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186-071
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-21 Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-071 50-029-21575-00-00 9961 Conductor Surface Intermediate Production Liner Liner 9180 80 2660 9117 1057 9480 20" x 30" 13-3/8" 9-5/8" 7" 8795 33 - 113 32 - 2692 31 - 9148 8904 - 9961 33 - 113 32 - 2692 31 - 8521 8318 - 9180 Unknown 2670 4760 5410 9480, 9490 5380 6870 7240 9457 - 9722 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6#L-80 29 - 8946 8776 - 8990 Structural 4-1/2" HES TNT Packer 8838, 8263 Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907-564-4763 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 29 - 8353 N/A N/A 579 585 45791 37707 8 28 1200 2010 1400 1015 324-074 13b. Pools active after work:Prudhoe Oil 5-1/2" TIW HBBP Packer 8275, 7791 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 4-1/2" HES TNT Packer 8129, 7668 8129, 8275, 8838 7668, 7791, 8263 No SSSV Installed By Grace Christianson at 3:17 pm, Mar 26, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.03.26 14:26:14 -08'00' Torin Roschinger (4662) RBDMS JSB 040224 DSR-4/12/24WCB 2024-07-09 ACTIVITY DATE SUMMARY 2/10/2024 T/I/O = SSV/250/0. PPPOT-T **PASS**, PPPOT-IC **PASS** (Pre RWO). PPPOT-T: Stung into test port (550 psi). Bled to 0 psi. Function all LDS & torque to 450 ft/lbs. Pressured void to 5000 psi for 30 min test. Lost 100 psi in 15 min, lost 50 psi in 30 min for a PASS. Bled void to 0 psi. PPPOT-IC: Stung into test port (500 psi), bled void to 0 psi. Pressure void to 3500 psi. Lost 100 psi in 15 min, lost 50 psi in 30 min for a PASS. Bled void to 0 psi. Did not function LDS. SV, WV, SSV = C. MV = O. IA, OA = OTG. 16:45 2/14/2024 ***WELL S/I ON ARRIVAL*** RAN DOGLESS GR W/ EQ. PRONG TO 2-7/8'' XX PLUG @ 8380' MD PULLED 2-7/8'' XX PLUG @ 8380' MD PULLED 4.5'' XXN NIP REDUCER @ 8380' MD SET 3.81'' PXN PLUG W/ FILL EXTENSION @ 8380' MD ***CONT. WSR ON 02-15-2024*** 2/14/2024 TFS Unit #4 Assist Slickline T/I/O = 630/160/0 Job continues 2-15-24 2/15/2024 TFS Unit #4 Assist Slickline with Combo MIT Initial T/I/O = 350/190/0 Pressure up TBG and IA to 2750/2740/0 15 mins results 2715/2720/0 for a loss of 35/20/0 30 mins results 2697/2703/0 for a loss of 18/17/0 ***PASS*** Bleed back to starting pressure FWHP T/I/O = 650/560/0 Well left in Slickline control 2/15/2024 ***WSR CONT. FROM 02-14-2024*** PERFORM COMBO MIT (Pass) RUN READ 40 ARM CALIPER LOG FROM 8370' SLM TO SURFACE (BAD DATA, ARMS DIDNT OPEN) ***WELL LEFT S/I ON DEPARTURE*** 2/15/2024 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 1000/250/0 RU YJ ELINE AND BAKER CUTTER, FUNCTION WLV AND PT 300/3000 PSI. CUT AT 8264 FT IN PUP ABOVE PACKER, BAKER TOOL ZERO REFERENCE AT CUT DEPTH. BAKER REPORTS GOOD INDICATION OF CUT, LOST 200 LB LINE TENSION WHILE CUTTING. FINAL T/I/O = 1000/250/0 ELINE COMPLETE *** WELL SI ON DEPARTURE, DSO NOTIFIED *** 2/16/2024 ***WELL S/I ON ARRIVAL*** RAN 3.45'' BARBELL TO TUBING CUT @ 8262'SLM(unable to pass) RAN 10'x2.78'' DMY WHIPSTOCK DRIFT TO TUBING CUT @ 8262'SLM (unable to pass) RAN READ 40 ARM CALLIPER FROM 8260'SLM TO SURFACE(GOOD DATA) ***WELL LEFT S/I ON DEPARTURE*** 2/17/2024 T/I/O= 1066/267/0. LRS 72 Circ Out (RWO EXPENE). Pressure TBG & IA to 2500/2264 for 10 min with 31 bbls DSL to check integrity PASSED. Pump 720 Seawater down TBG up IA to open top tanks. Freeze protect TBG & IA with 172 bbls DSL down IA up TBG. U-Tube for 1 hr. Bleed the TxIA. Flush the surface equipment with 2 bbls of 60/40 MeOH. Final T/I/O= 0/0/11. Well Control Drill: SSV barrel leaking hydraulic oil while pumping water. 2/19/2024 T/I/O = 0/0/0. Set CTS BPV with dry rod. Daily Report of Well Operations PBU H-21 RU YJ ELINE AND BAKER CUTTER, FUNCTION WLV AND PT 300/3000 PSI. CUT AT 8264 FT IN PUP ABOVE PACKER Daily Report of Well Operations PBU H-21 2/29/2024 RDMO H-17A and MIRU on H 21 3/1/2024 MIRU, N/D tree, N/U BOP, Test BOP to 250 low/ 300high psi for 5 min each - test waived AOGCC Kam St.John 3/1/2024 5" H CTS BPV is already set in tubing hanger, check tubing & void for psi., none, nipple down tubing head adapter, clean void & BPV profile, install CTS plug in BPV, make up 4-1/2" TC-II test sub 8 RH, test 3500 psi., good test, bleed off, rig down test equipment, function upper lock down screws one at a time, 4-1/8" clear bowl, re- torque to 500 ft/lbs, install hanger neck protector, install new BX-160, stand by for BOP nipple up & test. 3/2/2024 Make up tubing hanger to string, run in hoele, land on RKB & run in lock down screws, have driller close annular & test hanger to 500 psi/5 min., good test, stand by for circulating, testing, drop ball & rod, set 4" H BPV, stand by for BOP nipple down, clean void, ring groove, & BPV profile, install new DX seal, install lnew BX-160, nipple up THA, test void 500 psi/5 min., 5000 psi/10 min., good tests, bleed off test psi., pull BPV, set TWC,stand by for tree test, pull TWC, RDMO. 3/2/2024 Replace upper IBOP and test same, Rock out diesel and CBU, Pull completion and L/D same, Clear rif floor and load pipe shed 3/3/2024 Cont to run completion, space out and land hanger, displace to inhibited seqa water, set packer. Perform MIT on tubing to 3000 psi for 30 min. Initial 3,140 psi, final 3,100 psi, MIT IA to 2500 for 30 min. Initial 2600 psi, final 2538 psi. N/D BOP and N/U tree. test void and tree to 250 low and 5000 high for 5 min each. 3/4/2024 Test tree to 250 low/5000 high for 5 min each. Release Rig from H-21 @ 06:00. Innovation go into RDMO Operations While LRS FP Tbg/IA with 150 bbls DSL. Allow DSL to U-Tube. Lubricate in BPV. Final Report for Innovation Rig. 3/4/2024 T/I= 0/0 (RWO EXPENSE) Freeze Protect TBGxIA. Pumped 150 bbls of Diesel down IA to displace Sea Water, while taking returns up TBG, out to the Tanker Tank. Rig in control of well upon departure. FWHPs= 300/300 3/6/2024 ***WELL S/I ON ARRIVAL***(post rwo) FUNCTION TEST WLV PULL BALL & ROD FROM RHC @ 8,193'MD PULL 1-1/2" RK-DMY GLV FROM STA #3 @ 5,281' MD PULL 1-1/2" RK-DMY GLV FROM STA #4 @ 3,218' MD SET 1-1/2" RK-LGLV (16/64" ports, 1500# tro) IN STA #4 @ 3,218' MD SET 1-1/2" RK-OGLV (20/64" ports) IN STA #3 @ 5,281' MD PULL 4-1/2" RHC FROM X-NIPPLE @ 8,193' MD PULL P-PRONG FROM 4-1/2" PXN @ 8,380' MD ***CONT WSR ON 03/07/2024*** 3/6/2024 T/I/O = BPV/0/0. I-RIg Completion, Installed 4" CIW FL Tree, PT to 5000 psi. Pass. Pull 4" "H" BPV #134. ***Job Complete*** Final WHP's 0/0/0. 3/7/2024 ***CONT WSR FROM 03/06/2024*** PULL 4-1/2" PXN FROM XN @ 8,380' MD ***WELL LEFT S/I ON DEPARTURE, PAD OP NOTIFIED ON WELL STATUS*** PULL BALL & ROD FROM RHC @ 8,193'MD Cont to run completion, space out and land hanger, displace to inhibited seqa water, g set packer. Perform MIT on tubing to 3000 psi for 30 min. Initial 3,140 psi, finalg 3,100 psi, MIT IA to 2500 for 30 min. Make up tubing hanger to string, run in hoele, land on RKB & run in lock down gg g screws, have driller close annular & test hanger to 500 psi/5 min., good test, stand by g for circulating, testing, drop ball & rod, set 4" H BPV, CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:James Lott - (C) To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC) Subject:Hilcorp Innovation 3-2-24 BOP Test Report Date:Saturday, March 2, 2024 5:41:01 PM Attachments:Hilcorp Innovation 03-02-24.xlsx James Lott HILCORP Drilling Foreman HILCORP INNOVATION Rig PBU, North Slope Alaska 907-670-3094 (Office) 907-398-9069 (Cell) Harmony 1006 jlott@hilcorp.com jameslott352@yahoo.com The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 3UXGKRH%D\8QLW+ 37' STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* SSub m itt to :jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner: Rig No.:Innovation DATE: 3/2/24 Rig Rep.: Rig Email: Operator: Operator Rep.: Op. Rep Email: Well Name:PTD #11860710 Sundry #324-074 Operation: Drilling: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly: Other: Rams:250/3000 Annular:250/3000 Valves:250/3000 MASP:2450 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1FP Permit On Location P Hazard Sec.P Lower Kelly 1P Standing Order Posted P Misc.NA Ball Type 1P Test Fluid Water Inside BOP 1P FSV Misc 0NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0NATrip Tank PP Annular Preventer 1 13 5/8" 5K P Pit Level Indicators PP #1 Rams 1 2 7/8 x 5 1/2" 5K P Flow Indicator PP #2 Rams 1 Blinds P Meth Gas Detector PP #3 Rams 1 7" 5K NT H2S Gas Detector PP #4 Rams 0NAMS Misc 0NA #5 Rams 0NA #6 Rams 0NAACCUMULATOR SYSTEM: Choke Ln. Valves 1 3-1/8" 5K P Time/Pressure Test Result HCR Valves 2 3-1/8" 5K P System Pressure (psi)3000 P Kill Line Valves 2 3-1/8" 5K FP Pressure After Closure (psi)1475 P Check Valve 0NA200 psi Attained (sec)26 P BOP Misc 0NAFull Pressure Attained (sec)92 P Blind Switch Covers: All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.): 6 @ 2355 P No. Valves 15 P ACC Misc 0NA Manual Chokes 1P Hydraulic Chokes 1FP Control System Response Time:Time (sec) Test Result CH Misc 0NA Annular Preventer 11 P #1 Rams 9 P Coiled Tubing Only:#2 Rams 9 P Inside Reel valves 0NA #3 Rams 0 NT #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:3 Test Time:12.5 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/28/24, 18:25 Waived By Test Start Date/Time:3/1/2024 16:30 (date) (time)Witness Test Finish Date/Time:3/2/2024 5:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Kam StJohn Hilcorp Test on 4.5" Test Joint. FP on Inside Kill with Low. Grease Inside Kill and Re-test with Pass. FP on Upper Kelly. Replace Upper Kelly and Test with Pass. FP on Super Choke. Flush through Super Choke and re-test with Pass. Matt Vanhoose Hilcorp North Slope LLC James Lott PBU H-21 Test Pressure (psi): mvanhoose@hilcorp.com jlott@hilcorp.com Form 10-424 (Revised 08/2022) 2024-0302_BOP_Hilcorp_Innovation_PBU_H-21 9 999 999 9 9 9 9 9 9 9 9 9 9 - 5HJJ FP FP FP FP on Inside Kill FP on Upper Kelly FP on Super Choke 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in this pool? Will perfs require a spacing exception due to property boundaries?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStratigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other Conditions of Approval: Post Initial Injection MIT Req'd?Yes No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU H-21 Tubing Swap RWO Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-071 50-029-21575-00-00 341J ADL 0028284 9961 Conductor Surface Intermediate Production Liner Liner 9180 80 2660 9117 1057 9480 20" x 30" 13-3/8" 9-5/8" 7" 8795 33 - 113 32 - 2692 31 - 9148 8904 - 9961 2450 33 - 113 32 - 2692 31 - 8521 8318 - 9180 Unknown 2670 4760 5410 9480, 9490 5380 6870 7240 9457 - 9722 L-80 29 - 89468776 - 8990 Structural 4-1/2" HES TNT Packer 5-1/2" TIW HBBP Packer 8275, 7791 8838, 8263 Date: Torin Roschinger Operations Manager Aras Worthington aras.worthington@hilcorp.com 907.564.4763 PRUDHOE BAY 3/1/2024 Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL Suspension Expiration Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 06/2023 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 4-1/2" 12.6#, 5-1/2" 17# x 4-1/2" 12.6# No SSSV Installed 324-074 By Kayla Junke at 2:11 pm, Feb 09, 2024 Digitally signed by Torin Roschinger (4662) DN: cn=Torin Roschinger (4662), ou=Users Date: 2024.02.09 13:12:54 -09'00' Torin Roschinger (4662) 2450 SFD 2/12/2024 DSR-2/13/24MGR12FEB24 BOPE test to 3000 psi. Annular to 2500 psi. 10-404 *&:JLC 2/14/2024 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.02.14 16:27:31 -06'00' RBDMS JSB 021424 RWO PBU H-21 PTD:186-071 Well Name:PBU H-21 API Number:50-029-21575-00 Current Status:Not-Operable Rig Innovation Estimated Start Date:3/1/2024 Estimated Duration:5days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker First Call Engineer:Aras Worthington Contact:907-440-7692 Current Bottom Hole Pressure:3,243 psi @ 8,800’ TVD (7.1 ppge) Max. Anticipated Surface Pressure:2,450 psi (Based on last SIWHP) Last SI WHP:2,450 psi (7/24/2023) Min ID:3.70” Cement Sheath @ 8,522’ Max Angle:38 Deg @ 9,850’ MD Brief Well Summary: H-21 produces from the Ivishak formation. The well was worked over in September of 2021 with new L-80 Vam Top tubing. In July of 2023, the well failed a TIFL and a subsequent LDL indicated six collar leaks in the tubing from ~4200’ MD to ~6850’ MD. An MIT-T failed with a LLR of 0.24bpm @ 2740 psi. A CMIT-TxIA passed to 2700 psi on 7/25/23 proving the production casing and packer have integrity. Objective: Pull the existing 4-1/2” tubing. Run new L-80 4-1/2” completion with stacker packer. Achieve a passing MIT-IA & MIT-T. Return the well to production. Well Completion Information: Wellhead: McEvoy 13-5/8” x 4-1/2” hanger. Existing Production Packer: HES TNT, 9-5/8” x 4-1/2” Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi, PPPOT-IC to 3500 psi. Slickline/Fullbore: 2. Pull 2-7/8” XX plug and Nipple reducer from 8,380’ MD. 3. Set PXN plug with extended junk catcher @ 8,380’ MD. E-line/Fullbore: 4. Cut tubing in the top of the first pup joint of tubing above the packer (~8,262’ MD). 5. Circulate well with 8.4 ppg KCl or seawater @ max rate down tubing and out IA to displace all crude from the well. LLR TxIA through the leaks is 0.24 bpm/2700 psi. 6. Freeze-protect TxIA. DHD: 7. Bleed WHP to 0 psi. Valve Shop: 8. Set and test TWC. RWO PBU H-21 PTD:186-071 RWO Procedure: 1. MIRU Workover Rig. 2. Nipple down tree and tubing head adaptor. Inspect landing threads. 3. NU BOPE configuration top down: Annular, 2-7/8”x5-1/2” VBRs, blinds and integral flow cross. 4. Test BOPE to 250psi Low/3,000psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). a. Record accumulator pre-charge pressures and chart tests. b. Notify AOGCC 24 hrs in advance of BOP test. c. Confirm test pressures per the Sundry Conditions of approval. d. Test the 2-7/8”x 5-1/2” VBRs with 4-1/2” test joint. e. Test the annular with 4-1/2” test joint. f. Submit a completed 10-424 form to the AOGCC within 5 days of BOPE test. 5. RU and pull TWC. RU lubricator if pressure is expected. 6. Rock out diesel freeze-protect. 7. MU landing joint or spear, BOLDS and pull hanger to the floor. a. Expected PU weight in 8.4ppg = 98k-lbs based on PU weight when tubing run in 2021. b. Lift threads are 4-1/2” TC-II 8. Pull 4-1/2” tubing to floor, circulate bottoms up. 9. Lay down 4-1/2” completion. Tubing hanger will be re-dressed and re-run. Tbg will be salvaged. 10. Run 4-1/2” gas lifted tubing string with stacker packer completion as detailed on tally attached. a. Torque turn connections. 11. