliance is 9216' MD, 100' above perforations). Tag/pressure cement, circulate hole clean and POOH. 4. R/U electric line and chemical cut 4-1/2" in the middle of the first full joint(.-8560') above the packer and below the sliding sleeve. Notify Ops Drlg Engineer if chemical cut is unsuccessful, or a jet cut becomes necessary. 5. Circulate well to clean seawater. Freeze protect to ±2,200' MD. 6. Set and test BPV. Remove wellhouse and flowlines, level pad, dig out cellar. Summary Riq Procedure 1. MIRU. Circulate well with 8.5 ppg seawater. Set and test BPV. ND tree. Set BOP blanking plug and NU BOP's. Test same. Pull BOP blanking plug and BPV. 2. Pull 4-1/2" from chemical cut made in pre-rig. Replace 9-5/8" packoff if necessary while pulling tubing. 3. M/U and RIH with bridge plug on electric line and set at depth to allow whipstock kickoff at 8500'. M/U 8-1/2" drilling assembly and sidetrack from whipstock. Directionally drill as per plan to TD of section to TSag at 8809' MD. 4. M/U and run 7" liner to TD and hang off in 9-5/8" casing. Cement liner in place and cleanout if necessary. 5. M/U 6" drilling assembly with 4 phase resistively, RIH, and drill directionally as per plan to TD of section at 10,920' MD. 6. Run DPC open hole logs to horizontal. 7. M/U and run 4-1/2" liner to TD and hang off in 7" casing. Cement liner in place and cleanout if necessary. 3 0 • 8. RIH and perforate liner. M/U and run 4-1/2" completion to the 4-1/2" liner top at 8718' MD (RP shear in top GLM). Shear RP valve in uppermost GLM. 9. Set BPV and test from below. N/D BOP's. N/U tree. Set tree test plug and test tree. Pull test plug and BPV. Circulate and freeze protect well. 10. Set BPV and RDMO. 4 -a'Lf J /1 i b - /: 03 9075637252 SPERRY-SUN PAGE 02 • V P � +�2 g°C "'-o=^ci=moo^^a • # CZ/4 i( - - $ r-- T4 m.7...,g,:a.tamddr_.. 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N N N N N N _N _N N CO •D N E M M M M of Of N O O C N N N N N N (�.c (� • f� NNNN C d N m op to oC rN- N• 2 O pU) M M M Ni 2 N�7 pt plOQ -CD EO Ca 8 C) v3vivv � cyv $ o -SR 2) y e E .`�-' Gi (p u] t0 v) CO r- O 0) 0) 0) 0) G) 0) 0) 0) 0) 00 E A N. rr_ N. N_ iomcoeoco co co mmmm oo a) . • <9 N p p y pp p p p p p p p p p p ¢w co cu 0 t ? c — 4.. t S s3 8 (7 2 `Q�8 $8 8 .p^- 8 p 8 1 2i 8 o6a 8 `aa a tp aa 9 p 8p O Z.Z. C d N _ N D ~ O, 2 b) O O O O O O O O Q O 'D CO == n --0 m _ as .= 4 > .- > [0 1-- , - ^) 02/19/1999 17:03 9075637252 SPERRY-SUN PAGE 06 0 • Sperry-Sun Drilling Services .c ' Proposal Report for hl 29A -H-29A Wpl 1 (Cony) Alaska State Plane Zone 4 Prudhoe Bay Unit PBU_WOA H Pad Measured Vertical Vertical Dogleg Depth Incl. Azim. Depth Northings Eastings Section Rate (ft) (n) (ft) (ft) : (ft) (•n 00ft) 8500.00 34.078 322.318 8214.60 - 886.36 N 850.75 W -200.14 8530.00 36.174 320.285 8239.14 899.83 N 881.54 W -201.43 8.000 8809.01 25.935 32.184 8485.49 1018.82 N 882.38 W -151.29 13.000 8839.01 25.935 32.184 8512.47 1029.92 N 875.39 W -139.25 0.000 9215.00 67.440 91.124 8775.23 1102.04 N 638.61 W 98.80 15.003 9283.73 72.595 91.099 8798.71 1100.79 N 574.04 W 149.33 7.500 9563.59 72.595 91.099 8882.42 1095.67 N 307.05 W- 366.81 0.000 9631.33 76.530 81.377 8900.49 1100.00 N 242.00 W 422.70 15.000 = - 9631.35 76.530 81.374 8900.50 1100.00 N 241.98 W 422.72 14.000 