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCl or seawater. 12. Drop ball and rod and set packer. 13. Perform MIT-T to 2,500 psi. 14. Bleed off tubing pressure to 1000 psi and MIT-IA to 2,500 psi for 30 charted minutes. 15. Bleed tubing pressure down to shear the shear out valve in the top GLM. FP Tubing and IA with diesel to 2200’ MD. 16. Set TWC. 17. ND BOPE 18. NU tree and tubing head adapter. 19. Test both tree and tubing hanger void to 500psi low/5,000psi high. 20. RDMO Workover Rig. RWO PBU H-21 PTD:186-071 Post-rig valve shop work 21. Pull TWC. Post-rig Slickline Work 22. Pull Shear-out valve, run KO GLV. 23. Pull Ball and rod and RHC profile. 24. Pull TTP. Attachments: x Wellbore Schematic x Proposed Wellbore Schematic x BOP Schematic x Existing Tbg tally x Draft Tally x Sundry Revision Change Form RWO PBU H-21 PTD:186-071 Wellbore Schematic O/C C C C C RWO PBU H-21 PTD:186-071 Proposed Wellbore Schematic 9-5/8” x 4-1/2” Packer X-Nipples (three) Gas-Lift Mandrels 4-1/2” L-80 Tubing O/C C C C C RWO PBU H-21 PTD:186-071 Innovation BOP Stack RWO PBU H-21 PTD:186-071 Existing Tbg Tally RWO PBU H-21 PTD:186-071 RWO PBU H-21 PTD:186-071 Draft Tally RWO PBU H-21 PTD:186-071 Changes to Approved Sundry Procedure Date: Subject: Sundry #: Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to the AOGCC by the “first call” engineer. AOGCC written approval of the change is required before implementing the change. Step Page Date Procedure Change HNS Prepared By (Initials) HNS Approved By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date Kaitlyn Barcelona Hilcorp North Slope, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 E-mail: kaitlyn.barcelona@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal Received By:Date: DATE: 10/13/2021 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL PBU H-21 (PTD 186-071) CBL 08/09/2021 Please include current contact information if different from above. 37' (6HW Received By: 10/13/2021 By Abby Bell at 5:24 pm, Oct 13, 2021 Operator Name:2. Development Exploratory Service 5 Permit to Drill Number:186-071 6.50-029-21575-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Well Name and Number:8. 10.Field/Pools: Well Class Before Work4. Present Well Condition Summary:11. Total Depth: measured feet feet Plugs measured feet feet Effective Depth: measured feet feet Packer measured feet feettrue vertical true vertical 9961 9480 8795 Unknown 9480 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" x 30" 33 - 113 33 - 113 Surface 2660 13-3/8" 32 - 2692 32 - 2692 5380 2670 Intermediate 9119 9-5/8" 31 - 9148 31 - 8521 6870 4760 Production Liner 1057 7" 8904 - 9961 8318 - 9180 7240 5410 Perforation Depth: Measured depth: 9457 - 9722 feet True vertical depth:8776 - 8990 feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6# x 5-1/2" 17# L80 29 - 8946 29 - 8353 8838 8263 Packers and SSSV (type, measured and true vertical depth)5-1/2" TIW HBBP Packer Liner 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 101119931257234259 Representative Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Name: Contact Email: Brodie Wages David.Wages@hilcorp.com Authorized Name:Stan Golis Authorized Title: Authorized Signature with Date:Contact Phone:907.564.5006 Treatment descriptions including volumes used and final pressure: 13. Sr. Area Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing 5 GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9180 Sundry Number or N/A if C.O. Exempt: 321-276 No SSSV Installed Junk Packer Printed and Electronic Fracture Stimulation Data 5 Operations shutdown Change Approved Program N/A Senior Pet Engineer:Senior Res. Engineer: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Suspend Perforate Other Stimulate Alter Casing Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well5 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 0028284 PBU H-21 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): Stratigraphic Other: API Number: Form 10-404 Revised 03/2020 Submit Within 30 days of Operations 458 18335 48 1997 1076 8275, 8838 7791, 8263 4-1/2" HES TNT Packer 8275 7791 By Meredith Guhl at 11:16 am, Sep 29, 2021 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.09.29 10:13:55 -08'00' Stan Golis (880) SFD 9/29/2021MGR15OCT2021DSR-9/29/21 RBDMS HEW 9/30/2021 ACTIVITY DATE SUMMARY 7/10/2021 T/I/O = SI/250/0. PPPOT-T (FAIL) PPPOT-IC (PASS) PPPOT-T: Stung into test port (0+ psi), bled void to 0 psi. Pump through void, good returns. Would not pressure passed 1000 psi. leaking by lowest neck seal into control line port and down control line. Primary packing likely ok. Attempt to function LDS, all very tight, will have to return with bigger toys. (FAIL) PPPOT-IC: Stung into test port (0+ psi), bled void to 0 psi. Pump through void, good returns. Pressure to 3500 psi lost 500 psi in 15 min. Bled pressure to 0 psi, re- energize secondary seal with plastic pack. Pressure void to 3500 psi 0 psi pressure loss after 15 min, 0 psi pressure loss after 30 min. (PASSs). Did not function LDS 7/12/2021 T/I/O = SSV/250/0. Temp = SI. Function LDS post PPPOT-T (pre RWO). No AL, well house or flow line. Stung into TBG hanger test port (0 psi). Function all LDS on the TBG hanger, all functioned freely except one is broken. Broken LDS is in the 3;00 position, it can be drilled prior to RWO or the nose can be ground off during the RWO. 7/26/2021 T/I/O = 1040/1220/0. Temp = SI. WHPs (eval high IAP). Wellhouse & flowline disconnected. T FL @ 100' (3 bbls). IA FL @ 260' (12 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 7/27/2021 T/I/O=1025/1204/5 (RWO EXPENSE) MIT-OA TO 1083 psi PASSED. Pumped 4.1 BBL's of diesel to pressure OA to 1200 psi. 1st 15 min OA loss = 78 psi, 2nd 15 min OA loss = 23 psi, for a total loss of 101 psi in 30 min (PASS). Bled OA to 90 psi (2 BBL's). CMIT-TxIA to 2714/2851 psi PASSED. Pumped 15.9 BBL's to pressure TxIA to 2863/2997 psi. 1st min T/IA loss = 104/99 psi, 2nd 15 min T/IA loss = 45/47 psi, for a total loss of 149/146 psi in 30 min (PASS). Bled TxIA back to 1060/1167 psi (5.5 BBL's). Tags hung from WV & CV's. WSL notified of results. FWHP's=1060/1167/172 8/2/2021 ***WELL SI ON ARRIVAL*** (Pre RWO) ATTEMPT TO PULL 5 1/2" EVO @ 8616' SLM (SHEARED GR) ***CONTINUE 8/3/21*** 8/3/2021 ***CONTINUED 8/3/21*** PULL 5 1/2" EVO-TRIEVE PLUG @ 8616' SLM DRIFT & TAG @ 9483' ELMD (9459' SLM) + 24' ON TAG CORRECTION (NO SAMPLE RECOVERED) SBHPS STOPS FOR 15 MINUTES PER PROGRAM 9483' MD / 8721' TVD TAG DEPTH 9457' MD / 8700' TVD 9333' MD / 8600' TVD 9215' MD / 8500' TVD ******FINAL FLUID LEVEL SEEN @ 400'**** ***WELL LEFT SI*** 8/3/2021 Cost placeholder for Arctic Lift Systems DGLV's and latches 8/9/2021 T/I/O= 490/200/20 TEMP= SI Assist Sline as directed Pump 200 bbls of crude down TBG for load Sline in control of well upon departure Pad op notified of well status. FWHP's= 2600/2500/490 SV,WV= C M= O CV's= OTG Daily Report of Well Operations PBU H-21 Daily Report of Well Operations PBU H-21 8/9/2021 **WELL S/I ON ARRIVAL** THUNDERBIRD LOADED TBG w/ 200BBLS CRUDE RAN CBL, LOGGED FROM 8910'SLM TO 6970'SLM (field interpretation shows cement in I/A up to 8475' md Stringers as high as 8455' md) SET SLIPSTOP CATCHER(SS-51) @ 8550'SLM ATTEMPTED TO PULL DMY @ ST # 2 (unable to sd) **WSR CONT ON 8/10/21** 8/10/2021 **WSR CONT'D FROM 8/9/21** PULLED RA-DGLV FROM ST # 2 PULLED EMPTY CATCHER @ 8585'SLM **WELL S/I ON DEPARTURE** 8/12/2021 T/I/O = 60/70/20. Temp = SI. TBG & IA FLs (pre Eline. No AL or flowline. Rig scaffold in place. TBG FL @ 370' (9 bbls). IA FL @ 200' (9 bbls). SV, WV, SV = C. MV = O. IA, OA = OTG. 20:45 8/13/2021 T/I/O=118/72 ASSIST SLICKLINE ( MIT-COMBO ) Pumped a total of 31.6 bbls of crude down IA for 3 failing CMIT-T/IA.(SEE LOG FOR DETAILS) *** WSR continued on 09/14/21*** 8/13/2021 ***WELL S/I ON ARRIVAL*** (rwo expense) DRIFTED w/ 4.42" BARBELL TO S/D @ 8,626' SLM. SET 5-1/2" EVOTRIEVE @ 8,607' SLM.(zeroed at bottom) top of EVO @ 8602' SLM LRS LEFT ON LOCATION FOR 3,000 psi CMIT. ***JOB COMPLETE, READY FOR E-LINE*** 8/14/2021 T/I/O = 690/740/110. Temp = SI. CMIT T x IA Failed to 3000 psi (Pre RWO). Test pressure = 3000 psi. Max applied pressure = 3155/3218 psi. TBG & IA FL's @ surface. Hardline installed for a circ out. No AL or flowline. Rig scaffolding installed. Pumped 9.3 bbls of DSL to Pressure up the TBG/IA to 3155/3218 psi. TBG & IA would not stabilize (3 tests). Established a LLR x IA of .26 gpm @ 3100 psi. Bled the TBG/IAP to 530/580 psi (10 bbls). Tag hung. AFE sign already hung. FWPs = 530/580/100. 8/14/2021 ***JOB CONTINUED FROM 12-AUG-2021*** Pumped a total of 14.15 bbls of crude for 3 failing CMIT-TxIA's. Job postponed until well stabalizes (SEE LOG FOR DETAILS). Bled T/IA to 660/706 psi recovering ~6.2 bbls. Pad-OP notified of well status upondeparture. WV/SV/SSV=C MV=O IA/OA=OTG. FWHP's=660/706/150 8/14/2021 T/I/O = 600/660/90. Temp = SI. Bleed TBG/IA to 0 psi (pre Rig). No AL. Flowline, scaffold, and wellhouse removed. Rig scafffold in place. TBG FL @ near surface and IA FL @ surface. Bled IAP to BT from 660 psi to 04 psi in 1.5 hrs, (fluid, 12.5 bbls). TBG tracked to 90 psi. Bled TBG from 90 psi to 0 psi in 20 mins, (gas). IAP went on Vac. After 30 min monitor TP & IAP unchanged. Bled OAP to BT from 50 psi to 0 psi in <2 min (gas). In 15 min OAP increased 20 psi. Bled OAP to 0 psi and maintained open bleed for 20 min. SI OA bleed and monitor for 15 min. WHPs unchanged. Final WHPs = 0/0/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:30 8/17/2021 T/I/O =-9/12/0 LRS Unit #46 CMIT-T/IA (RWO EXPENSE) Pumped a total of 21.9 bbls of crude down IA to attempt 3 CMIT-T/IA (SEE LOG FOR DETAILS) ***JOB CONTINUED ON 18-AUG-2021*** Daily Report of Well Operations PBU H-21 8/18/2021 ***WELL S/I ON ARRIVAL*** PULL 5 1/2" EVO @ 8621' SLM ATTEMPT TO BRUSH XN NIPPLE @ 8905' SLM ATTEMPT TO SET PXN PLUG @ 8905' SLM ***JOB CONT. 8/19/21*** 8/18/2021 ***JOB CONTINUED FROM 17-AUG-2021*** CMIT-T/IA PASSED to 2817/2871 psi. Max Applied pressure = 3000 psi, Target Pressure = 2750 psi. Pressured T/IA to 2851/2904 psi with 21.9 bbls of crude. CMIT-T/IA lost 18/17 psi in the 1st 15 min and 16/16 psi in the 2nd 15 min for a total loss of 34/33 psi in 30 minutes (SEE LOG FOR DETAILS). Bled T/IA to 271/361 (8.5 BBL's). Pad-Op notified of well status upon LRS departure. WV/SV/SSV=C MV=O IA/OA=OTG FWHP's=270/360/12 8/19/2021 T/I/O=100/30/0. LRS #72 Assist Slickline (RWO EXPENSE) CMIT-TxIA to 2750 psi ***FAILED*** TxIA fell below test pressure in 7 minutes on 2 attempts. 3000 psi max applied pressure. LLRT= ~0.10 bpm at 2800 psi. Pumped 24.5 bbls of 60* F crude to achieve test pressure. Pumped 4.5 bbls of crude to establish LLR. Bled back10 bbls to final T/I/O= 424/470/24. 8/19/2021 ***JOB CONT. FROM 8/18/21*** PULL 4 1/2" PXN PLUG @ 8910' SLM SET 4 1/2" EVO @ 8900' SLM, W/ HES DPU. LRS PERFORM CMIT, TEST FAILED. SET 4 1/2" JUNK CATCHER ON EVO @ 8897' SLM (LIH= 72"). ***JOB COMPLETE*** 8/20/2021 ***WELL S/I ON ARRIVAL***(pre RWO) LRS PERFORMS PASSING CMIT-TXIA TO 2750 PSI (SEE LRS WSR) LRS PERFORMS 4 BPM & 5 BPM PRE TBG PUNCH CIRCULATION PUMPING DOWN TBG TAKING IA RETURNS. DID NOT HAVE A PRESSURE DIFFERENTIAL. PUNCH HOLES FROM 8393' - 8396' ELMD. CUT TUBING WITH 3-3/8" RADIAL CUTTING TORCH AT 8406' MD. TIED INTO TUBING TALLY DATED 5-14-86 ***JOB COMPLETE / CIRC-OUT NEXT*** 8/20/2021 T/I/O= 270/330/10. LRS 72 Assist E-Line (RWO EXPENSE) CMIT-TxIA to 2750 psi. *PASSED*at 2918 psi (3000 psi max applied). T/IA lost 32/32 psi during the first 15 minutes and 16/16 psi during the second 15 minutes. Pumped 11.8 bbls of 60* F crude to achieve test pressure. Bled back 9.8 bbls to Final T/I/O= 271/330/13. Pumped 50 bpm into the TBG with IA returns to H-06 FL. No DP was observed. FWHPs=200/280/65 8/21/2021 T/I/O = 180/280/310. Temp = SI. Bleed C&B line (pre RWO). Wellhouse, flowline & AL disconnected. Rig scaffold and hardline installed. CLP = 1250 psi. BLP = 210 psi. Bled CLP to 0 psi in <1 min (gas). Held open bleed for 1 hr. Bled BLP to 0+ psi in 2 min. Monitored for 5 min (1/2 gallon fluid/gas mix). BLP increased 210 psi. Bled TP, IAP, and OAP to flowback tank to 0 psi in 1 min. Held open bleed for 1 hr. Bled BLP to 0+ psi & held open for 1 hr 30 min (3 gallon fluid/gas mix). Monitored for 30 min. CLP increased 10 psi. Bled BLP to 0 psi in 2 min (1/8 cup fluid/gas). Held open bleed for 1 hr. Monitored for 30 min. WHPs unchanged. Final WHPs = 0/0/0. CLP = 0 psi, BLP = 0 psi. SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:59 Daily Report of Well Operations PBU H-21 8/21/2021 T/I/O=720/7750/0 LRS Unit #72 (RWO EXPENSE) CMIT-TxIA to 2826 psi ***PASSED*** on the 3rd attempt. Pump 9.5 BBL's of crude down the IA to pressure TxIA to 2889/2959 psi. T/IA lost ~ 45/45 psi in 1st 15 min, and 18/17 psi in the 2nd 15 min, for a total loss of ~ 63/62 psi in 30 min. Pumped 50 BBL's of FW w/6% WR-06, 580 BBL's of 1% KCL, & 168 BBL's of diesel down the tubing while taking returns up IA to H-06 flowline. U-tube diesel freeze protect for 1 hr. FWHPs=450/450/400 8/22/2021 T/I/O=0/0/0. Set 6" CIW J TWC #419 at 135" w/ CIW lubricator. Verified 0/0 psi on 2 each control lines. ND 6-3/8" CIW tree w/ Baker actuator. ND 13-5/8" 5M McEvoy 5- seal THA. Wellhead tech function LDS to minimum OUT measurement of 4-1/16", torqued LDS and GNs to 550 ft/lbs, replaced broken LDS with blank, milled nose of LDS off to clear bowl, plugged 2 each 1/8" NPT C&B ports in hanger neck, test fit 7" IJ4S x/o 5-3/4 turns snug, removed x/o. NU 13-5/8" YJ BOP's, torque to API spec. NU 3" integral flange on IA valve, RDMO. 8/23/2021 TBird-1: New WSR for Well H-21 started at 12:01 on 8/23/2021. Job Scope TBG Swap- Continue clearing location on NK-22 and prepping equipment to be moved to H-21. Completed walkdown on NK-21, Agreed with operator to have Well support close out the work transfer. Mobilise Rig & equipment from NK-22 to H-21. Update AOGCC with estimated BOPE test timee. Spot base beam, rig modules and Rig in place. RU BOPE lines and hoses. Spot tanks.Spot pump. Spot choke and accumulator. Spot Flow back & RU hardline. RU Floor & wind walls. Take on 300 bbls of 120deg 1% KCL. Continue WSR on 8/24/2021 8/24/2021 RWO: Assist WS to pull 6¿ J plug using lubricator, MU 2-7/8¿ LJ with crossovers to 7¿ IJ4S hanger lift threads, BO tubing hanger LDS to minimum clear bowl OUT 4- 1/16¿, tighten gland nuts, pull tubing hanger to rig floor (140K up wt), rig unable to BO hanger from first joint of 5-1/2¿ tubing, LD scrap tubing hanger with full joint, RKB from tubing hanger LDS to top of cauldron is 10.72¿ 8/24/2021 T/I/O=0/0/0. RU CIW lubricator to BOP stack. RIH w/ 1 - 5' extension & pull 6" CIW J TWC #419 at 95". RDMO. 8/24/2021 TBird-1:. Job Scope TBG Swap- Cont RU Process Spot Flow back & RU hardline. RU Floor & wind walls.. Install 2-7/8 X 5-1/2" VBR's ,Conduct Shell Test. Review Spartin Rig Near Miss event with Crew. RU BOP test equipment. PT BOPE per sundry. Perform BOPE test 250psi low/3500psi high- With 4-1/2" & 5-1/2" Test joints. AOGCC witness waived by Guy Cook.Via Email. 