9820.34 76.530 81.374 8944.52 1127.57 N 80.27W 588.15 0.000 - 10025.17 89.040 60.000 8970.49 1194.74 N 129.81 E 782.89 12.000 10256.70 89.045 32.212 8974.44 1353.68 N 295.00 E 1009.02 12.000 10920.21 89.045 32.212 • 8985.49 1914.88 N 648.84 E 1618.16 0.000 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. i The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 55.550°(True). Based upon Minimum Curvature type calculations,at a Measured Depth of 10920.21ft., The Bottom Hole Displacement is 2021.85ft., in the Direction of 18.712°(True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9631.33 8900.49 1100.00 N 242.00 W Target:H-29A PrePoly,Geological Format/on Tops Measured Vertical Sub-Sea Depth Depth Depth Northings Eastings Formation Name (ft) (ft) (ft) (ft) (ft) 8543.95 8250.49 8180.00 906.16 N 868.60 W TJC 8693.26 8380.49 8310.00 972.48 N 894.59 W TJB 8770.30 8450.49 8380.00 1004.06 N 889.76 W TJA 8792.38 8470.49 8400.00 1012.58 N 885.95 W Fault 8809.01 8485.49 6415.00 1018.82 N 862.38 W TSGR 8847.95 8520.49 8450.00 103330 N 873.21 W TSHU 8916.37 8580.49 8510.00 105628 N 850.06 W TSAD 9104.76 8720.49 8650.00 1096.80 N 733.71 w 42N SHALE 9229.02 8780.49 8710.00 1101.79 N 625.61 W TZ3 9557.13 8880.49 8810.00 1095.79 N 313.21 W TZ2C/CGOC 9781.58 8935.49 8865.00 1121.92 N 97.53 W POWC 9847.55 8950.49 8880.00 113222 N 34.13 W 25N Shale Casing details From To Measured Vertical Measured Vertical Depth Depth Depth Depth Casing Detail (ft) (ft) (ft) (ft) 8500.00 8214.60 8809.01 8485.49 7'Caning <Surface> <Surface> 10920.21 8985.49 4 1/2'Liner continued... 19 February, 1995- 14:57 -1- DrlllOu.4F '_ - x2/19/1998 17:03 9075637252 SPERRY-SUN PAGE 07 0 • Sperry-Sun Drilling Services Proposal Report for H-29A -11-21PA Wpl1 (Cony) Alaska State Plane Zone 4 Prudhoe Bay Unit PBU_WOA H Pad Targets associated with this welipath Target Entry Coordinates Target TVD Northings Eaatings Target Target Name (ft) (ft) (ft) Shape Type H-29A Poty 8970.49 1194.74 N 129.81 E Polygon Geological H-29A PrePoly 8900.49 1224.37 N 374.72 W Polygon Geological Poly Entrance 8970.49 1194.74N 129.81 E Point Geological Poly Exit 8985.49 1914.98 N 848.64 E Point Geological Pre Poly Target 8900.49 1100.00 N 242.00 W Point Geological 19 February, 199e-14:57 '2' Or/UOuest TREE: 4„ -29A ProposedBF. ELEV=46.49 WELLHEAD: McEVOYilk ACTUATOR: AXELSON 4-1/2"SSSV LANDING ± NIPPLE 2100 13-3/8", 72#/ft, L-80, BTRS 2676' GAS LIFT MANDRELS / - A -- - • MD BKB TVDss TDeo terBe mined I - 4-1/2",12.6#/ft,L-80,BTRS TUBING TUBING ID:3.958" CAPACITY:.01522 BBUFT 7" Liner top @ 8350' MD 7" Production Packer 7"26#L-80 Liner @ 8868' MD Whipstock @ 8500' MD ® , • Tubing Cut @ 8550' MD I 4-1/2" Liner tdp @ 8718' MD ,x 4-1/2" 12.6# L-80 TOP OF 8645' I I @ 10,943' MD 7" LINER 9-5/8",47#/ft, 8889' 411 1 L-80,BTRS P&A Cement Plug (9200' -9456' MD) PBTD 9659' 7",29#/ft, L-80, 9700' BTRS DATE REV.BY COMMENTS PRUDHOE BAY UNIT 6-4-88 INITIAL COMPLETION WELL: H-29A 8-1-90 A TEEL PUT ON MAC API NO: 50-029-21813-01 2/23/98 CMJ Proposed Completion SEC 21_; TN 11N ; RGE 13E BP Exploration (Alaska) x 4 U) O 0 0 o 0 U? 0 vt'7 1. r 0 0 0 z O co UI co <I Q• J Wp .4 CV u o z o 0 0 0 0 GI O 0 cow cro 07 O N •D rt ICT:Z � O ao cc w o � ui t c mo W � Q f p W t Q OD g • a' o "4 Z N H i 4 ^ V L LI)J N U CO J _ U Cr) iu G t—� Li, CO Q I F • • • i DO NOT WRITE IN THIS SPACE 0- 2 al 0 (71 u) o w a i 0 2 C o) c CO Li- U_ H 0 U- 0 0) Z a) `o a) 0a) A a` a) a) W -0 It Q ❑ I- 2 a Z LU a) Q ct CD 0 CC N c a 0 3 L i c cn W cuE a ` E Niiiiii J ° 0 !