24 notice given 8/23 at 00:42 am. RU lubricator and Pull J style plug. RD lubricator. BOLDS. Pull Hanger free with 140K, PUW, PUW-120K. Trouble shoot broken slip segement in floor slips. New slip installed. Pull and LD hanger with xo and first full joint at once. RU and circulate out diesel FP. Continue WSR on 8/25/2021 8/25/2021 TBird-1: New WSR Job Scope TBG Swap- Finish circulating out the diesel FP. RU for pulling pipe. Trouble shoot spooler. 5-1/2" pipe is very tight, having to beat on collars to get them to break out. POOH with 5-1/2" 17# L-80 tubing. Monitoring well with continuous hole fill while pulling. Lay out and talley new tubing w/ assistance from Well Sppt. Pressure test 9-5/8" casing to 3,500 psi. Lost 130 psi in the first 15 minutes (3%). Lost 60 psi the second 15 minutes. Lost 5% over entire test. OA pressure remained at 0 psi throughout test. R/U GBR torque turn equipment for running 4-1/2" completion. ***In Progress*** Daily Report of Well Operations PBU H-21 8/26/2021 Thunderbird Rig #1 CONTINUED: R/U GBR torque turn equipment, RIH w/ 4-1/2" completion. At Jt #88 displacement fluid started coming from tbg only. Found 7 of 24 control line bands were missing large rubber segments (6-1/2 x 10" and 1/2" thick) S/O Wt was notml but unable to PU. Circulated up backside @ 3 bpm @ 200 psi unrestricted. Attempt to PU again to 80K over (125k) with very slight movement. Stack 10K down w/ no movement. Attempt to circulate and reverse @ 800 psi. Jug tight. PU 200T elevators and next joint (#90) Work up and down. Have ~8" movement. Packer appears to be set and the noticeable travel correlates to internal travel if internal ratchet didn;t engage. Drop Ball and rod and confirm packer set w/ 3400 psi. RD GBR Casing. Call out AK Eline for RCT cut. Send AOGCC BOP test notice for test w/ 2-7/8" test joint. Adam Earl with AOGCC waived witness. RIH with 2.5" RCT and cut 4-1/2" tubing at 3,805' (1' above the top of the packer). POH with 4-1/2" tubing. ** IN PROGRESS** 8/26/2021 ASSIST RIG CUT TUBING AT 3805', CCL TO ME = 13.5', CCL STOP DEPTH = 3791.5' JOB COMPLETE 8/27/2021 Thunderbird Rig #1: Pulled 4-1/2" tbg from tbg cut @ 3791.2'. Measure cut Tbg pup. Cut is 1.25' above packer. Set test plug, Test VBR's to 3500 psi w/ 2-7/8" test Joint. Test Kelly valve and annular to 3000 psi. Pull test plug. MU and RIH w/ Baker Milling BHA w/ 8.5" Packer mill, (2) 7" boot baskets, 4-3/4" pump out sub, Bumper Sub, Oil Jar, 324' 3-1/2" Spiral DC's OAl - 369'. RIH on 2-7/8" PH6 DP. Tag @ 3791.7'. PU Power Swivel. ND riser and NU BIW rotating head. Mill tubing stub from 5 BPM at 1,000 psi; 1,500 ft-lbs of torque. 80 RPM. 5k-lbs down. Mill Packer at 5 BPM at 900 psi; 2,000 ft-lbs of torque. 80 RPM. 8k-lbs down. ** IN PROGRESS** 8/28/2021 Thunderbird Rig 1 CONTINUED: Continue milling packer at 3795.8': 5 BPM at 900 psi; 3,000 ft-lbs of torque. 80 RPM. 5k-lbs down. Mill through top slips of Packer to 3795.9'. Packer gives way and falls down hole. Chase Packer downhole with 2-7/8" DP. Tag top of Packer at 3,818'. Sit 12k-lbs down on Packer. Circulate 260 bbls of 1% KCL at 5 BPM at 900 psi. Break and L/D Swivel and BIW Head. POH w/ BHA #1. Normal wear on mill w/ a few metal muncher buttons missing from shoulder. MU and RIH w/ BHA #2 - 4-3/4" Spear, Bumper sub, Oil Jar, 324' 3-1/2" spiral DC's OAL 354. PU and S/O Wt 36K. Note top of fish @ 3818' then 6' of travel and set down 5k @ 3824' and packer fell. Chase in hole 120' Up Wt 37K . Discuss chasing to bttm but decide POH based on final tag depth that spear went all the way in on fish. OOH w/o packer. RBIH w/ BHA #3 w/ 8-1/2" Packer mill, (2) 7" boot baskets, 4-3/4" Pump-out sub, bumper sub, oil jar, and 324' 3-1/2" spiral DC's. OAL 369'. Tag top of Packer and sit 18k-lbs down at 8,274'. Repeat tag three times. RIH and tag top of Packer while rotating at 20 RPM while circulating at 5 BPM and 1,500 psi. Tag at 8,274' with 15k- lbs down. ** IN PROGRESS** Daily Report of Well Operations PBU H-21 8/29/2021 Thunderbird Rig 1 CONTINUED: Reverse circulate at 4 BPM at 1,000 psi. DP packs off after 55 bbls reverse circulated. See large chunks of rubber packer element in returns. Clear drill pipe blockage. Repeat tag on top of Packer at 8,274' while rotating at 20 RPM and circulating at 5 BPM and 1,500 psi. Circulate 540 bbls of 1% KCl (BU volume) at 5 BPM and 1,500 psi. L/D Swivel and BIW Head. POH with Packer Mill BHA#3 while standing back 2-7/8" drill pipe. Well Control and Evacuation Drill and AAR. LD BHA #3 and PU BHA #4 w/ Mill. Lift sub backed out of oil jar while MU spear. See details in report. Review procedure and corrective actions. Changeout power tongs. RIH w/ BHA #4. Tag at 8,256' with 10k-lbs down. Circulate at 3 BPM at 700 psi. RIH and work down to 8,258'. Pump pressure increases to 1,100 psi. Continue to work down another 5.5' and tag with 10k-lbs down (travel of Spear inside packer). POH w/ Fish. Pull 30k-lbs. over. Packer is engaged. Unable to POH however. Jar 15 times at various overpulls (30k to 50k). No movement in Fish. Continue to jar while circulating at 3 BPM and 1,100 psi at various overpulls. No movement in Fish seen. Decision made to get Burn Shoe BHA on location. Baker mobilizing BHA. Continuing to jar without pumping at various overpulls. Attempted to pull 150k-lbs several times (90k-lb overpull). No movement. M/U Swivel. Rotate and release Spear. L/D Swivel. POH w/ BHA #4 while standing back drill pipe. ** IN PROGRESS ** 8/30/2021 Thunderbird Rig 1 CONTINUED: Continue POH w/ BHA #4 while standing back drill pipe. L/D BHA #4. M/U BHA #5: 8.5" Rotary Shoe, 8.125" Washpipe Extension, 3x Boot Baskets, Bumper Sub, Oil Jar, and Drill Collars. OAL = 377.41'. Tagged fish @ 8257' PU get dry weights up/down 72k/62k started pumping 5 bpm fired up power swivel at 90 RPM/1700 psi on hydraulic system. Start working mill down to 8258' and started milling with 5k down. Mill 3' of Packer with 10k-lbs down. Unable to mill further. 0.5" of Packer body remaining. Circulate a 25 bbl high vis sweep followed by a 50 bbl sweep to clean above Packer. L/D Swivel. N/D BIW Head. N/U Riser. POH w/ BHA #5 while standing back doubles. ** IN PROGRESS** 8/31/2021 Thunderbird Rig 1...Continue WSR from 8/30/2021...: POH w/ BHA #5. L/D BHA #5. P/U BHA #6: 4.75" Spear, 4.75" Bumper Sub, 4.75" Oil Jar, XO, Accelerator, Drill Collars. RIH w/ BHA #6 to top of Packer. Tag on top of packer @ 8257' (top of packer) Difficult to get spear into packer. PU Swivel and rotated into fish. Tag @ 8263'. PU 10K over to confirm catch and RD swivel. Packer came free after 1 jar hit at 35k over. PU Wt. 3500 lbs over and fish is ~2000 lbs. TOH standing back. AOGCC (Jeff Jones) waived witnessing BOP test. L/D BHA # 6. L/D Packer and Tailpipe assembly. ...Continue WSR on 9/1/2021... 9/1/2021 Thunderbird Rig 1: Continued from 8/31/21 WSR... Break and L/D Tailpipe assembly. Set Test Plug. Test BOPE to 250 psi low/ 3,500 psi high. Test Annular to 250psi/2,500 psi. Pull Test Plug. Test Casing - Pass. Test Hyd choke to verify funtionaility for Well Control - Pass. LD DC's in derrick. Completion Equipment cleaned, drifted, and overshot repinned @ Tool Service and returned. M/U BHA #7: 8.5" Dress Off Shoe, 3x Extensions, Extreme Magnet, Bumper Sub, Oil Jar, (OAL = 56.18'). RIH w/ BHA #7 on 2-7/8" PH6 Drill Pipe from the Derrick. Tripping speed is slowed by displacement coming out of drill pipe. Continued on 9/1/21 WSR... Daily Report of Well Operations PBU H-21 9/2/2021 Thunderbird Rig 1: ... Continued from 9/1/21 WSR. Continue to RIH w/ BHA #7 and tag at 8,380'. P/U a 6' and an 8' 2-7/8" pup Joint and M/U to Swivel. M/U BIW Head. RIH and tag at 8,380'. P/U 5' to 8,375'. Begin to rotate and circulate at 3 BPM at 400 psi. Free spin torque is 800 ft-lbs. RIH to 8,380' and begin to dress off tubing stub at 60 RPM. Maximum torque seen is 1,400 ft-lbs. Work dress off mill down 16' until it bottoms out at 8,396'. POH to above tubing stub. Increase rate to 5 BPM at 1,000 psi. RBIH and dress off tubing stub again at 60 rpm. Work dress off mill down 16' until it bottoms out at 8,396'. Max torque seen is 2,500 ft lbs. POH to above tubing stub at 8,375'. Reverse circulate 600 bbls of 1% KCl at 5 BPM and 800 psi. LD power swivel. ND BIW head and NU riser, TOH laying down 2-7/8" DP, . OOH @ 14:30. Magnets full of cuttings and some in boot basket. Normal wear on shoe and mill. Prep floor and pipe racks, RU GBR. Run 4-1/2" VAM L-80 competion... Continued on 9/3/21 WSR... 9/3/2021 Thunderbird Rig 1: ... Continued from 9/2/21 WSR. Wait on wind to subside. RIH w/ 4- 1/2" 12.6# Vam Top completion. *** IN PROGRESS *** Stop due to high winds from Midnight to 04:00. Blocks swinging enough to hit derrick and causing bad torque-turn connections. Continue slowly running completion in windy conditions. Note both set of pins in NS Solutions Overshot shear @ ~8-10k Lbs. Tag @ 8398.5' - 13.6' overshot reach = 8384.9' tob of tbg stub. Space out. Add 2.3' pup. Landed hanger w/ overshot 4' off no-go . Bttm of overshot landed @ 8394'. RILDS. RD GBR. Reverse in 180 bbls 1% KCL w/ Corr inhibitor 1% Baracor 100 and .1% Oxygon 4 bpm @ 300 psi. Reverse in 280 bbls of 1% KCL at 4 bpm @ 300 psi. Drop Ball and Rod. (OAL = 6.6', 1.375" fishing neck). Pressure up on Tubing to 500 psi for 5 minutes and check for bleed off. No bleed off. Pressure up on Tubing to 3,500 psi. See intial Packer setting at 2,000 psi. Packer completely set at 3,100 psi. MIT-T to 3,500 for 30 charted minutes. PASS. MIT-IA to 3,500 psi for 30 charted minutes. PASS. Bleed Tubing to 0 psi and shear DCR. Set TWC. T/I/O = 0/0/0 psi. *** JOB COMPLETE *** 9/3/2021 M/U Landing Joint to TBG HGR (4 1/2" TC-II). M/U TBG HGR to string, RIH, land TBG HGR at RKB of 10.7'. Verify landed throug IA valve (verification mark on pup joint below TBG HGR). Run in LDS and torque to 550 ft lbs. Torque gland nuts. Stand by for set packer/tubing test. Set 4" HTWC w/ dry rod. 9/4/2021 Stage tools and equipment, stand by for Yellowjacket to open blind rams. Assist in N/D of BOP, clean void, inspect TBG HGR neck and lift threads. Install new DX seal and BX160. N/U THA, fill void w/ test oil, rig up test equipment. Test void to to 5M for 30 minutes. After first 15 min, loss of 200 psi. After final 15 min 0 loss. Good test. Bleed off test pressure, stow tools and equipment. Stand by for tree N/U and shell test. Retreive 4" HTWC w/ dry rod. 9/5/2021 Circ in Freeze Protect Post Rig Job (RWO EXPENSE) Pumped 5 bbls 60/40 meth, 225 bbls 110* DSL and 5 bbls 60/40 meth down IA, taking returns from Tbg to open top tank. U-Tubed freeze protect into Tbg for 1 hour. Pad Op notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG 9/5/2021 T/I/O=0/0/0. Post Thunderbird. ND BOP's, NU 13 5/8"x 4 1/8" McEvoy Tubing Head Adapter. Torqued flange to API spec. Wellhead Tech performed PPPOT on THA to 5000 psi for 30 min. Passed. NU 4 1/16" Cameron Tree witrh SH 3000 actuator, torqued flanges to API spec. Install tree work platforms. PT tree aginst TWC to 5000psi. Passed. Wellhead Tech pulled 4" "H" TWC with dryrod. Installed production flowline and GLT piping. Torqued to ANSI spec. Installed wellhouse, floor, backing. Job Complete. Final WHP's 0/0/0. Daily Report of Well Operations PBU H-21 9/5/2021 ***WELL S/I ON ARRIVAL***(post rig) PULLED BALL & ROD FROM 8,380' MD. MADE 3 ATTEMPTS TO PULL ST# 3 @ 5,262' MD. (friction bite first run) PULLED RKP-DCR FROM ST# 4 @ 3,232' MD. RATTLED MANDRELS TO RHC @ 8,380' MD. RAN 1.75" LIB TO ST# 3 @ 5,262' MD. (valve partially out of pocket) ATTEMPTED TO PULL ST# 3 @ 5,262' MD. RAN PINNED RK-1 TO ST# 3 @ 5,262' MD. (sheared) ***WSR CONTINUED ON 9/6/21*** 9/6/2021 ***WSR CONTINUED FROM 9/5/21*** (post rig) MADE NUMEROUS RUNS W/ VARIOUS PULLING TOOLS & LIBS TO ST#3 @ 5,262' MD PULLED RK-DGLV FROM ST#3 @ 5,262' MD W/ 1-5/8" GUTTED JD W/ SPOON SKIRT SET RK-GLV IN ST# 4 @ 3,232' MD. RAN POCKET BRUSH TO ST# 3 @ 5,262' MD. SET RK-OGLV IN ST# 3 @ 5,262' MD. PULLED 4-1/2" RHC FROM X-NIP @ 8,380' MD. RAN 10' x 2-1/2" P-BLR TO 8,875' SLM. (full blr of solids) ***WSR CONTINUED ON 9/7/21*** 9/7/2021 ***WSR CONTINUED FROM 9/6/21*** (post rig) BAILED FROM 8,876' SLM TO 8,892' SLM. (~15 gallons of solids, big chunks of rubber, some metal & part of 1 slip) RAN 3.50" MAGNET w/ NO RECOVERY. ATTEMPTED TO LATCH 4-1/2" JUNK CATCHER @ 8,892' SLM. RAN WIRE SPEAR TO MOVE DEBRIS ON TOP OF JUNK CATCHER @ 8,892' SLM. RAN 2-1/2" HYDROSTATIC BLR w/ 3.65" DREAM CATCHER TO 8,892' SLM. (~1 gallon solids, metal marks) RAN 3.50" LIB TO 8,892' SLM. (slip across face) ***WSR CONTINUED ON 9/8/21*** 9/8/2021 ***WSR CONTINUED FROM 9/7/21*** (post rig) RAN VARIOUS BAILERS, BOX TAPS AND WIRE GRAPS TO FREE UP SLIP @ 8,893' SLM. (see log for details) RAN 3.50" MAGNET TO 8,893' SLM. (recovered packer slip) PULLED 4-1/2" HES JUNK CATCHER FROM 8,893' SLM. PULLED 4-1/2" EVOTRIEVE FROM 8,903' SLM. (recovered packer slip) ***WSR CONTINUED ON 9/9/21*** 9/9/2021 ***WSR CONTINUED FROM 9/8/21*** (post rig) POLLARD UNIT #58 RIGGED DOWN ***JOB COMPLETE, WELL LEFT S/I*** Operator Name:2. Exploratory Development Service 5 Permit to Drill Number:186-071 6.API Number:50-029-21575-00-00 PRUDHOE BAY, PRUDHOE OIL Hilcorp North Slope, LLC 5. Field/Pools:9. Well Name and Number: ADL 028284 Property Designation (Lease Number):10. 341H 8. PBU H-21 7.If perforating: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Stratigraphic Current Well Class:4. Type of Request:1.Abandon Plug Perforations Fracture Stimulate Repair Well 5 Operations shutdown Op Shutdown GAS GSTOR WAG SPLUG Abandoned Oil 5 WINJ Exploratory Development 5Stratigraphic Service WDSPL 12. Attachments: PRESENT WELL CONDITION SUMMARY 9961 Effective Depth MD: L80 11. 