_ U LU r--,i,----0zzzzzzzzzzzzz zzzzzzzzzzzzzzzz z - zzz :E C5--- >- >- >- >- >- >- >- >- >- 7- >1.-'3;) >- >- >- 7-6T6>-41111%411 >- >- >- )Q z . . . w • I ° ° • D a • ° • • • •m m co 3 m u.u0 e '0--, ^> o .,>.*h \ • • 4 c otcE • • u) > Eo , F ,. , a)C U) \M . • . ° • c ° avioN ` o ° 2' 0 wa) IC 0 - -o 2 . . 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Q Q w Q Q� o • • 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 infor �cation. S • qgrD3 Sperry-Sun Drilling Services —Zr7&O LIS Scan Utility Mon Aug 24 12:17:04 1998 Reel Header Service name LISTPE Date 98/08/24 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 98/08/24 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF RECEIVED Comment Record AUG 2 6 1998 TAPE HEADER PRUDHOE BAY UNIT Alaska Oil&Gas Cons.Commission MWD/MAD LOGS Anchorage WELL NAME: H-29A API NUMBER: 500292181301 OPERATOR: BP EXPLORATION (ALASKA) , INC. LOGGING COMPANY: SPERRY-SUN DRILLING SERVICES TAPE CREATION DATE: 24-AUG-98 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 JOB NUMBER: AK-MM-80173 AK-MM-80173 AK-MM-80173 LOGGING ENGINEER: K.ALLEN B.HENNINGSEN B.HENNINGSEN OPERATOR WITNESS: W.AUBERT W.AUBERT T.MAUNDER MWD RUN 5 MWD RUN 6 JOB NUMBER: AK-MM-80173 AK-MM-80173 LOGGING ENGINEER: B.HENNINGSEN B.HENNINGSEN OPERATOR WITNESS: T.MAUNDER T.MAUNDER SURFACE LOCATION SECTION: 21 TOWNSHIP: 11N RANGE: 13E FNL: FSL: 1006 FEL: 1265 • • FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 72.40 DERRICK FLOOR: 70.90 GROUND LEVEL: 45.40 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 9.625 8536.0 3RD STRING 8.500 7.000 8898.0 PRODUCTION STRING 6.000 11050.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. RUN 2 IS DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 4. MWD RUNS 3-6 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR)UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) , COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND STABILIZED LITHO-DENSITY (SLD) . THE CHANGE FROM NGP TO DGR DETECTORS OCCURS Al 8839'MD, 8912'TVD. 5. NEAR/FAR NEUTRON COUNT RATE DATA IS NOT AVAILABLE FOR MWD RUN 6. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM GREG BERNASKI OF BP EXPLORATION (ALASKA) , INC. ON 07/14/98. 7. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11050'MD, 8944 'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = COMPENSATED THERMAL NEUTRON SANDSTONE POROSITY. SBD2 = SMOOTHED BULK DENSITY- COMPENSATED (BEST BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (BEST BIN) . SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (BEST BIN) . ENVIRONMENTAL PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6" MUD WEIGHT: 8.5 TO 8. 6 PPG FORMATION WATER SALINITY: 11500 PPM CHLORIDES MUD FILTRATE SALINITY: 22000-23500 PPM CHLORIDES FLUID DENSITY: 1. 0 G/CC . MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8499.5 11011.5 ROP 8559.5 11050.0 FCNT 8880.5 10762.0 NCNT 8880.5 10762.0 NPHI 8880.5 10967.0 FET 8890.5 11018.5 RPD 8890.5 11018.5 RPM 8890.5 11018.5 RPS 8890.5 11018.5 RPX 8890.5 11018.5 PEF 8892.0 10982.0 DRHO 8892.0 10982.0 RHOB 8892.5 10982.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 8558.0 8900.0 MWD 3 8900. 0 9684.0 MWD 4 9684.0 9946.0 MWD 5 9946.0 10844. 0 MWD 6 10844.0 11050.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined . 111 • Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 ROP MWD FT/H 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPD MWD OHMM 4 1 68 16 5 RPX MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 RHOB MWD G/CC 4 1 68 32 9 DRHO MWD G/CC 4 1 68 36 10 SNP2 MWD BARN 4 1 68 40 11 NPHI MWD P.U. 4 1 68 44 12 NCNT MWD CNTS 4 1 68 48 13 FCNT MWD CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 8499.5 11050 9774.75 5102 8499.5 11050 GR 10.5558 671. 822 46.4281 5025 8499.5 11011.5 ROP 1.7698 309.375 49.4123 4982 8559.5 11050 RPS 0.1709 2000 21.64 4257 8890.5 11018.5 RPD 0.4419 2000 34.5426 4257 8890.5 11018.5 RPX 0.1857 2000 18.609 4256 8891 11018.5 RPM 0.1944 2000 24. 6762 4257 8890.5 11018.5 FET 0.3286 22.6067 2.14712 4257 8890.5 11018.5 RHOB 2.1406 3.3438 2.35525 4180 8892.5 10982 DRHO -0. 153 0.4325 0.0303854 4181 8892 10982 SNP2 1.1811 15.7871 2.31745 4181 8892 10982 NPHI 4.51 39.81 21.178 4174 8880.5 10967 NCNT 860.286 2608.99 1501.58 3764 8880.5 10762 FCNT 9.4779 161.983 28.2998 3764 8880.5 10762 First Reading For Entire File 8499.5 Last Reading For Entire File 11050 File Trailer Service name STSLIB. 001 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB. 002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8499.5 8839.0 ROP 8559.5 8899.5 LOG HEADER DATA DATE LOGGED: 30-MAR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 / ISC 5.07 DOWNHOLE SOFTWARE VERSION: SP4 5.03/SLD 10.51/DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME) : MEMORY TD DRILLER (FT) : 8900.0 TOP LOG INTERVAL (FT) : 8558.0 BOTTOM LOG INTERVAL (FT) : 8900.0 • BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 25.1 MAXIMUM ANGLE: 34.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER NGP NATURAL GAMMA PROBE NGP SPC 63 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.500 DRILLER'S CASING DEPTH (FT) : 8.5 BOREHOLE CONDITIONS MUD TYPE: BARASILC MUD DENSITY (LB/G) : 10.00 MUD VISCOSITY (S) : 45.0 MUD PH: 13.0 MUD CHLORIDES (PPM) : 29500 FLUID LOSS (C3) : 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .000 MUD AT MAX CIRCULATING TERMPERATURE: . 000 65.6 MUD FILTRATE AT MT: . 000 MUD CAKE AT MT: . 000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : .6 EWR FREQUENCY (HZ) : REMARKS: # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Last Name Min Max Mean Nsam Reading Reading DEPT 8499.5 8899.5 8699.5 801 8499.5 8899.5 GR 46.5925 137.571 105.9 680 8499.5 8839 ROP 9. 6508 309.375 83.5928 681 8559.5 8899.5 First Reading For Entire File 8499.5 Last Reading For Entire File 8899.5 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB. 002 • Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8837.0 9643.0 FCNT 8880.5 9598.5 NCNT 8880.5 9598.5 NPHI 8880.5 9598.5 RPD 8890.5 9650.0 RPM 8890.5 9650.0 RPS 8890.5 9650.0 RPX 8890.5 9650.0 FET 8891.0 9650.0 PEF 8892. 0 9614.0 DRHO 8892.0 9614.0 RHOB 8892.5 9614.0 ROP 8896.0 9684.0 LOG HEADER DATA DATE LOGGED: 03-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5. 07 / ISC 5.07 DOWNHOLE SOFTWARE VERSION: SP4 5. 