5/1/2021 Commission Representative: 15. Suspended Contact Name: Brodie Wages Contact Email: David.Wages@hilcorp.com Authorized Name: Stan Golis Authorized Title:Sr. Area Operations Manager Authorized Signature: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Yes No Spacing Exception Required?Subsequent Form Required: Approved by:COMMISSIONER APPROVED BYTHE COMMISSION Date: OtherAlter Casing Pull Tubing Conditions of approval: Notify Commission so that a representative may witness Sundry Number: COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Detailed Operations Program Packers and SSSV Type: No SSSV Installed Packers and SSSV MD (ft) and TVD (ft): Perforation Depth MD (ft):Tubing Size: Size Total Depth MD (ft):Total Depth TVD(ft): 9180 Effective Depth TVD:Plugs (MD):Junk (MD): Other Stimulate Re-enter Susp Well Suspend Plug for Redrill Perforate Perforate New Pool 8838, 8263 No SSSV Installed Date: Liner Well Status after proposed work: 16. Verbal Approval: 5 Change Approved Program 32 - 2692 32 - 2692 14. Estimated Date for Commencing Operations: BOP Sketch 33 - 113 Structural 6870 Proposal Summary 13. Well Class after proposed work: 5-1/2" TIW HBBP Packer 9457 - 9722 8776 - 8990 5-1/2" 17# x 4-1/2" 12.6#29 - 8946 Production Liner 9480 8795 9480 Unknown 33 - 113 13-3/8" 9-5/8" Contact Phone:907.564.5006 Date: 4760 80 20" x 30"Conductor 2670 GINJ 5 Post Initial Injection MIT Req'd? Yes No 5 5 Comm. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Surface 2660 5380 Intermediate 9119 29 - 9148 29 - 8521 1057 7"8904 - 9961 8318 - 9180 7240 5410 Address:3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 3. No 5Yes Casing Length MD TVD Burst Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft): Collapse MPSP (psi): Wellbore Schematic 2358 Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 03/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 8:40 pm, Jun 02, 2021 321-276 Digitally signed by Stan Golis (880) DN: cn=Stan Golis (880), ou=Users Date: 2021.06.02 15:18:25 -08'00' Stan Golis (880) MGR04JUN21 DSR-6/3/21 0 BOPE test to 3500 psi. Annular to 2500 psi. DLB DLB06/03/2021 2358 Revised date 09/01/2021 per Hilcorp. DLB 10-404X dts 6/7/2021 JLC 6/7/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.06.07 10:10:26 -08'00' RBDMS HEW 6/7/2021 H-21 Integrity RWO Well: H-21 PTD:186-071 Well Name:H-21 API Number:50-029-21575-00 Current Status:Shut-in, Not Operable AFE Estimated Start Date:May 2021 Estimated Duration:4 Days Reg.Approval Req’std?Date Reg. Approval Rec’vd: Regulatory Contact:Abbie Barker 564-4915 First Call Engineer:Brodie Wages (907) 564-5006 (O)(713) 380-9836 (M) Reservoir Engineer:Laurie Derrick (907) 564 5279 (O)(720) 308-3386 (M) Current Bottom Hole Pressure:3228 psi @ 8700’ TVD 7.5 ppg | 2009 SBHP + Safety Max. Anticipated Surface Pressure:2358 psi 0.1 psi/ft gas to surface Last SI WHP:750 psi Taken 5/10/2021 Min ID:3.125” @ 2044’ 5-1/2” SSSV Max Angle:77.3 deg @ 11,290’ MD Objective:Restore tubing integrity and return the well to production from the Ivishak. Brief Well History: H-21 is a GDWFI slant well that was drilled in 1986. The well has been a full-time producer and has cum’d 10.1 MMBO, 25.2 MMBW, 126 BCF gas. Originally, the entire column from zone 2C through zone 4A was perforated. The well was a full-time producer until 2003 when it was Shut-in for a packer leak. The well remained shut-in until 2009 when a packer cement squeeze restored integrity. A saturation log & PPROF in 2014 showed oil saturation in upper Z4A so in 2015 an IBP plug was set over the lower perfs which were hitting MGOR and 15’ of Z4A were added. This work shut off 100% of the water, 3 mmscfd formation gas and increased oil by 150 bopd. In May 2017, the IBP plug failed and moved uphole. It was retrieved and a Posiset plug with cement cap was installed. The well has produced full time since with minimal production fluctuation except for opening the choke in October 2018 which increased the gas rate ~ 8 mmscfd without much GOR acceleration. In May 2020 the well started showing signs of TxIA communication. It failed a pressure test. A Leak detect log ID’d multiple tubing leaks and a caliper confirmed the tubing is corroded with 68% max penetrations. The well needs a RWO to return to service. Surface Infrastructure: H-21 has access to the GC1 Annex via the 47H header, GC2 HP via the 42H header and GC2 LP access via the 46H header. The H-pad headers are not velocity constrained at this time. Notes Regarding Wellbore Condition: > 08/23/20: LDL ID Leaks at 6899' & 7207' MD > 05/26/20: Set Evotrieve MIT-T Failed LLR 1.3 BPM @ 2600 psi CMIT-TxIA Passed to 2500 psi > 05/25/20: Set DGLVs > 05/25/20: Caliper ran from 8846'MD to surface. 68 jts 0-20% penetration. 80 jts 20-40% penetration. 78 jts 40-85% penetration. Max pen 68%. > 10/01/15: MIT-T Passed to 3000 psi After 2009 packer squeeze, when heading in to mill out cement in the tubing, coil tagged TOC @ 8721’. Two bbls of cement pumped into the IA puts the TOC in the IA @ 8774’ -00 DLB H-21 Integrity RWO Well: H-21 PTD:186-071 Volumetrically, based on dry tag after cement job, we only got 1.4 bbls of cement into the IA (32’ of cement). A tubing cut at ~8500; gives us ~274’ of room to ensure we do not try and cut into cement We will be unable to wash over the current production packer and cement due to the overshot used in the initial completion Procedure: DHD – MIT OA – 1200 psi CMIT-TxIA to 3,500-psi, run eline LDL if failing. Cycle LDS PPPOT-T PPPOT-IC SL – Drift, pull DSSSV nipple, pull Evo, drift and tag cement top, run memory CBL to find cement top in tubing x casing annulus, attempt to set plug in X nipple in tubing tail EL – Shoot string shot near cement top, cut tubing above cement Load hole with KWF, CMIT-TxIA to 3,500 psi, LDL if necessary DHD – Bleed WHP’s to 0 Valve Shop – Set and test TWC Nipple Down Tree and tubing head adapter. Inspect lift threads. Tubing barriers: KWF and TWC Casing barriers: Production packer and tubing hanger NU BOPE configured top down, Annular, 4-1/2” x 5-1/2” VBRs, Blinds and integral flow cross. Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. Test BOPE to 250psi Low/3,500psi High, annular to 250psi Low/2,500psi High (hold each ram/valve and test for 5-min). Record accumulator pre-charge pressures and chart tests. A. Perform Test per Thunderbird #1 BOP test procedure. B. Notify AOGCC 24 hrs in advance of BOP test. C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8” x 5-1/2” VBR’s with 4-1/2” and 5-1/2” test joints. Test the Annular preventer with a 4-1/2” test joint. E. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. Pull TWC. 4. MU landing joint or spear 5. BOLDS and pull hanger to the floor. a. PU weights are expected to be ~130K b. 5-1/2” 17# L80 yield: 397k# 6. Circ out diesel freeze protect 7. Pull 5-1/2” tubing to floor, circulate bottoms up. 8. Run 4 ½” L80 tubing per proposed schematic/tally. 9. Land Hanger and reverse in corrosion inhibited 8.4ppg 1%KCl 10. Drop ball and rod and set packer with 3,500psi pump pressure. 11. Perform MIT-T to 3,500 psi and MIT-IA to 3,500 psi for 30 charted minutes. Assure well is dead. expected TOC in tubing at 8522' MD /possible (if able to set plug) H-21 Integrity RWO Well: H-21 PTD:186-071 12. Shear valve in upper GLM. 13. Set TWC 14. Rig down Thunderbird #1. Post rig valve shop work 1. ND BOPE 2. NU tree and tubing head adapter. 3. Test both tree and tubing hanger void to 500psi low/5,000psi high. 4. Pull TWC and freeze protect to ~2,000ft with diesel. Post rig Slickline Work 1. Pull Ball and rod and RHC profile 2. Set GLV’s per GL Engineer 3. Pull PX plug set in tubing tail 4. RDMO & pop well Additional Post Rig Work: 1. Schedule SVS testing with AOGCC per regs Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing (if one was set) H-21 Integrity RWO Well: H-21 PTD:186-071 Current WBS: H-21 Integrity RWO Well: H-21 PTD:186-071 Proposed WBS: H-21 Integrity RWO Well: H-21 PTD:186-071 BOP Schematic: Hilcorp North Slope, LLCHilcorp North Slope, LLCChanges to Approved Rig Work Over Sundry ProcedureDate: May 12, 2021Subject: Changes to Approved Sundry Procedure for Well H-21Sundry #:Any modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “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 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMIS• • REPORT OF SUNDRY WELL OPERATIONS FEB 0 1 2018 1. Operations Performed Abandon 0 Plug Perforations MFracture Stimulate 0 Pull Tubing 0 Operations 0 n Cvv❑ Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Set Plug w/Cement Cap I3 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 186-071 3. Address: P.O.Box 196612 Anchorage, Development LZ Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21575-00-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PBU H-21 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9961 feet Plugs measured 9480 feet true vertical 9180 feet Junk measured 9566/9649 feet Effective Depth: measured 9480 feet Packer measured 8840 feet true vertical 8795 feet Packer true vertical 8264 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 33-113 33-113 Surface 2663 13-3/8" 32-2696 32-2696 5380 2670 Intermediate 9119 9-5/8" 31-9149 31-8523 6870 4760 Production Liner 1064 7" 8883-9947 8300-9169 7240/8160 5410/7020 Perforation Depth: Measured depth: 9457-9722 feet True vertical depth: 8776-8990 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"x4-1/2",L-80 28-8948 28-8354 Packers and SSSV(type,measured and 5-1/2"TIW HBBP Packer 8840 8264 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): NNED li'+t-i ( £,, 0 i' i`; 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: 523 21653 328 1369 1761 Subsequent to operation: 493 19358 0 788 1805 14.Attachments:(required per 20 AAC 25.07025.071,&25.283) 15.Well Class after work: Daily Report of Well Operations El Exploratory 0 Development II Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Shriver,Tyson Contact Name: Shriver,Tyson Authorized Title: Well Intervention Engineer / �j Contact Email: Tyson.Shriver@bp.com Authorized Signature: 5 �� � Date:l f j/iO Contact Phone: +1 9075644133 Form 10-404 Revised 04/2017 /' 7z ,iY 3�� O RB DMS LI. FEB - 2 2018 �///A�'l// Submit Original Only Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary January 31, 2018 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Setting of a Posiset Plug with a Cement Cap for Well H-21, PTD # 186-071. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska) , Inc. P.O. Box 196612 Anchorage, AK 99519-6612 . • • Q 'o U) c 0 - c 0) 0 - co C to p +-. Cc)rua) co 0_ Q E a) Q co co N c L _c a) U N "a O 0 u) 3 r) Q 0_ N N Y C to E17, © _c 0 . _ L C 2 E 0) -0 o Q) C 0) -0 _L., U) ..J. CO a) r C L 0 C cn O 06 2 0 (I) o� N o Z •(7 J rn OL w 0_.c • O a) M a) O o - Q 0 w C.) 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D=4892H8823' 9= 1 ,,.4 '-'1- ***. N**••: 8838' --1 9-5/8"X 5-1/2"71W FEBP PKR 0=4.75- 4, A• 8843' —1MILLOUT EXTENSION 8849' 5-1/2"X 4-1/2°xo I 1 _ 8881' 1H4-112'OTIS X NP,ID=3.813" [TOP OF 7"LNR i---L 8904' l• 1 _I 4 ir j 8918' --14-1/2"011S XN MP,0=3125- I $ • . [4-1/2'TA LPIPE, 12.6#,L-80,.0152 bpf,0=3.958:J—I 8946' j--- . , 1 8946' H4-1/2*BKR7BG TAL,D=3.958" \ _ L 8942'_1-1E_MD TT LOGGED 09/25/94 [9-5/8"CSG,47#,L-80,D=8.681" 1--I 9147' —411 hi PERFORATION SUMMARY REF LOG: GEARHART-BHCS 05/12/86 9212' J---I MARKER JONI'i ANGLEAT TOP PERF: 35°qi 9457' Note:Refer b Production DB for hisbrical perf data SIZE SPF INTERVAL Opn/Sgz DATE 9480'ELM 1---LEST TOC(01/11/18)I 2-7/8" 6 9457-9472 0 10/15/15 .44.4.•,•,•.4.14 --.w-- 3-3/8' 6 9476-9481 S 01/20/94 9490'ELM —12-1/8"SLB POSISET PLUG(01/10/18)j 3-3/8" 6 9490-9506 S 01/20/94 3-3/8" 6 9516-9526 C 04/12/94 Ilk I FISH: 1'X 9'UPPER VALVE SLV FROM BP, 3-3/8" 12 9526-9536 C 01/23/94 I A SSTD SMALL DEBRIS FROM BP 01/24/17) 3-3/8" 6 9540-9550 C 01/25/94 3-3/8' 6 9565-9575 S 01/20/94 Ilk L —9649' RASH-.2 BKR FASORLL c8Ps,1 2-7/8" 6 9585-9593 C 07/02/14 3-3/8" 6 9585-9606 S 01/20/94 2-7/8" 4 9680-9722 S 01/20/94 P1370 —I 9919' ........4 /.././.. .1•1****4 WAWA. 7"UR,29#,L-80,.0371 bpf ID=6.184" [—I 9961' DATE REV BY COMIVENTS DATE REV BY COIVMENTS PRUDHOE BAY UNIT 05/16/86 ORIGINAL COMPLETION 11/10/15 JTGIJIYI3 DUMP SLUGGITS(10/21/15) WELL H-21 07/16/14 ATO/AD ADRRFS(07/02/14) 11/27/17 JMG/JMD RLL DSSSV/BP,BAIL SLUGGITS,FISH PERA4T No:'1860710 07/17/15 RKT/JIVD SET DSSSV(05/06/12) 01/03/17 BSEIJMD CORRECTION TO SSSV NP AF1 No: 50-029-21575-00 11/10/15 R.NQJMD GLV 00(10/21/15) 01/15/18 EITNJNO SET PLUG&CMT(01/11/18) SEC 21,T11N,R13E,534'FNL&1266'FEL 11/10/15 STF/JMD A DFERFS/SET FLUG(10/15-16/1f 01/22/18 DG/JM) SET DSSSV(01/18/18) BP Exploration(Alaska) 11/10/15 JTG/Jk/13 RESET DSSSV(10/21/15) STATE OF ALASKA , • ALASKA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS Nf V 19 2015 1. Operations Performed Abandon 0 Plug Perforations Et Fracture Stimulate ❑ Pull Tubing 0 OperVp s 0 Suspend 0 Perforate IZI Other Stimulate 0 Alter Casing 0 Charti°g�ei proved rogram 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: Se-f /SP EV 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 186-071 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21575-00-00 7. Property Designation(Lease Number): ADL 0028284 8. Well Name and Number: PBU H-21 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 9961 feet Plugs measured 9485 feet true vertical 9180 feet Junk measured 9649 feet Effective Depth: measured 9475 feet Packer measured 884o feet true vertical 8791 feet Packer true vertical 8264 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 33-113 33-113 0 0 Surface 2663 13-3/8"72#L-80 32-2696 32-2696 4930 2670 Intermediate 9119 9-5/8"47#L-80 31 -9149 31 -8523 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet 2 9 n 6 L SCANNE Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 5-1/2"TIW HBBP Packer 8840 8264.47 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 570 42648 2136 1860 1667 Subsequent to operation: 745 4184 692 1360 673 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory 0 Development II Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil El Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature �, Phone +1 907 564 4424 Date 11/17/15 Form 10-404 Revised 5/2015 y77_ jZ/2/G RBDM8 NOV 2 0 2015 Submit Original Only • • m Q. 000000 to O N 00 O O N LO C N V CC) I"- CD I— U O O O O O O 3 01 CO N r- m Nt CO 00 I- co MC.oMI- OCAv O N O CO CO CO CO to N CO N CO O) 6) CO 00 • 1 1 1 1 1 1 1 I— O I- O) M N N- 0 0 CO CO C'7 CO C7 CO ,- N N CO O CO CD Ch COO O I- Cf) 00 cy)CO CO CA CO CD N CA CA C)) CO CO ✓ p - ++ r Q NcON CO C9 CM I CO CO CO CO CO N CO CO 01 CO W OCO O coC J _1 00 00 CO J • y CO N *k N N X *k *k N N (00 - N C N rn L O O CO c- CD CO C CO CO c- O N- CO O d N O 0) co N- W I O• W 0 U tO U O u D a a Z Z Z rxW W W m m O p l- Z_ Z_ D D • Z J J I- I- • a) 0 Ea CO C N MCO CO • CO O O cd Ln N c0 O co co O a)p N- a) cO co a) co co co a) ❑ co co co c0 a) a) co a) a) H 0 co co V co CO N CA Ln Ln 0) .c •st a) N N co a) CO CO CA CO CO Q CO M V N 0 M M o M CO 0 N N- o O N CO CO (0 V-- a) L0 LU ❑ I� N- CO CO CO CO CO CO CO CO 0) > ❑ a) co a) a) a) a) a) a) a) a) a) 0 > 2 H W lY ❑ ❑ ❑ wz W W 0O w 0 J d W ggY oO o N r CO CO cr Cfl O co co In N J J J a s W W ++ p N- a) o N co co co N- C)) O N a a < w L1 0_ z a) '' V 10 Ln Ln Ln Ln Ln Ln CO N- 0 0 0 J W W J ❑ C)) O) O) O) O) O) C7) O) n) O) O) O J J J ❑ Ch z z Z ❑ ❑ w CD M of 0 0 0 W Z Q Z w w w d H H < J < (fir Ocncncnu) rn CU < = o 0 H M « N- Co co co co O Ln Ln CO O M 0- Ln I- O) .