03/SLD 10.51/DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME) : MEMORY TD DRILLER (FT) : 9684.0 TOP LOG INTERVAL (FT) : 8900.0 BOTTOM LOG INTERVAL (FT) : 9684. 0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 31.8 MAXIMUM ANGLE: 76.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0980SP4 EWR4 ELECTROMAG. RESIS. 4 P0980SP4 SLD STABILIZED LITHO DEN P0980SP4 CTN COMP THERMAL NEUTRON P0980SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.000 DRILLER'S CASING DEPTH (FT) : 6. 0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : 41.0 MUD PH: 8.7 MUD CHLORIDES (PPM) : 22000 FLUID LOSS (C3) : 10.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) H • I MUD AT MEASURED TEMPERATURE (MT) : .210 MUD AT MAX CIRCULATING TERMPERATURE: .107 60.9 MUD FILTRATE AT MT: .200 MUD CAKE AT MT: .200 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : .6 EWR FREQUENCY (HZ) : REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 ROP MWD 3 FT/H 4 1 68 24 7 FET MWD 3 HOUR 4 1 68 28 8 RHOB MWD 3 G/CC 4 1 68 32 9 DRHO MWD 3 G/CC 4 1 68 36 10 SNP2 MWD 3 BARN 4 1 68 40 11 NPHI MWD 3 P.U. 4 1 68 44 12 NCNT MWD 3 CNTS 4 1 68 48 13 FCNT MWD 3 CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 8837 9684 9260.5 1695 8837 9684 GR 10.5558 671. 822 50.4336 1613 8837 9643 RPX 0. 1857 2000 34.9997 1519 8891 9650 RPS 0. 1709 2000 37.3672 1520 8890.5 9650 RPM 0. 1944 2000 43.5601 1520 8890.5 9650 RPD 0.4419 2000 68.501 1520 8890.5 9650 ROP 6.1807 304.102 41. 0793 1577 8896 9684 FET 0.7637 3.3567 1.36596 1520 8890.5 9650 RHOB 2. 1406 3.3438 2.41005 1444 8892.5 9614 DRHO -0. 121 0.4325 0. 0222736 1445 8892 9614 SNP2 1.3055 15.7871 2.87587 1445 8892 9614 NPHI 4.51 39. 81 19.2846 1437 8880.5 9598.5 411 NCNT 860.286 2608.99 1530.47 1437 8880.5 9598.5 FCNT 9.4779 161.983 32.7639 1437 8880.5 9598.5 First Reading For Entire File 8837 Last Reading For Entire File 9684 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF File Header Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9594.5 9861.0 NPHI 9594.5 9861.0 FCNT 9595.0 9861.0 DRHO 9609.5 9876.0 RHOB 9609.5 9876.0 PEF 9614.5 9876.0 GR 9640.0 9905.0 FET 9645.5 9912.0 RPD 9645.5 9912.0 RPM 9645.5 9912.0 RPS 9645.5 9912.0 RPX 9645.5 9912. 0 ROP 9680.0 9946.0 LOG HEADER DATA DATE LOGGED: 04-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 / ISC 5.07 DOWNHOLE SOFTWARE VERSION: SP4 5.03/SLD 10.51/DEPII 2.22A • ! DATA TYPE (MEMORY OR REAL-TIME) : MEMORY TD DRILLER (FT) : 9946.0 TOP LOG INTERVAL (FT) : 9684.0 BOTTOM LOG INTERVAL (FT) : 9946.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 73.7 MAXIMUM ANGLE: 87.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0980SP4 EWR4 ELECTROMAG. RESIS. 4 P0980SP4 SLD STABILIZED LITHO DEN P0980SP4 CTN COMP THERMAL NEUTRON P0980SP4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.000 DRILLER'S CASING DEPTH (FT) : 6. 0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 22000 FLUID LOSS (C3) : 7.