- N co d' Co a) O) a) O W a) v - co co co co co co co Co a ❑ O) n) O) O) O) O) O) n) O) O) co CU co — a) LYU) -1 HHaJa 2 O co co co co up G) a 0 0 C) c LL_ d U) U) U) U) U) U) U) U) U) �aaaaaaaa0 0 0 0 < mmmmmmmmmm a O a) a) a • Ln ,n Ln Ln Ln Ln Ln Lc) Ln Lc) Ln 0 ❑ O 0 0 O O Co 0 0 0 0 0 z O N N N N N N N N N N z w a W ncococococococococo O w ❑ J N w ❑ W ❑ W LY a 0 c 0 0 0 0 0 0 0 0 0 z J C) w w w p m 0 D W J J ❑ w W a a d Ln U LL Lai 0 a ct ar E to z z N N N N N N N N N N N m a a (/) O J 0 N0 w Li 22222222222 a a m m LL Li cn cn Q ct • • ce f / 2 \ / \ 2 / E' y \ CO / 0) 22 / \ 0) y) 2 / 2 \ E < Lo ® / 2f ID `- < k 0 ® '6 2 / / a o p - \ k / _ § 0 / @ 7 _ w10 0 o U A a — E 0. 0 2 W AO N = one = o ® I = U)- 0 -/ k/ \ C $ _I k= a 22 [ = a $"� m / - < -1 q = o o - c < % 0 o ri / § 0 y 0 / 2 ƒ k - \ \ � S / a < co E E _ ¥ . = R 2 co / a / $ o 0 _ �.c 4 0 ii. 2 / / .\ t / 0 % \ \ 9 - _ ƒ O _ � p / f wk 2 \ / 2 \ 2 � / / \ E / A2 % / 32.1- -I / / / \ Z & / J // H \ 45 E ƒ\ / f t \ / / @ / $ %/ / ® t : C = gw t 0- f / O2 t § \ / g - � p/ / ak k / kJ \ / � 7 / � / 4 ƒ / si 0 / \ (1 0 e / LLE ® / / / / \ f ) n (Ni 900CD ® N- 2 7 � � / h / / � �$ / / \ @ / R < y 7 / / / / / ƒ / � / ƒ ,- � � c0 ® � 0 � >U / � � $ 9 � � = m � / CC = ct ._ ct > $ % 2 2v- 2 p$ m 2 a E 7 o $ $ < E \ CU I E E / < / —1 � E R : / / / E E \ / / / / % / 0 0 6 $ NI: / < o0 � Z / = E ƒ / mac i � � ? 2 = = r ^ G - Eg2m / Z Z Z 10 ,00u_ m ± 8 ;113- 21 - 0 ' m ° 613) 1_1_ _I- com0 00 \ 27 2 u E y ƒ » § oo ± y 22E7 & E2EL / O L - 04100 2 = r = r > U U2 � � Rm © = OOeR = 6 2 < _ R Z / .E O c / x % 2 G - E G / 0 32 \ m - R / > / / 2 Z \ o z O \ 0 \ § / E , p 9 z ± f 11 \ z E / k k ua ± g i / g -i g I & 7 0 .E ° / O a L O $ H.> a a m G / = U u)--, R 2 z - g R ,L0 z = 2 U E 5 (DE c O .- O 2 m R O - u s s ± - - - » 2D * 0 - 0 = a : _ ± D R : : w I a. _1 : & 2 : _1 m I c _1 m 2 ct � 2 : 0 2 < 0 G et ± i E < * L < r o r m to r »0 / \ / \ \ / I- 5 \ \ CO CO / / / a & a 0) a) a < • • (00 o cum t 0 rn I- ,n o Q 0 0 45 N C N Z CO CD CO N N- n a) -:-1: O 0 3 M - E Q a) Y C ce) U o c'') W N a d cu r - 7 j E II Q a) Q � °° • N a) a Z . a i- u_ *� Q� pp � Q a v = w0 W co � o � N a; 0 Li CO D - Z c Dooi o_•N > 0 i) O • LL. i- _I 0 = Q o aiN o 0) rb CD IT E w o LL rn* J 1- z r rn r ID Cl) 's`a— ww a v� ��U`` C o in Qco J N 1 > - "C H O V F O N a) U- © C a) O N co 0 N 0 J O "° p Z O C Q (n CD D N > N) > Q N ccor 0 -0 o EI- J _ II S 0_ a) C w1.- co o w c°o0 .- - * Q C w � 0 J o E .'v> ICU.- C 'C ~ -I C N Q In p w (n _ on _ m _ a) a) Q Z C C O Z a) O U r * co Q r 0 ~ c0 - Z J O C a o_ * CO Z * i t 0 O d Z �[ U C d - a) 0 a • �) (u O� r L.L.J * w Q d N 2CO 0 wU .� oU 2O 2mca P � N WA (C9 >< w * a) U) a) _ * Wiz .-.� �, �' *, * coJ � - °' a a .� 0 < craw Q� p 1 I2 X04 c% 6)* Win TO (7)u) _0m -p2 2 II o 0 0 * cou) ocn * Q c � mr OorxQoI- cnco ai .cnQwLL ICU) * C > 2 .a) Jam * * "° . 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Opa Y � Q * E eco Cfl �n - t0wM ❑ w = O J N O m O a Ln O O Q NJ <- � U W O N Qv Nal 2 Qd- WN a y- M „- YH CCI' W = a N ;- * oric�i �# O O U ❑ 7Z 0 1 o * U o * F- = O W a0 ❑ ¢ ZY � J ~ Q in F- f ‘4t � cnU = Zcn too J ❑ U �- * � � c) * Iz '-o D O (c) Q W QQ ( Z W < O * OCU *kms * O - Q C) 0QQ � W II ) a > LLI = Q N � -I U) 22uN_ N_ tZ N a A � --J - IUWF- D OE NLu '- - X00 °0-N � ❑_ c> 0 p ❑w � 0 � °° ❑ � IQ J3 0Qa0O .- °Du_ u_ c�oc) 21- = c�n z � cn ❑ CC CL LnJ F- ZDZw ❑ U? � i 6348"ACEVOY •WELLFfAD= A.CEVOY H -2 1 21 NOTES: •CTUATOR= OTIS OKB.ELEV= 76.51' BF ELEV= 47.51' KOP- __. .. 5050' 2044' —5-1/2'OTIS SSSV LAND NIP.ID=4,562' 'I Max Angle= 38°@ 9850' • 2044' —5-1/2'DSSSV,D=3.11"(10/21/15) Datum MD= 9581' Datum TVD= 8800 SSI GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3019 3019 0 OTIS DOME RM 16 10/21/15 13-3/8'CSG,72#,L-80,D= 12.347" — 2692' 1 4 5316 5305 21 OTIS SO RM 20 10/21/15 3 7259 6943 37 OTIS DMY RM 0 08/31/04 2 8495 7975 32 OTIS DIM' RM 0 01/02/92 /Y44 a:= 1 8692 8141 33 OTIS 'DMY RM 0 02/08/09 Minimum ID =3.125" @ 2044' :67 pi 'STA#1 =❑IM Bt3r�Cl3�TrsHEATH 5-1/2" DSSSV .i1i ►1i 8763' —5-1/2'OTIS XA SLIDING SLV,ID=4.562' TOP OF CEMENT SHEATH,ID=3.70' — VW '41'4 •1.141�11 4 8622' V 878$' HTOP OF LA CMT PLUG( J 1111 114 I. 0 8820'-8822' —TUBING PUNCH(02/06109) J 1111 14r.4• 11'111 N ,,lOr 5-1/2'TBG, 174. L-80,.0232 bpf,ID=4.892- —J 8823'_ A1�1c�11411!'`14 8823' HTAW OVERSHOT SEAL ASSY .4.11 ..1r: 8838 1--19-5/8'X 5-1/7 TAW HBBP PKR,ID=4.75' 1I 8843' —MILLOUT EXTENSION 1 • 1 8848' JH5-117 x 4-1/7 XO _a. I. 8881' H4-1/2 OTIS X NP,ID=3.813' I TOP OF 7'1.14R — 8904• 1 F,1 I li / - 1 • I. Y , $916' —4-1/2'OTIS XN NP,ID=3.725' 41 4-1/2'TAIPPE, 12.64,L-80,.0152 bpf, ID=3.958' — 8946' I 8946' 1-4-1/7 BKR TBG TAIL ID=1958" 8942' -ELMD IT LOGGED 09/25/94 9-5/8'CSG,474, L-80,ID=8.681' H 914T HA ' MT-ORATION SUMW\RY REE LOG: GEARI-LART-BHS 05/12/86 9212' —MARKER JOINT ANGLE AT TOP FERE: 35'@ 9457' Note:Refer to Production DB for historical perf data SIZE SPF NTHR'VAL Opn/Sgz DATE 9475' ELMD DUMP 10'SLUGGITS(10/21/15) 2-7/8" 6 9457-9472 O 10/15/15 ' /////////� 9478' —13-3/8'BKR IBP(10/16/15) 3-3/8" 6 9476-9481 S 01/20/94 3-3/8" 6 9490-9506 S 01/20/94 3-3/8' 6 9516-9526 C 04/12/94 I 3-3/8' 12 9526-9536 C 01/23/94 3-3/8' 6 9540-9550 C 01/25/94 3-3/8" 6 9565-9575 S 01/20/94 lir —9649' FISH:2 BKR FASDRILL CBPs 2-7/8' 6 9585-9593 C 07/02/14 3-38' 6 9585-9606 S 01/20/94 2-7/8" 4 9680-9722 S 01/20/94 PBTO H 9918' 11111111 1111111/11111114 7'LNR,29#,L-80,.0371 bpf,D=6.184' I—I 9961' 1.4..4141! DATE REV BY COMMENTS DATE REV BY COMENTS PR AHDE BAY LINT 05/16/86 ORIGINAL COMPLETION 11/10/15 JTG/JM3 DUM3SLUGGIFS(1021/15) WELL H-21 07/16/14 ATO/JM)ADFS4 S(07/02/14) PERMIT No:'1860710 07/17/15 RKT/JMD SET DSSSV(05/06/12) AR Na: 50-029-21575-00 11/10/15 R/UJMD GLV C/O(10/21/15) SEC 21,T11N,R13E 534'Ft'L 8 1266'FEL 11/10/15 STF/JMD ADf8S/SET RUG(10/15-16415) BP Exploration(Alaska) 11/10/15 JTG/JK) RESET DSSSV(1021/15) viG • • 2342 WELL LO TRANSMITTAL II. PROACTIVE DIAGNOSTIC SERVICES, INC. DATA LOGGED IOM4/2015 K.BENDER To: AOGCC v,tv, Makana Bender 333 W. 7th Ave t11.-J 0 9 Lu' Suite 100 Anchorage, Alaska 99501 (907) 793-1225 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Analisa Steger LR2—1 900 Benson Blvd. Anchorage, AK 99508 Qancpdc@bp.com and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 SCANNED SEP 1 52016 Fax: (907) 245-8952 1) LeakPointTM Survey 28-Sep-15 H-21 BL/CD 50-029-21575-00 2) Signed : o►)'j✓a 6.44tDate : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGECC MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\BPTransmit.docx • • Regg, James B (DOA) / From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] 17� 5' - Sent: Friday, August 24, 2012 6:16 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); Clingingsmith, Mike J Subject: OPERABLE: Producer H -21 (PTD #1860710) Tubing Integrity Confirmed An, Producer H -21 (PTD # 1860710) a TIFL on 8/23/2012. The passing test confirms the presence of two competent barriers in the well. The well has been reclassified as Operable. Please call if you have any questions. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 SCANNED MAY 0 2 2013 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (a�BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, August 12, 2012 4:52 PM To: 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS C2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug ; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES' GPB West Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU � Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: H -21 (PTD #1860710) Sustained Casiru,' Pressure on IA Above MOASP All, Producer H -21 (PTD #1860710) was found to have sustaine. asing pressure above MOASP on the IA. The tubing /IA/OA were SSV /2300/0 psi on 08/09/2012. The we is reclassified as Under Evaluation while further diagnostics are conducted. The plan forward is: 1. Downhole Diagnostics: TIFL 2. Well Integrity Engineer: Determine further.: iagnostics pending TIFL results Attached are TIO plot and wellbore schematic for reference: 1 1, PG -Z Pit • • iS4 o7ro Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] e, /, i Sent: Sunday, August 12, 2012 4:52 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: AK, D &C DHD Well Integrity Engineer Subject: UNDER EVALUATION: H -21 (PTD #1860710) Sustained Casing Pressure on IA Above MOASP Attachments: H -21 TIO 08- 12- 12.docx; H- 21.pdf All, Producer H -21 (PTD #1860710) was found to have sustained casing pressure above MOASP on the IA. The tubing /IA/OA were SSV /2300/0 psi on 08/09/2012. The well is reclassified as Under Evaluation while further diagnostics are conducted. The plan forward is: SC WED tti A' 0 7 nil 1. Downhole Diagnostics: TIFL 2. Well Integrity Engineer: Determine further diagnostics pending TIFL results Attached are TIO plot and wellbore schematic for reference: «H -21 TIO 08- 12- 12.docx» «H- 21.pdf» 5 e Thank you, 5Cr - Z 3Lcps, Mehreen V zi r R P= 6 t 7o ph; BP Alaska - Well Integrity Coordinator % M- A P= 33. 't. �to O � t,C� WIC Office: 907.659.5102 WIC Email: AKDCWeIIlntegrityCoordinator PBP.com 1 PBU H-21 PTD # 1860710 8/12/2012 TIO Pressures Plot -7 Well:14-21 ! 1 3.000 - 1 i I -M-- IA ZOOG - • • . - --,•,-- OA 00A -4 000A I Oft PI. I ! 1,000 • • - - - . I . 1 0 . \■ • • • • 1 • • • • - . I 1 , /._.._.._......._.-."-'-*\ 05(12i12 05119/12 0525/12 0902/12 06109;12 06/16112 06123 06/30/12 07/07/12 07/14/12 07/11112 07r2012 080 0811/12 2 — i TREE = 6-3/8' MCEVOY III SAPNOTES: 1 WELLHEAD = MCEVOY ACTUATOR = OTIS H -21 k13EC.EV - 7675 f T BE El-EVI '-- ...- 47 - ' KOP 2044 —I5-1/2" 0115 SSSV LANE) NIP, ID = 4,582" 1 = 5050' Max Angie = 38° 046.67 Q Datum 95817 GAS LIFT MANDRELS Datum ND = : : .. BB ST MO IVO DEV TYPE VLV LATCH PORT DATE k 5 3019 3019 0 OTIS DOME RM 16 05/04/12 13-3/8° CSG, 72$, L-80, ID = 12.347" — 2692' --AI 11 II, 4 5316 5305 21 OTIS SO RM 20 05104/12 3 7259 6943 37 OTIS DMY RM 0 08/31/04 2 8495 7975 32 OTIS DMY RM 0 01/02/92 Kr .1:: 1 8692 8141 33 OTIS 'DMY RM 0 0 $; LT . , 1 r 1 1 Minimum ID = 3.70" @ 8522' ■ • 1 ■ • STA 41 = DMY BEHIND CEMENT SHEATH 0 4 4 4 1 . TOP OF CEMENT SHEATH 8763' 5-1/2'' 011S XA SLIDING SLV, ID = 4,582" 4 . 1 KIIMI TOP OF CEMENT SHEATH, ID = 3,70" I 8522' r N, 1 • 4"4 1110 • 8788' TOP OF IA CMT PLUG ( . ,_ 4 4 *tAA4 44. 4 ' 4 . .`*i% 8820' TUBING PUNCH (02106/09) Od • 1 4 [5-i12 TBG, 170, L-80, 0232 bpf, ID = 4,892" : : 23' !.7 • l' 4■411. 1 8823' - --Tra ONIS -------- SEAL ASSY ' pfr'q 8838' 1 X s-irt TIW FIBBP PKR, ID = 4.75" 0. • 4 1. 8843 JMILLOUT EXTENSION I 4 „ • I. o. 4 8849' ---1 x 4-112" XS) 4 ■: _ ITOP OF 7' LNR 89044 OTIS X NIP, ID = 1813" I ,r. 7 ■4 . 1 1,1- 6 in, ■ 0., 4 I 8916' —4-1/2' 0118 XN NIP, ID = 3,725' • I. ■, • , , • li I 4-1 fr TAILPIPE, 12.6S, L-80, .0152 bpf, 10 = 3,958" — 8946' I ,.. 0 8' , :' 4-1/2" BKR TBG TAIL, 10 = 3,958" I 8942' I--IELMD TT LOGGED 09/25/94 _ .. 9-518" CSG, 470, L-80, ID = 8.681' — I 9147', Ar-qP 4t7opc); r PERFORATION 51,11/MARY REF LOG. GEARHART-BI I 9212' CS 05/12/86 i—MARKER JOINT ANGLE AT TOP FERE 36° ig 9476' Note: Refer to Productoon EX3 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9476 - 9481 S 01/20/94 3-3/8" 6 9490 - 9506 S 01/20/94 3-3/8" 6 9516 - 9526 0 04/12/94 3-3/T 12 9526 - 9536 0 01)23/94 3-3/8" 6 9540 - 9550 o 01/25/94 lilif -9649' I--1FISH: 2 BKR FASDRILL CBPs I 3-3/8" 6 9565 - 9575 S 01 /20194 3-318" 6 9585 - 9606 S 01/20/94 2-7/8" 4 9680 - 9722 S 01120/94 I 'ITO H 9919' VAVA• • VAV • 1 F' • ' • •4 • 1 7" LNR, 291/, L-80, 0371 bpf, ID = 6184° Ma. DATE REV BY COMMENTS DATE ' REV BY COMIMENTS PRUDHOE BAY UNIT 05116186 OFaGINAL COMPLETION 09/09/09 TLH GLVS LATCH & SFTY NOTE CORR WELL H-21 09/20/01 RN/KAK CORRECTIONS 11106/09 BSEISV GLV C/O (10/28/09) '0'i TNo r 1:: 710 02/09103 ATP DELETEWAVER SAFETY NOTE 01/07/12 TTR/ PJC SET IBP (1/5/12) AF. 50-. • 21575-00 %lama WRR/TLP GLV C/0 05/23/12 DJS/JMD GLV C/0 (05/04/12) SEC21, T11N, R13E, 534' FNL & 1 .-7.• FEL 03/10/08 TEUTLH BP FULL/SET (02/21 & 02/28/08) 05/23/12 DJS/JMD RILL IBP (05/06/12) BP Exploration (Alaska) 02116/09 RMHISV CMT SHEATH / FISH (02/12/09) 05/23/12 JNID GLM DATE & DEPTI-ICORRECTIONS „ , • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg 0 AUG z01 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue /� ' - Anchorage, a Alaska 99501 9 f0 Subject: Corrosion Inhibitor Treatments of GPB H -Pad 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 • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) I 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 1406 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 11-15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 11-16 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 11-18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -198 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 1 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 -.4 1-1-21 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 11-28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 11-30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 11-31 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 H -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 . • prb 1860 James B (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWeIIIntegrityCoordinator @bp.com] Sent: Monday, May 07, 2012 11:16 AM To: Regg, James B (DOA) Subject: RE: UNDER EVALUATION: Injector 13 -18 (PTD #1820350) Begin Water Injection Prior to AOGCC MIT -IA Attachments: MIT PBU P2 -34 05- 02- 12.xls; MIT PBU H -21 04- 29- 12.xls; MIT PBU 13 -18 04- 22- 12.xls Jim, Enclosed are the MIT's for the 2 injection wells that I sent over the weekend and 1 producer I referenced for passing MITs this weekend. Injector 13 -18 (PTD #1820350 Injector P2 -34 (PTD #1950660) ]�� C � n1 i ____j Producer H -21 (PTD #1860710) ✓, Please let me know if you need anything else. I'll ensure that the MITs are included with the letters I send. Jerry Murphy BPXA Well Integrity Coordinator From: Regg, James B (DOA) [mailto:jim.regg@ alaska.gov] Sent: Monday, May 07, 2012 10:18 AM To: AK, D &C Well Integrity Coordinator; Schwartz, Guy L (DOA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS P EOC TL; G GPB FS3 Drillsites; Catron, Garry R (Northern solutions) Cc: Walker, Greg (D &C); Clingingsmith, Mike J; LeBaron, Michael 3 Subject: RE: UNDER EVALUATION: Injector 13 -18 (PTD #1820350) Begin Water Injection P for to AOGCC MIT -IA Please send MITs you reference when bringing well on line. You probably send the ith the batch submittal later in month; we cannot wait for that submittal. A passing MIT is important info in su • •ort of decision to put well back on injection and should accompany the notice. Thank you. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 -793 -1236 From: AK, D &C Well Integrity Coordinator [mailt•.AKDCWeIIInte • ri Coordinator • bp.com] Sent: Saturday, May 05, 2012 8:57 AM To: Regg, James B (DOA); Schwartz, Guy L D OA); AK, OPS FS3 OSM; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 DS Operators; AK, D &C Well Services Opera 'ins Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; Daniel, Ryan; AK, RES GPB West Well •pt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS PCC EOC TL; G GPB FS3 Drillsites; Catron, Garry R (Norther olutions) Cc: AK, D &C Well Integrity Cool nator; Walker, Greg (D &C); Clingingsmith, Mike J; LeBaron, Michael J Subject: UNDER EVALUATIO Injector 13 -18 (PTD #1820350) Begin Water Injection Prior to AOGCC MIT -IA All, 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.recioaalaska.00v; doa. aogcc.prudhoe.bay(a)alaska.gov; phoebe.brooks(aalaska.gov: tom.maunderaalaska.aov OPERATOR: BP Exploration (Alaska), Inc. I'1eo (1(t7- 6 FIELD 1 UNIT / PAD: Prudhoe Bay / PBU / H Pad A —6 i f � Q _ DATE: 04/29/12 l67-un OPERATOR REP: Gerald Murphy AOGCC REP: Packer Depth Pretest _ Initial 15 Min. 30 Min. 45 Min. 60 Min. Well H -21 - Type Inj. N ' TVD 8,262' Tubing 645 650 650 650 Interval 0 P.T.D. 1860710 ' Type test P Test psi 2065.5 Casing 23 3001 a 2919 2880 P/F P Notes: OA 0 2 2 2 Producer exhibiting TxIA communication Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing, Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. _ Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industnal Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU H - 21 04 - 29 - 12 ft /x,07(0 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] a 5 /7� / Sent: Monday, May 07, 2012 9:40 AM t57 To: Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: AK, D &C Well Integrity Coordinator; Walker, Greg (D &C); LeBaron, Michael J; Arend, Jon (NORTHERN SOLUTIONS LLC); Clingingsmith, Mike J Subject: UNDER EVAL: H -21 (PTD #1860710) Passed MIT -IA, Dummy Subsurface Safety Valve Set in Tubing All, Producer H -21 (PTD #1860710) passed an MIT -IA to 3000 psi on 04/29/2012. During wellhead testing, on 4/1/2012 it was identified that the communication was seen through the SSSV control lines that were in the well. A dummy subsurface safety valve has been set in the well to mitigate the TxIA communication. The well is reclassified as Under Evaluation. Plan forward: 1. WIE: Monitor well pressures once well is returned to production for 10 -14 days to evaluate for continued TxIA communication Please call if you have any questions or comments. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Email: AKDCWeIIIntegrityCoordinator (cr�BP.com From: AK, D &C Well Integrity Coordinator Sent: Friday, January 06, 2012 7:13 AM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti 3; AK, OPS Well Pad HU Cc: Walker, Greg (D &C); Olson, Andrew Subject: NOT OPERABLE: H -21 (PTD #1860710) Secured with IBP All, Producer H -21 (PTD #1860710) failed an MIT -IA confirming a lack of two competent barriers. The well is reclassified Not Operable and has been secured wth an IBP. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) 1 • • P((t4-z-( Regg, James B (DOA) Pm /8667(o From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator @bp.com] Sent: Friday, January 06, 2012 7:13 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: Walker, Greg (D &C); Olson, Andrew Subject: NOT OPERABLE: H -21 (PTD #1860710) Secured with IBP All, Producer H -21 (PTD #1860710) failed an MIT -IA confirming a lack of two competent barriers. The well is reclassified Not Operable and has been secured wth an IBP. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator 8 I BP Alaska Drilling & Wells'� �' Well Integrity Office: 907.659.5102 Email: AKDCWeIIlntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, November 30, 2011 2:07 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS ' 2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D: Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB West Wells Opt gr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: King, Whitney; Olson, Andrew Subject: UNDER EVALUATION: H -21A (PTD #1860710) Sustained Casing P -ssure on IA Above MOASP All, Producer H -21A (PTD #1860710) was found to hay sustained casing pressure above MOASP on the IA. The tubing /IA/OA were 1620/2300/400 psi on 11/28/20 1. The well is reclassified as Under Evaluation while further diagnostics are conducted. The plan forward is: 1. Downhole Diagnostics: MIT -IA to 30011 •si 2. Production Engineer: Evaluate for L: -k Detect Log pending MIT -IA results Attached are TIO plot and wellbor- schematic for reference: «File: H- 21.pdf» «File: 1/21 TIO 11- 30- 2011.doc» Thank you, / 1 CORRECTION - UNDER EVALUATION: H. (PTD #1860710) Sustained Casing Pr ure on... Page 1 Al Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator ©bp.com] � l �/3] tt Sent: Wednesday, November 30, 2011 2:10 PM t I To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: CORRECTION - UNDER EVALUATION: H -21 (PTD #1860710) Sustained Casing Pressure on IA Above MOASF All, Correct well name is H -21 (PTD #1860710). H -21A was reported in the previous email erroneously. Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 ' , Jr I S} , ;t /t` i; Email: AKDCWeIllntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Wednesday, November 30, 2011 2:07 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility 011; AK, OPS GC2 Field 0 &M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB West Wells Opt a Engr; AK, RES GPB East Wells Opt Engr; Phillips, Patti J; AK, OPS Well Pad HU Cc: King, Whitney; Olson, Andrew Subject: UNDER EVALUATION: H -21A (PTD #1860710) Sustained Casing Pressure on IA Above MOASP All, Producer H -21A (PTD #1860710) was found to have sustained casing pressure above MOASP on the IA. The tubing /IA/OA were 1620/2300/400 psi on 11/28/2011. The well is reclassified as Under Evaluation while further diagnostics are conducted. The plan forward is: 1. Downhole Diagnostics: MIT -IA to 3000 psi 2. Production Engineer: Evaluate for Leak Detect Log pending MIT -IA results Attached are TIO plot and wellbore schematic for reference: cP « File: H- 21.pdf » « File: H -21 TIO 11- 30- 2011.doc » Thank you, (?L Zoe%; Mehreen Vazir 33 (Alternate: Gerald Murphy) � P = Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIllntegrityCoordinator @BP.com 11/30/2011 PBU H -21 PTD # 1860710 11/30/2011 TIO Pressures Plot Well: H -21 4.000 - i 1 ( 3,000 • Tby —f— IA 2,000 - 00A —.-- 000A 1 On 71441\ 1 I ■ 1,000 - i 09/03/11 09/10/11 09/1 09/24/11 10101/11 10/08/11 10/15/11 10/22/11 10/29/11 11/05/11 11 /12/11 11/1 11/26/11 • TREE = 6 -3/8" MCEVOY • WELLHEAD = MCEVOY SAFETY NOTES: • ACTUATOR = OTIS I KB. ELEV = 76.51' BF. ELEV = 47.51' KOP = 5050' 2044' 1— [5 -1/2" OTIS SSSV LAND NIP, ID = ,562" Max Angle = 38 @ 9850' Datum MD = 9581' Datum TV D = 8800' SS GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LAID-4 PORT DATE A 5 3019 2942 0 OTIS DMY RM 0 i. 10/28/09 13 -3/8" CSG, 72 #, L-80, ID = 12.347" H 2692' I---A 4 5316 5228 20 OTIS DMY RM 0 10/28/09 3 7259 6866 38 OTIS DMY RM 0 :08/31/04 HP 2 8495 7899 32 OTIS DMY RM 0 H0/19/86 1 8692 8065 33 OTIS "DMY RM 0 :08/31/04 Minimum ID = 3.70" @ 8522' 011 M " STA #1 = DMY BEHIND CEMENT SHEATH 1 4 11 TOP OF CEMENT SHEATH 1414 11�� 8763' — 15 -1/2" OTIS XA SLIDING SLV, ID = ; .562" x' 1 . 1`; 1 ; • � 1 � + TOP OF CEMENT SHEATH, ID = 3.70" 1' 8788' JTOP OF IA CMT PLUG , $$22 I —I TOP 1 1 1 1 11 1 / rf4'1� , 1 1 1 , 11 1 1 I* ! 8820' -8822 I-I TUBING PUNCH (02/06/09) 11 11'1 t 8823' TIW OVERSHOT SEAL ASSY 5-1/2" TBG, 17 #, L-80, .0232 bpf, ID = 4.892" H 8823' ! 1 ` / 1 11114 $$23 4 h ► 1 1 1 ∎1 e 'x.1,1 t.1•'\ " 8838' J- 19 -5/8" X5 -1/2" 11W HBBP PKR, IDW 4.75" 0 8843' I- IMILLOUT EXTENSION I - ■ 8849' I-- 15 -1/2" x 4 -1/2" XO I 8881' - 14 -1/2" OTIS X NIP, ID = 3.813" I — 1 TOP OF 7" LNR I 8904' 1 ■ ■: , 8916' 1- 14-112" OTIS )'N NIP, ID = 3.725" 1 4 -1/2" TAILPIPE, 12.6#, L -80, .0152 bpf, ID = 3.958" H 8946' , m 8946' 1--14 -1/2" BKR TBG TAIL, ID = 3.958" l 894.2' I--IELMD TT LOGGED 09/25/94 I 1 9 -5/8" CSG, 47#, L-80, ID 8.681" H 9147' i 1 a Al'LS7(.`1 PS. . PERFORATION SUMMARY REF LOG: GEARHART -BHCS 05/12/86 9212' H MARKER JOINT I c ANGLE AT TOP PERF: 36 @ 9476' Note: Refer to Production DB for historical pert data ,.. SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9476 - 9481 S 01/20/94 3 -3/8" 6 9490 - 9506 S 01/20/94 3 -3/8" 6 9516 - 9526 0 04/12/94 3 -3/8" 12 9526 - 9536 0 01/23/94 3 -3/8" 6 9540 - 9550 0 01/25/94 3 -3/8" 6 9565 - 9575 S 01/20/94 1111, -9649' I -FISH: 2 BKR FASDRILL CBPs I 3 -3/8" 6 9585 - 9606 S 01/20/94 2 -7/8" 4 9680 - 9722 S 01/20/94 I PBTD 1 9919' WM11f1I ► .- 17" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" I- 9961' ►.1.1. 1.1.1,1 .1 .1 '' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/16/86 ORIGINAL COMPLETION 09/09/09 TLH GLVS LATCH & SFTY NOTE CORR WELL: H -21 09/20/01 RN/KAK CORRECTIONS 11/06/09 BSE/SV GLV C/O (10/28/09) PERMIT No: 1860710 02/09/03 ATD /TP DELETE WAIVER SAFETY NOTE 12/09/10 MCIWPJC SET PLUG IN SSSV NIP (12108/10) API No: 50 -029- 2 -00 08/31/04 WRR/TLP GLV C/O 01/09/11 TAR/PJC PULL PLUG (01/06/10) SEC 21, T11N, R13E, 534' FNL & 1266' FEL 03/10/08 TEL /TLH BP PULL/SET (02/21 & 02/28/08) BP Exploration (Alai: ka) 02/16/09 RMH/SV CMT SHEATH / FISH (02/12/09) _ OPERABLE: H-21 (PTD #1860~0) Tubing Integrity Restored • Schwartz, Guy L (DOA) Page 1 of 2 From: NSU, ADW Weil Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Saturday, August 01, 2009 9:08 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA); Schwartz, Guy L(DOA}; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Welipad Lead; Rossberg, R Steven; Engel, Harry R; NSU, ADW Well Operations Supervisor; GPB, Optimization Engr; GPB, Welis Opt Eng; GPB, Prod Controllers Cc: Quy, Tiffany; Starck, Jennifer L; NSU, ADW Well Integrity Engineer ~~ /~ Subject: OPERABLE: H-21 (PTD #1860710) Tubing Integrity Restored f ~ D D~ All, We~l H-21(PTD #1860710) passed a TIFL on 7/31J09 after changing out the orifice gas lift vaive proving tubing integrity has been restored. The well has been reclassifed as Operable. Please let us know if there are any questions. Thank you, Anna ~Du6e, ~.~. ~alt Torin Roschinger) Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 . , ~• ~ '{, `.~t1~;_~ _~, ~ , b >, . , ~, . ~ x; ~ :=~. ~ a ~,~.~:. ~ . From: NSU, ADW Well Integrity Engineer Sent: Monday, July 27, 2009 4:04 PM To: 'Regg, ]ames B(p0A)'; 'Maunder, Thomas E(DOA)'; 'Schwariz, Guy (DOA)'; GPB, Area Mgr West (GC2/WRD); GPB, GC2 OTL; GPB, GC2 Wellpad Lead; GPB, Well pad MN; Rossberg, R Steven; Engel, Harry R; NSU, ADW WeU Operations Supervisor, GPB, Optim¢ation Engr; GP6, Wells Opt Eng; GPB, Prod Controllers Cc: NSU, ADW Well Integrity Engineer; Quy, Tiffany; Starck, Jennifer L Subject: UNDER EVALUATION: H-21 (PTD #18607].0) for Sustained casing pressure due to TxIA Comm All, Well H-21 (PTD #1860710) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing/IA/OA equal to SSV/2360/60 psi on 07/20/09. Due to the constraint of not being able to bieed pressure down to the productian system due to the shut-down, the diagnostic work took longer ta complete. O~ 07/27/09, a TIFL failed on IA repressurization overnight confirming Tx1A communication. The well has been reclassified as Under Evaluation and placed on a 28-day clock. Operations may allow the IA pressure to continue as is or may return the well to production once the facility is online. The plan forward for the well is as follows: 1. DHD: TIFL - FAIIED 2. Slickline: Set dummy gas lift valves 4. DHD: MI7-IA to 3Q00 psi A TIO plot and wellbore schematic have been included for re#erence. $/3/2009 OPERABLE: H-21 (PTD #186QZ10) Tubing Integrity Restored • Page 2 of 2 ~ « File: H-21 TIO Plot.doc »« File: H-21.pdf » Please call with any questions or concems. Thank you, Torin Roschinger (alt. Anna Dube) Well Integ~ity Coordinator Office (907) 659-5102 Cell (406) 570-9630 Pager (907) 659-5100 E~. 1154 8/3/2009 TREE = 6-3l8" MCEV OY WEI.LHEAD = MCEVOY ACTt;ATOR = OTIS KB. ELEV = 76.51' BF. ELEV = 47.51' KOP = 5050' Max Angle = 38 @ 9850' Datum MD = 9581' Datum ND = 8800' SS ~ H -21 ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2692' Minimum ID = 3.70" @ 8522' TOP OF CEMENT SHEATH TOP OF CEMENT SHEATH, ID = 3.70" $522' 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" $$23' OF 7" LNR ~-~ 8g04~ ~ 41/2" TAILPIPE, 12.6#, L-80, .0152 bpf, ID = 3.958" ~--{ 8946~ &5/8" CSG, 47#, L-80, ID = 8.681" ~ 9147~ PERFORAl10N SUMMARY REF LOG: GEARHART-BHCS 05/12/86 ANGLE AT TOP PERF: 36 @ 9476' Note: Refer to Production DS for historical perf data SIZE SPF INTERVAL OpnlSqz DATE 3-3l8" 6 9476 - 9481 S 01/20/94 3-3/8" 6 9490 - 9506 S 01/20/94 3-318" 6 9516 - 9526 O 04/12/94 3-3/8" 12 9526 - 9536 O 01/23/94 3-3l8" 6 9540 - 9550 O 01l25/94 3-318" 6 9565 - 9575 S 01120/94 3-3/8" 6 9585 - 9606 S 01120l94 2-7/8" 4 9680 - 9722 S 01/20194 ~~ 9919' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 9961' SAFE~OTES: IA X OA COMM. 2044' -~5-1/2" OTIS SSSV LAND NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LAT PORT DATE 5 3019 2942 0 OTIS DOME RA 16 03/04/09 4 5316 5228 20 OTIS SO RA 20 03/04109 3 7259 6866 38 OTIS DMY RA 0 08/31/04 2 8495 7899 32 OTIS DMY RA 0 10l19/86 1 8692 8065 33 OTIS 'DMY RA 0 08J31l04 " J I H iFl = UMY tStHINU G`tMtIV I SHtA 1 Fi 8763' r1/2" OTIS XA SLIDING SLV, ID = 4.562" $78$' TQP OF IA CMT PLUG ( 8820~-8822~ TUBING PUNCH (02l06l09) 8823' 11W OVERSHOT SEAL ASSY 8838' 9-5/8" X r1/2" TIW HBBP PKR, ID = 4.75" 8843~ MILLOUT EXTENSION 8849' S-~/2° x 4-112" xo $881 ~ 4-1/2" OT1S X NIP, ID = 3.813" 8916' --I4-1/2" OTIS ~1 NIP, ID = 3.725" 8946~ 4-1/2" BKR TBG TAIL, ID = 3.958" $942' ELMD TT LOGGED 09/25/94 g212' ~'-~MARKER JOINT -9649~ I-I FISH: 2 BKR FASDRILL CBPs DATE REV BY COMMEMS DATE REV BY COMMHJTS 05/16/86 ORIGINAL COMPLETION 03/06/09 DAVlSV GLV C/O 09/20l01 RN/KAK CORRECTIONS 03/29/09 ?/ PJC CMT SHEATH / GLV CORRECTION 02/fl9/03 ATD/TP DFIETE WANER SAFEIY NOTE 08/31/04 WRR/TLP GLV GO 03I10/08 TEL/TLH BP PULUSET (Q2121 & 02/28/08) 02/i6l09 RMH/SV CMT SHEATH / FISH {02/12l09) PRUDHOE BAY UNfT WEL~: H-21 PERM(f No: ~1860710 API No: 50-029-21575-00 SEC 21, T11 N, R13E, 534' FNL & 1266' FEL BP F~cpioration {Alaska) # ! TIO Plot (PTD# 1860710) ~ t T~ ~ .a . o~ o~ ~~ ~ oo~ ^ o~ I ~~ n~~;n>m~a n~,ni~a!n~i n~,~i~;na ii„~=~.mv n~,r<n,na iis;nFm4 r~~n~ma ria;~?n~na nan»rw mm.nmo iV/t1/0a I17:1A109 nonc The first bleed on 06/27/09 showed the tubing pressure staying down verifying tubing integrity. However, the second bleed on 07/27/09 built up pressure overnight resulting in a failing TIFL. • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, February 23, 2009 2:28 PM To: 'Preble, Gary 6 (SAIC)' Subject: RE: Emailing: H-21 186-071 WORK SUMMARY ADD.PDF Thanks Gary. When other patch work is done, similar information should be included. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Monday, February 23, 2009 2:26 PM To: Maunder, Thomas E (DOA) Subject: Emailing: H-21 186-071 WORK SUMMARY ADD.PDF Tom, ~ cx~~.4•ti~J ~tt7 Oc~rc:,_~~or5 S~~a~-c~e~1 d~Jl ~~~~ This attachment needs to be added to thCe_ sundry I submitted on 2/17/09 for H-21 (186-071). It shows that the mit-ia passed. Thanks The message is ready to be sent with the following file or link attachments: H-21 186-071 WORK SUMMARY ADD.PDF Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «H-21 186-071 WORK SUMMARY ADD.PDF » ,~z ~;~~ ~~B ,~~ ~ 20C~~ 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, February 19, 2009 3:17 PM To: 'Preble, Gary B (SAIC)' Subject: RE: H-21 (186-071) Not a problem Gary. It looked like there still was a little work to accomplish. Tom From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Thursday, February 19, 2009 3:16 PM To: Maunder, Thomas E (DOA) Subject: RE: H-21 (186-071} Tom, I just talked with the PE and she said that the MITIA has not been conducted yet, but it is scheduled ASAP. Could you hold the Sundry and I will send you the updated events summary as soon as it is done? Sorry about that. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, February 19, 2009 2:27 PM To: Preble, Gary B (SAIC) Subject: H-21 (186-071) Gary, I am reviewing the 404 submitted for the cement packer work. Was there an MITIA conducted to verify the repair? Thanks in advance. Tom Maunder, PE AOGCC 2/19/2009 /+,,,~~ ~ ~ ~ STATE OF ALASKA ~- /VNl~ ALAS OIL AND GAS CONSERVATION COMM~~~ ~- ~ ~°~~~ REPORT OF SUNDRY WELL OP~R~A~;'QS~ons, fsofnmission ,~'~v 1. Operations Abandon ~ Repair Well 0 , Plug Perforations ~ S 'mu ate ~ ther PACKER REPAIR AnChOPaQ~ ^ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Exxttension ^ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well[] 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory ~ 186-0710 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21575-00-00- 7. KB Elevation (ft): 9. Well Name and Number: 76.51 KB - H-21 - 8. Property Designation: 10. Field/Pool(s): ADLO-028284 ` PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 9961 ~ feet Plugs (measured) None true vertical 9179.76 ~ feet Junk (measured) None Effective Depth measured 9919 feet true vertical 9146.59 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20"x30" 30 - 110 30 - 110 Surface 2663 13-3/8" 72# L-80 29 - 2692 29 - 2692 4930 2670 Production 9119 9-5/8" 47# L-80 28 - 9147 28 - 8521 6870 4760 Liner 1057 7" 29# L-80 8904 - 9961 8318 - 9180 8160 7020 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# L-80 27 - 8838 4-1/2" 12.6# L-80 8838 - 8946 Packers and SSSV (type and measured depth) 5-1/2" TIW HBBP Packer 8838 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory T! Development r' ' Service T~` Daily Report of Well Operations X 16. Well Status after proposed work: Oil - Gas r WAG GINJ ~ WINJ T! WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-369 Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone 564-4944 Date 2/17/2009 Form 10-404 Revised 04/2006 { , ., Submit Original Only ~"~.a~~, F~~ Laos r"'a(l~l H-21 186-071 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H-21 8/11/86. PER 9,680. 9,722. 8,956.31 8,990.05 H-21 6/25/90 APF 9,490. 9,506. 8,803.24 8,816.2 H-21 6/25/90 APF 9,516. 9,534. 8,824.29 8,838.84 H-21 6/25/90 APF 9,540. 9,550. 8,843.69 8,851.76 H-21 6/25/90 APF 9,565. 9,575. 8,863.85 8,871.9 H-21 6/25/90 APF 9,585. 9,605. 8,879.95 8,896.03 H-21 8/18/91 APF 9,476. 9,481. 8,791.88 8,795.94 H-21 1/20/94 SQZ 9,476. 9,481. 8,791.88 8,795.94 H-21 1/20/94 S(~Z 9,490. 9,506. 8,803.24 8,816.2 H-21 1/20/94 SQZ 9,516. 9,534. 8,824.29 8,838.84 H-21 1/20/94 SQZ 9,540. 9,550. 8,843.69 8,851.76 H-21 1/20/94 SQZ 9,565. 9,575. 8,863.85 8,871.9 H-21 1/20/94 S(1ZZ 9,585. 9,605. 8,879.95 8,896.03 H-21 1/20/94 SQZ 9,680. 9,722. 8,956.31 8,990.05 H-21 1/25/94 APF 9,534. 9,536. 8,838.84 8,840.46 H-21 1/25/94 RPF 9,526. 9,534. 8,832.38 8,838.84 H-21 1/25/94 RPF 9,540. 9,550. 8,843.69 8,851.76 H-21 4/12/94 RPF 9,516. 9,536. 8,824.29 8,840.46 H-21 1/23/03 FIL 9,585. 9,919. 8,879.95 9,146.59 H-21 6/30/03 BPS 8,831. 9,919. 8,257.08 9,146.59 H-21 7/31/05 BPP 8,831. 9,919. 8,257.08 9,146.59 H-21 1/13/06 BPS 8,865. 9,919. 8,285.3 9,146.59 H-21 2/21/08 BPP 8,865. 9,919. 8,285.3 9,146.59 H-21 2/28/08 BPS 8,930. 8,932. 8,339.35 8,341.01 H-21 2/3/09 BPP 8,930. 8,932. 8,339.35 8,341.01 H-21 2/4/09 BPS 8,930. 8,932. 8,339.35 8,341.01 H-21 2/5/09 SPS 8,830. 8,930. 8,256.25 8,339.35 H-21 2/6/09 PER 8,820. 8,822. 8,247.96 8,249.62 H-21 2/7/09 SQZ 8,815. 8,832. 8,243.81 8,257.91 H-21 2/12/09 BPP 8,930. 8,932. 8,339.35 8,341.01 H-21 2/12/09 SPR 8,830. 8,930. 8,256.25 8,339.35 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • H-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 2/2/2009fCTU #9 w/1.75" CT. Job objective: Packer Repair. MIRU CTU. Assist LRS with IA fluid pack. Tempera ures ranging rom - to -39* F. s*** Continued on WSR 02/03/09 **` 2/2/2009 T/I/0=250/100/40 Assist CTU load IA (Packer Squeeze) Pumped 4.5 bbls crude down IA. IA pressured right up to 1500 psi. Monitored for 15 min. IAP lost 0 psi. Bled IAP to 0 psi S/I IAP slowly rose to 100 psi. Bled to 0 psi. pumped 13 bbls to pressure IA back to 1500 psi. Bled TP fro 300 psi to 250 psi. IAP dropped to 1440 psi. DHD reshot IA fluid level at surface. IA pressure bled to 0 psi. FWHPs= 360/0/40 Valve positions at time of departure (CTU still on well); SV shut, WV shut, SSV open, MV open, IA open, OA open, A/L line closed. T/I/O =SSV/240/0+. Temp = St. T & IA FL's. AL blinded @ casing valve. Operator not able to come open SSV for pressure/FL. IA FL @ 2706' (119 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 2/3/2009 CTU #9 w/1.75" CT. Job objective: Packer Repair. *** Continued from WSR 02/02/09 ""* RU CTU. Makeup BHA #1 w/2.75" BDN. CTU on STBY for weather. Continue OPS, stab on well, PT and RIH. During TIH taking gas and crude returns ;Well would not bleed off. Tagged plug twice at 8935' ctmd, PU and correct depth to 8929'. PUH to 8830' and flagged pipe. Online with KCL down the CT taking returns of gas and slugs of crude. After 56 bbls away, WHP continued to climb to 830psi and then dropped off. RIH past plug depth, continue RIH and push to .:bottom. Hard tag at 9606' {between squeezed perfs). POOH. Makeup BHA #2: t Baker ~ pos~el~ug. it well with 5 bbls of 60/40 meth and 350 bbls of 2% KCI. iFreeze protect well with 46 bbls of 60/40. Weather dropped to -41*F. CTU to weather standby. *** Job Continued on WSR 02/04/09 **" _~. .~....~. _~. m. ~- e_ 2/3/2009 T/1/O = 360/1490/60. Temp = SI. IA FL for Coil. Coil is on well. IA FL @ surface. SSV, WV = C. SSV, MV = O IA, OA = OTG. NOVP. 2/4/2009~CTU #9 1.75" CT Scope; pkr repair, «interact publishing» resume job after weather hold. RIH w/ Baker setting tool and 3.6" composite plug. **continue on €WSR 02-05-09** 2/5/2009CTU # 09 1.75" CT Scope; pkr repair «interact publishing» continued from IWSR 02-04-09 set 3.6" composite plug @ 8931.8 (middle of joint below XN Ini le .Pooh. RIH w/ nozzle. Tag plug and correct dept to top o plug. Flag CT @ 8830' (100' above plug). Fluid pack backside and PT plug to 700 psi. .Pump 1200# of 20/40 river sand in 5 bbl pill. Let sand fall 2 hr. ag san at 8836'. ~ Wash down from 8200'-8820'. SD, tag plug @ 8821'. everse out rom 8 00' to flag @ 8830' (100' above plug). Clean up coi- I. P~bH. Freeze protect well w/ 35 ~bbls 60/40 meth. MU and RIH w/ SLB memory logging tools. *"job cont on WSR i 02-06-09"* 2/6/2009 2/6/200 T/I/0= Vac/450/0 Temp= S/I Assist Coil as directed. (Packer squeeze to restore Tubing intregity) Pumped 3 bbls 30* 60/40 MW and started pumping 90* crude down TBG taking returns up IA to CTU's choke traitor through hardline and skid to the FL of well H-22, -----Job In Progress---- ***WSR Continued to 02-07-09*** CTU # 9 1.75" CT Scope; pkr repair « interact publishing» **continued from WSR 02-05-09** cont RIH w/ mem logging tools. Tag sand top @ 8835 down wt. 8829 up wt. log up and paint flag @ 8779', cont log @50 fpm to 8000'. pooh. (data good). Corrected sand to is 8832'. MU/RIH w/ 1.56" HSD perf gun. Correct to top sho a ag. Punch interval 8820-8822' @ 4 spf. Attempt infectivity test. IA not fluid packed. Bleed off gas. Have 600 psi DP to IA. POOH. Prep to have LRS roll hole to crude. See LRS SWR for details. ** job continued on WSR 02-07- 09** 2/7/2009~Continued from 02/06/09 WSR. Interact publishing=yes. Standby while LRS complete well circ to crude. Perform weekly BOP test. Test/repair surface isolation valves. MU/RIH w/ 2.3" BDN. Lay in 6.5 bbls cmt on top of sand @ X8832'. Take returns from IA and allow two 6G~s cmt into IA. Pooh filling pipe fdiso acement. continued on WSR 02-08-09** n i~ innnn ***WSR Continued from 02-06-09*'`* Temp= SI Assist CTU as directed- (Packer squeeze to restore TBG integrity) Pumped a total of 750 bbls 90* crude followed by 20 bbls diesel down TBG taking returns up IA to CTU's choke traitor through hardline and skid to FL of well H-22. Pumped a total of 21 bbls crude and 7 bbls Neat meth down H-22 FL for freeze protect. FWHP's= 0/100/80 ***Annulus casing valves tagged and left open to gauges*** CTD unit still on well at tme of departure. _~.. ~-_........a~~~~ ~e~.~a~.. .......- ~ ~.~ continued from WSR 02-07-09; interact publishing. MU and RIH w/ LH motor and 3.7" mill. Dry tag TOC @ 8614. Start milling @ 8614' w/ 5-7 bbl Geovis sweeps. Mill to 8718', standby for rig move. Start pooh due to temperture drop to -40. **job , continued on WSR 02-09-09** i t~ C J 2/9/2009 continue from WSR 02-08-09 «interact publishing» cont pooh. freeze protect well w/ 58 bbls meth. start weather hold. 2/10/2009 Cost placeholder for trucking charges during weather standby for coil 2/11/2009=CTU #9 Scope; mill cmt «interact publishing»'"*Continued from WSR 02-09-09 ** pickup injector and lubricator. **job continued on WSR 02-12-09** 2/12/2009~Continued from WSR 02-11-09 «interact publishing» RIH w/ LH motor and 3.7" E Piranha mill. Dry tag top of cmt @ 8721' up wt. Mill to 8829' w/frequent Geovis sweeps, appears o e o om o cement. Jet through sand to 8928'_ w/ Geovis bites. Prematurely break through composite plug @ 8932'. Lost returns. Work ,coil out o to ing tai ,run o 9020'. Clear. POOH. Flush tubing w 313 l~Laydown BOT string. MU/RIH w/ 2.5" JSN, tag btm @ 9609'. (open perfs @ 9516- ~9550). pooh. freeze protect well w/ 58 bbls of 60/40 meth **job complete** (rig down continued on 02-13-09) 2/13/2009~continued from WSR 02-12-09. Blow down reel. Rig down. Job is complete. FLUIDS PUMPED BBLS 524 60/40 METH 1020 1 %KCI 1685 1 % XS KCI 51 DIESEL 10 HEC GEL 771 CRUDE 152 METH 6.5 CLASS G CEMENT 79 GEOVIS 50 GALLONA N2 4298.5 Total yVell~erviceReport ~ !~ WELL SERVICE REPORT Page 1 of 2 WELL d0B SCOPE UNIT H-Z1 CEMENT SQUEEZE LRS 46 DATE DAILY WORK DAY SUPV 2/22/2009 MIT-IA SPIELER COST CODE PLUS KEY PERSON NIGHT SUPV PBHPDWL21-N LRS-VARNER SAUVAGEAU MIN ID DEPTH TTL SIZE 0" 0 FT 0" TII/0=01010 MIT IA PASSED fa 3000 psi (Post Packer Squeeze) Pumped 9.7 bbls crude into lA for MITIA. IA lost 100 psi in the 1st 15-mins and 30 psi in the 2nd 15 mins for a total pressure loss of 130 psi in 30 mins. Bled IA. FWHP's=0/0/0. SV, WV, LOG ENTRtES Init-> 0 0 0 TIME BPM BBLs FLUID TEMP TBG IA OA COMMENTS 08:00 Start ticket. Road to CH2MHill and #or fuel. 09:00 Road to Loc. 09:40 MIISim O s with 5-line & ASRC well testers. 09:57 PJSM/RU to iA 11:11 PT to 3500 si. 11:29 .7 01st crude 20* 0 0 0 Start down IA. 11:31 .S 2 0 100 0 11:43 .5 9.7 0 3000 20 SD. Start test. 11:58 0 2900 40 15 min ressures. 12:13 0 2870 40 30 min ressures. PASS 12:28 Bleed IAP 13:10 RDMO 13:59 End ticket. Final-> 0 0 0 REQUIRED TEST PRESSURE 3,000 TEST TYPE MIT-IA FLUIDS USED TO TEST CRUDE START TIME: 11:43 PRE TEST PRESSURES INITIAL PRESSURES 15 MINUTE PRESSURES 30 MINUTE PRESSURES PASS OR FAIL TUBING 0 0 0 0 IA 0 3,000 2,900 2,870 PASS http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=7669F8EA242B4B04... 2/23/2Q09 FLUID SUMMARY 10 bbls crude • '~'~ ~ , `~ - ~ ~~ ~---~ ~~ ~~ SARAH PAL/N, GOVERNOR t1•ilCS-7~ OII! ~ GAS 333 W. 7th AVENUE, SUITE 100 COI~TSERVA7`IO1~T CODII-IISSIOrT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Starck Production Engineer BP Exploration Alaska, Inc ~~~~~ ~~-~ ~ ~ ~~~~ PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-21 Sundry Number: 307-369 $~~~~ I ti Dear Ms. Starck: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of December, 2007 Encl. . a L I~ fry RE~EIVE~ ' ^~~ ~'rb ~' STATE OF ALASKA N ~' /~' 1 ALASKA OIL AND GAS CONSERVATION COMMISSION ~~C 1 ~ ~~~ i , 1 APPLICATION FOR SUNDRY APPROVAL ~~~ ~n AAA ~~ ~~n Alaska Qil & Gas Cons, C~itxtmissian 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~'t' Othe Alter casing ^ Repair well Q ~ Plug Perforations^ Stimulate ^ Time Extension ^ Packer repair Change approved program^ Pul{ Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 - Exploratory ^ 186-0710' 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21575-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU H-21 , Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028284 ~ 76.51 KB ' PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9961 9179.76 9919 9146.59 8865 NONE Casing Length Size MD TVD Burst Collapse Surface 2663 13-3/8"72# L-80 29 2692 29 2692 4930 2670 Production 9119 9-5/8" 47# L-80 28 9147 28 8521 6870 4760 Liner 1057 7" 29# L-80 8904 9961 8317.71 9180 8160 7020 Conductor 80 20"x30" 30 110 30 110 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 5-1/2" 17# L-80 27 - 8838 - - 4-1/2" 12.6# L-80 8838 - 8946 Packers and SSSV Type: 5-1/2" TIW HBBP Packer Packers and SSSV MD (ft): 8838 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/25/2007 OIL 0 GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby ce ~ at the for going is true and correct to the best of my knowledge. Contact Jennifer Starck Printed Na a Jen ff2 cly Title Production Engineer Signature/ ~ Phone 564-5811 Date 12/11/2007 COMMISSION USE ONLY ®~_ ~~ 3 Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~g ~~ Ytq~ .