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .220 MUD AT MAX CIRCULATING TERMPERATURE: .120 60.9 MUD FILTRATE AT MT: .200 MUD CAKE AT MT: .230 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : .6 EWR FREQUENCY (HZ) : REMARKS: # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 III . RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 FET MWD 4 HOUR 4 1 68 24 7 RHOB MWD 4 G/CC 4 1 68 28 8 DRHO MWD 4 G/CC 4 1 68 32 9 SNP2 MWD 4 BARN 4 1 68 36 10 NPHI MWD 4 P.U. 4 1 68 40 11 ROP MWD 4 FT/H 4 1 68 44 12 NCNT MWD 4 CNTS 4 1 68 48 13 FCNT MWD 4 CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 9594.5 9946 9770.25 704 9594.5 9946 GR 15.2205 78.1701 27.6399 531 9640 9905 RPX 2.2696 16.9368 6.438 534 9645.5 9912 RPS 2.3164 19.5125 7.17973 534 9645.5 9912 RPM 2.4155 18.9941 7.2606 534 9645.5 9912 RPD 2.7269 19.5634 7.74997 534 9645.5 9912 FET 0. 8895 22. 6067 4.20473 534 9645.5 9912 RHOB 2.2056 2.7669 2.32983 534 9609.5 9876 DRHO -0. 153 0.1572 0. 0194135 534 9609.5 9876 SNP2 1.2639 6.2495 2.04149 524 9614.5 9876 NPHI 17. 14 26.87 21.3316 534 9594.5 9861 ROP 5.5352 377.283 50.1508 533 9680 9946 NCNT 1240.32 1684.61 1500.44 534 9594.5 9861 FCNT 17.6215 34.809 26.5841 533 9595 9861 First Reading For Entire File 9594.5 Last Reading For Entire File 9946 File Trailer Service name STSLIB.004 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB.005 Physical EOF File Header Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 9855.5 10762.0 NCNT 9856.0 10762.0 NPHI 9856.5 10762. 0 DRHO 9872.5 10777.5 RHOB 9872.5 10777.5 PEF 9876.5 10777.5 GR 9903.0 10806.5 FET 9907.5 10813.5 RPD 9907.5 10813.5 RPM 9907.5 10813.5 RPS 9907.5 10813.5 RPX 9907.5 10813.5 ROP 9944.0 10845.0 LOG HEADER DATA DATE LOGGED: 06-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.07 / ISC 5. 07 DOWNHOLE SOFTWARE VERSION: SP4 5. 03/SLD 10.51/DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME) : MEMORY TD DRILLER (FT) : 10844.0 TOP LOG INTERVAL (FT) : 9946. 0 BOTTOM LOG INTERVAL (FT) : 10844.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.6 MAXIMUM ANGLE: 107.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0980SP4 EWR4 ELECTROMAG. RESIS. 4 P0980SP4 SLD STABILIZED LITHO DEN P0980SP4 CTN COMP THERMAL NEUTRON P0980SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.000 DRILLER'S CASING DEPTH (FT) : 6. 0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : 52.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 22000 FLUID LOSS (C3) : 6. 0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : .160 MUD AT MAX CIRCULATING TERMPERATURE: . 079 70.3 411 410 MUD FILTRATE AT MT: .200 MUD CAKE AT MT: .240 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : # TOOL STANDOFF (IN) : .6 EWR FREQUENCY (HZ) : # REMARKS: $ # Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . . 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 5 API 4 1 68 4 2 RPX MWD 5 OHMM 4 1 68 8 3 RPS MWD 5 OHMM 4 1 68 12 4 RPM MWD 5 OHMM 4 1 68 16 5 RPD MWD 5 OHMM 4 1 68 20 6 FET MWD 5 HOUR 4 1 68 24 7 RHOB MWD 5 G/CC 4 1 68 28 8 DRHO MWD 5 G/CC 4 1 68 32 9 SNP2 MWD 5 BARN 4 1 68 36 10 NPHI MWD 5 P.U. 4 1 68 40 11 ROP MWD 5 FT/H 4 1 68 44 12 NCNT MWD 5 CNTS 4 1 68 48 13 FCNT MWD 5 CNTS 4 1 68 52 14 First Last Name Min Max Mean Nsam Reading Reading DEPT 9855.5 10845 10350.2 1980 9855.5 10845 GR 13. 6156 79.5648 27.3028 1808 9903 10806.5 RPX 2. 6416 19.4828 10.3353 1813 9907.5 10813.5 RPS 2. 6472 26. 6787 14.6819 1813 9907.5 10813.5 RPM 2.5715 30. 6621 16.5303 1813 9907.5 10813.5 RPD 2. 9779 34.3644 18.3963 1813 9907.5 10813.5 FET 0.5274 18. 9766 2.03507 1813 9907.5 10813.5 RHOB 2. 1618 2. 8063 2.32 1811 9872.5 10777.5 DRHO -0. 117 0.2393 0. 0365865 1811 9872.5 10777.5 SNP2 1. 1811 6.7592 2.00801 1803 9876.5 10777.5 NPHI 17.39 27.19 22.1335 1812 9856.5 10762 ROP 4. 0607 263.672 38.5171 1803 9944 10845 NCNT 1275.27 1696.63 1479.73 1813 9856 10762 FCNT 16. 9775 36.1806 25.269 1814 9855.5 10762 • First Reading For Entire File 9855.5 Last Reading For Entire File 10845 File Trailer Service name STSLIB.005 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB.006 Physical EOF File Header Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10762.5 10967.0 PEF 10778.0 10982.0 DRHO 10778.0 10982.0 RHOB 10778.0 10982.0 GR 10807.0 11011.5 FET 10814.0 11018.5 RPD 10814.0 11018.5 RPM 10814.0 11018.5 RPS 10814.0 11018.5 RPX 10814.0 11018.5 ROP 10841.0 11050.0 LOG HEADER DATA DATE LOGGED: 07-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5. 07 / ISC 5. 07 DOWNHOLE SOFTWARE VERSION: SP4 5. 03/SLD 10.51/DEPII 2.22A DATA TYPE (MEMORY OR REAL-TIME) : MEMORY TD DRILLER (FT) : 11050.0 TOP LOG INTERVAL (FT) : 10844.0 BOTTOM LOG INTERVAL (FT) : 11050.0 110 410 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 84.8 MAXIMUM ANGLE: 88.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0980SP4 EWR4 ELECTROMAG. RESIS. 4 P0980SP4 SLD STABILIZED LITHO DEN P0980SP4 CTN COMP THERMAL NEUTRON P0980SP4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6.000 DRILLER'S CASING DEPTH (FT) : 6.0 BOREHOLE CONDITIONS MUD TYPE: QUIKDRILN MUD DENSITY (LB/G) : 8.60 MUD VISCOSITY (S) : 50.0 MUD PH: 8.8 MUD CHLORIDES (PPM) : 22500 FLUID LOSS (C3) : 6.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : . 190 MUD AT MAX CIRCULATING TERMPERATURE: .093 67.8 MUD FILTRATE AT MT: .200 MUD CAKE AT MT: .220 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : .6 EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999.25 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 API 4 1 68 4 2 RPX MWD 6 OHMM 4 1 68 8 3 RPS MWD 6 OHMM 4 1 68 12 4 RPM MWD 6 OHMM 4 1 68 16 5 RPD MWD 6 OHMM 4 1 68 20 6 411 III ROP MWD 6 FT/H 4 1 68 24 7 FET MWD 6 HOUR 4 1 68 28 8 RHOB MWD 6 G/CC 4 1 68 32 9 DRHO MWD 6 G/CC 4 1 68 36 10 SNP2 MWD 6 BARN 4 1 68 40 11 NPHI MWD 6 P.U. 4 1 68 44 12 First Last Name Min Max Mean Nsam Reading Reading DEPT 10762.5 11050 10906.2 576 10762.5 11050 GR 16.102 160.637 40.6235 410 10807 11011.5 RPX 2.9076 22.3385 9.77434 410 10814 11018.5 RPS 4.3547 25.0104 12.3642 410 10814 11018.5 RPM 4. 8373 24.3439 12.7775 410 10814 11018.5 RPD 5. 6584 24.4257 13.965 410 10814 11018.5 ROP 1.7698 181.299 78.5744 419 10841 11050 FET 0.3286 21. 8996 3.76462 410 10814 11018.5 RHOB 2.208 2.8504 2.35022 409 10778 10982 DRHO -0.046 0.4131 0.0454005 409 10778 10982 SNP2 1.3271 7.0138 2.06215 409 10778 10982 NPHI 16. 15 38. 98 23.3724 410 10762.5 10967 First Reading For Entire File 10762.5 Last Reading For Entire File 11050 File Trailer Service name STSLIB.006 Service Sub Level Name Version Number 1 0 0 Date of Generation 98/08/24 Maximum Physical Record65535 File Type LO Next File Name STSLIB.007 Physical EOF Tape Trailer Service name LISTPE Date 98/08/24 Origin STS Tape Name UNKNOWN Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 98/08/24 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical 11 411 a Services Physical EOF Physical EOF End Of LIS File