- Subsequent Form Required: (.~®~ i~~Y6e? ~~ ~~~~ r ~ 2Q~~ /~ APPROVED BY Approved by: CO MI NER THE COMMISSION Date: ~ ~b Form 10-403 Revised 06/2006 ~ ~ i 1 ~ ~ ~ ~ ~ ~ ~ Submit in Duplicate H-21 186-0710 PERF ATTACHMENT MD TVD 9476-9481 S 8792-8796 9409-9506 S 8737-8816 9516-9526 C 8824-8832 9526-9536 C 8832-8840 9540-9550 C 8843-8852 9565-9575 S 8864-8872 9585-9606 S 8880-8897 9680-9722 S 8956-8990 H-21 Packer Repair To: Jerry Bixby /Clark Olsen, Well Operation Supervisors From: Donald Reeves -Wells Engineer Jennifer Starck -Pad Engineer Subject: H-21 Packer Repair PBHPDWL21-N Please perform the attached packer repair procedure: December 10, 2007 Est. Cost: $300M IOR: 300 BOPD 1 S Pull IBP, drift thru tubing tail (pre packer repair) 2 E Set composite plug (pre packer repair) 3 C Lay Sand Plug, Tbg punch, Cement Pkr, Mill cement, sand & composite plug 4 F MITIA to 2000 psi (post packer repair) Current Status: Shut In Non-Operable producer, secured with IBP Last Production: 01112/06: 636 bopd, 1476 bwpd (70% wc), 29 mmscfd Deviation: 38° max at 9850' DD, 34° at packer (8838' DD) Minimum ID: 3.725" (XN nipple at 8916' DD) Last Downhole Operation: 08/11/07 E-line conveyed Tecwel LDL to IBP at 8865' Last SBHP & BHT: 3244 psi and 218° F at 8800' TVD (11/2512000) Latest H2S value: 15 ppm - 03/14/03 Background H-21 is a shut-in Non-Operable producer well with TxIA communication confirmed to be across the production packer only. The packer leak will be repaired using CT to place a small cement plug in the annulus above the packer. A caliper run 05-13-03 indicates the tubing is in fair condition (attached) and no additional tubing leaks were seen on the Tecwel log. The well has only produced a total of 4 months since the caliper in 2003. Objective The objective of this procedure is to restore tubing integrity by repairing the packer leak with cement. The perfs will be protected with a composite bridge plug and 107 foot sand plua on top. Cement will be circulated into the IA through holes shot with a tubing punch gun and a cement plug will be left in the tubing. After the cement develops 500 psi compressive strength (~5 hours, will use sample in cement lab for time), the cement top, sand plug and composite bridge plug will be milled out. Following the packer repair, an MITIA will verify tubing integrity has been restored. H-21 Packer Repair AnnComm History: > 04/22/03: TIFL Failed 310 psi BUR overnight > 05/13/03: Caliper tbg & set TTP @ 8858'. > 06/23/03: Pulled TTP -leaks? > 06/30/03: Set IBP @ 8828' and > 08/31/04: Ran DGLVs in sta# 5, 4, 3 & 1 > 09/20/04: TIFL Failed, IA FL rose 3623' > 11/12/04: A/L line blinded > 02/12/05: MIT-T Failed TBG to IA LLR= 1.5 gpm. > 02/15/05: MIT-T Passed to 2500 psi, MITIA Passed to 2500 psi > 07/27/05: WIC changed from Trouble to Normal for POP & eval > 07/31/05: Pulled IBP from 8828' > 12/26J05: TIFL Failed (FTS) > 01 /01 /06: Set DSSSV > 01/03/06: TIFL Failed > 01 /13/06: Set IBP at 8865' M D > 01/30/06: MITOA Passed to 3000 psi > 02/27/06: MIT-T Failed 0.1 BPM @ 3000#. CMIT TxIA Fail. MITIA Pass to 3000 psi > 08/10/07: TecWel LDL found packer leak @ 8841' Contact Donald Reeves at 564-4080 (W), 980-5490 (C), 522-0904 (H), Jennifer Julian at 564-5663 (W), 240-8037 (C), 274-0929 (H) or Jennifer Starck at 564-5811 (W) with any questions or comments. Note: JJs cell phone may not work if called from the CT unit's mobile phone. You may need to use a different cell phone. CC: Well File 2 H-21 Packer Repair • Cement Detail 5-1/2" Tubing Sliding Sleeve 8763 Overshot top Packer top at 81 4-1/2" X-nipple 4-1/2" XN-Nipple a Sear out suk 9-5/8" Casing 7" Liner TOC target 8800' 2' Tbg punch 10' above sand top (8820'-8822') >and top target 8830' >-1 /2"x4-1 /2" XO top at 8849' 4-1/2" Tubing 4-1 /2" Composite plug at 8930' ;ement Volume 'ol. in Annulus (TOC to Packer): 838'-8800' x 0.0438 = 1.7 bbls 'ol. in Tbg: 830'-8688' x 0.0232 = 3.3 bbls Jote: extra cement in Tbg will be ontaminated down to 8800' 'otal Cement = 1.7 + 3.3 = 5 bbls 3 • H-21 Packer Repair Repair Target Pump cement in the IA to repair the confirmed leak across the 9-5/8" x 5-1/2" TIW packer at 8838' DD. Cement will be circulated into the IA thru holes punched in the tubing at 8820' to place cement top at 8800'. • LLR down IA across packer was 0.7 gpm at 3000 psi during the TecWel job on 08/11 /07. • IA volume to packer is 387 bbls. • Tubing volume to composite plug to be set at 8930' is 207 bbls. NOTE: Have Dowell lab run tests for cement. Cement blend is 15.8 Unislurry with 0.2% D046, 0.2% D065, and 0.35% D167. Speak with SWS lab (659-2434) 2 days prior to rig up. They must be available to run lab sample during the job. Slickline 1. RU SL & pull IBP and elements from 8865'. 2. Drift thru tubing tail at 8946' with 3.625" gauge ring and centralizer. RDMO. • A 3.625" gauge ring and centralizer is requested because the Baker Quick-drill plug to be run next has an OD of 3.595". E-line 3. RU E-line and make up 4-1/2" Baker Quick-drill composite plug (OD = 3.595") 4. RIH with composite plug and use tubing tally to tie in. 5. Set 4-1/2" Baker Quick-drill plug at 8930' DD mid-element. RDMO. This is in the middle of the 4-1/2" joint below the XN nipple. Please note the distance from the plug top to mid-element in the AWGRS report. The top of the plug will be tagged by coiled tubing to tie-in. CTU Packer Repair Note: All GLVs are dummied off. It is important that the IA is liquid packed during the cement repair. Shortly before the CT rig-up, shoot fluid levels on Tbg & IA to plan liquid volumes to order for job. 6. RU CTU and Dowell pumping service. NOTE: Rig up squeeze trailer to allow returns from both the IA and the CTxTbg annulus. Ensure enough lubricator is rigged up to pick up Tbg punch BHA in Step 15 below. This will ensure the flag stays accurate from run to run. 4 • H-21 Packer Repair • 7. RIH with sand dump nozzle (no checks). Tag top of Baker Quick-drill plug set previously by e-line. Pick-up until full string weight is observed. Correct depth to top of Quick-drill (this depth should be in AWGRS report from e-line). 8. Circulate 1 %KCI if necessary to liquid pack tubing. Bleed gas head off IA and pump Diesel down IA if necessary to bring liquid level to surface. 9. Mix stage of sand slurry as follows and follow CT Sand Plug RP: • 1100 Ibs of 20/40 river sand into 4 bbls gel (~6.5 ppg in 30# HEC gel). • Tubing interval to fill: 8930'-8823' = 107' (1.83 bbls) • Sand volume: 1.83 bbls x 600.6 ppb = 1100 Ibs sand • The depth of 8823' is not critical since the excess sand will be reversed-out to the desired depth of 8830' after placing sand and allowing time to settle. • Please note the actual volume of sand used in the WSR summary. 10. RIH to Quickdrill plug at 8930' and lay in sand slurry 1:1. 11. When tail of slurry is out of nozzle, PUH 200' while circulating 1 %KCI. Allow sand to settle for 30 minutes. Line up to pump down the backside (CTxTbg) taking returns up the coil to open top tank. 12. Come online down backside with 1 %KCI taking returns up the coil at max rate possible. Reverse circulate 10-20 bbls before running in hole to make sure any sand in the backside gets flushed down and into the coil. 13. RIH slowly and reverse circulate down to desired depth of 8830'. • The depth of 8830' is critical since the cement volume to be pumped is based on the sand top at 8830'. 14. Continue to reverse out while POOH to sweep the entire coil volume and ensure no sand is left in the coil. 15. POOH and MU BHA with 2' SLB tubing punch gun (in a 5' carrier). 16. RIH with tubing punch gun and tag sand plug top. Pick-up until full string weight is observed and correct depth to sand top (should be 8830'). Flag pipe and PU 8'. • If the Tbg punch gun is in a 5' carrier, picking up 8' will put top shot at 8820'. 17. Punch 2' of holes in the tubing from 8820'-8822'. 18. Pump down tubing and up IA to confirm circulation through the punched holes by opening up returns from the IA and holding 100-200 psi backpressure. Confirm 1- • H-21 Packer Repair . 1-for-1 returns to a 40 bbl open-top tank. If circulation is less than ~ 1/4 bpm, then holes will need to be re-shot. 19. POOH with spent tubing punch gun and MU 2.75" - 3.25" cementing nozzle (no checks). Begin running in the hole with nozzle. • Because coil flag will be used during following steps, kep track of any coil length that gets cut off when making up cementing BHA. 20. Batch mix 5.0 pumpable bbls 15.8 ppg Unislurry cement which will give 500 psi compressive strength in 5-7 hours and 2000 psi ultimate compressive strength. BHT at packer depth of 8838' DD is 200°F. • Catch a sample of the cement for QC testing. (This needs to go to the lab to determine when the blend reaches 500 psi compressive strength. Lab must be notified prior to the job 659-2423.) Once the blend is approved, conduct Job Scope meeting to ensure that participants know the upcoming job sequence. Ensure all gas is out of the system. Do not proceed with cement repair unless the tubing and IA are IicLuid packed and gas free. First step will be to lay in all cement in tubing and then pull CT to safety and park. Then IA will be opened and cement will be circulated into IA as detailed in steps below. 21. RIH to flag. Use flag to calculate depth necessary to place nozzle 5' from sand top. RIH to put nozzle 5' above sand. Line out cementers to the CT. Pump the following down the coil: • 10 bbl spacer water • 5_0 bbl Unislurry cement • Spacer water • 1-'/2# biozan gel With the IA SI, take returns up the backside (Tbg x CT annulus) to the 40 bbl tank while pumping. Maintain 100-200 psi backpressure. Pump 2 bbl Unislurry out the nozzle (100' of cement above nozzle) and then lay-in 1:1 while PUH (This step is to ensure that you don't dilute cement as you pull up). Monitor returns in the 40 bbl tank. SAFETY: 5.0 bbls of cement would leave a WCTOC at 8615' DD if no cement is placed in the annulus (assuming sand plug top at 8830' DD). 22. With the nozzle at safety of at least 8300', SD pumping, SI backside (Tbg x CT annulus). Compare pump volume to return volume in the 40 bbl tank. 23.Open IA for returns to the 40 bbl tank. Begin pumping at minimum rate down the coil. Circulate 1.7 bbls through the tubing punched holes and up the IA using the returns in the 40 bbl tank to help gauge volume. SI the IA and swap over to take returns up the backside (CTxTbg). Launch a nozzle ball while pumping KCI spacer 6 H-21 Packer Repair i spacer water. NOTE: With sand plug at 8830' bD, the final cement top in the tubing should be 8688'. 24.When 1-1/2# biozan hits nozzle RBIH and contaminate cement down to a maximum depth of 8800'. • Cleaning down to 8800' will leave top of cement in the. tubing at the same depth as the cement top in the IA. 25. POOH and jet with 1 %KCI to surface, washing thoroughly across all jewelry. 26. MU 2-718" Left-Hand motor and 3.60"-3.70" mill and RIH. Wait until lab sample has reached 500 psi compressive strength (about 5 to 7 hours). 27. Mill through ~30' of cement to sand top. "Turn and burn" (at 2 bpm minimum) thru 107' of sand to Baker Quick-drill pumping slugs of Flo-Pro as necessary to adequately lift solids. When motor work indicates Quick-drill has been reached, PUH a few feet, and pump large Flo-Pro sweep followed by at least one backside volume (180 bbls) of KCI to sweep sand to surface. • It is important to pump one backside volume and sweep sand to surface. If the MHA becomes stuck and cannot circulate while milling the Quick-drill, any sand left in the backside would settle around MHA. 28. RIH and mill through Baker Quick-drill. Push plug bottom to TD. 29. POOH & freeze protect the top 2500'. RDMO. Fullbore Post Repair 30. MITIA to 2000 psi, establish leak rate if fails. _ _~~ _ II~~_~ _ __+ _¢¢ _ _ __ • :~~ .; 8841' H-21 Packer Repair • - ,-. - 8 • • zvsr~vc st}*~~axY hLr 1~: ~~`G - ~ . c".'~~ JTS 4N RACR. +~O J:S liAbl. '" ~-2 FT QN RAGi~. ~dS77-ZS FT ELAN, 1:.< " T.dCT C`dGTN~ CTATM(`_ ~ ~r DppATE: ~ ..;.~ _~~ . SA C1 L +~" ~ 1+ i J~ ~4T r /D ~ .17 FT C3'JT . dT ' ITEiii LENGTH T4F ~0~'TE1M E7ESCRIPTZU;~ '~ lz' aSh~~r~. ~~t $t, b . ~o Q4~FS SS 89~,3~ ,~,a,~~rF~ ~ a, 1 J,. '7AtC ~ ~~ ~~78` 9 / ? 77 $g~•5.55 ''y`= fz °r'.~~1 •~4 Tug .Cu7 i c:..; M '; }41`~t 1 r -p L~ /, 37 (er, ~fJ $'~ 1? r '17 /J'Y=r S' -- ~~.• 'f2'' ?AFL ~'if~ $50~~•3 $$g l.'FO /d-%'~"l~.G,¢G'~i~'lub. ~~ .! ~~ ~____- ~'/z ` X' 0 alC~' ~G ~<h:1C ~ ~ <~i ~1 , ~rt ~a+ SS~f? r ~'~ T( Gtr _~~ir of ~r<~Eru~r~~ ~ s2~r s ~~~ ss~srr~ rte i 1 ~~~a~ t~ .JEfZSil~t n G s~rn rs.~a x.97 8838.37 Ttu~ ! ~ %z" ~ P Jt. _.~ ,9~f ~ .a3 88~~.9? ,51~ 7'"t~8~ Tub. ;.~~+~': S%z`rT' ,,~ ~ ~i.~:t X77 ,sz gg14ro3 N ,, t, t; 5l~.,r /W f' Jt, ___ .7n 8"~t,7,rz 877G,is~. ,~ ~~ ,, !r f C ! ,~1`rt{iN ..I~F~i1~ 2+F.4~' ~.~'3 ~» ~71a~:..1 ~"~~"I~,~.Z f'15 ~. ~ ~'uf3.st. ~` ~ ~~ ~ ~s zr~ s s7~z~ R s/z"r~~.~~~Ar~.~~~ { .~/~ lJ% l bt N~ ~ ~ ' r1 ~, 1' 1~ ` .' ~-'^~`~~ '- ' 1f f .'7T ~lfJ~ p f f t~ l 0 f r ~ c O ~ j ~ .c < +r ~ S P Nt /r !1 rr Ir {{ ~J / - ~ Q 4 i ~rtM d L11- ~i ~"• ~ ( /~ fYi f f} I ~ g ~ + 1LJQ. /.d Q ~ / ~ j A ( I.7 / ~+ rVfO ~~ EI 11 /[ 1/ ~ ~r m `i z~.~~` q.~i ~t,7~ 8 oa,`75 ,s z'` 1'~i'.i~. ~/ /d.32 (o$ •'h2 1 SG~~1.7~f /x'"~7'`L•8c7t~. gar, j /.* rt ~U is ~ N ,(~` r ~fi$. ' Y~ ~/ pp O.SlTi b r~ ~ i0 O i l ~F it Jt tr N ~'~ re U~f SF` _ J , !! ,~ LL pp ~~ ,,,, Q iT+V'f' t`f It /t J! // r~ "`~ ~~ r~~ ~ 7z sa3<~ C~f~ s '' ,."~!'z" v ..~1'. r r r~., -Q'if~7 $~ E ~~x {7~L-c~5u~'uia•:Bu ` oc ! ' J~-.S, ~r ,~ 7 ~' ~G4 ~I1~N~ ... t~ , j g7~~'~`~ If r, 1! 1r !/ ..... r ¢ J _..__. _ r~~k ~~ / . ' n4rr't''~3 X9.66' i ..2 ~$~! C1~i5 _ /~' PU(~ •~, ra,3 ~ ,84 7~59r~~. .SJz~,I'~,~-8~~b.t3~ti" sl ,;,'JAM Tubin+ ~f-9 - 1-s 9i 5335.80- 7z~~,8a u u 11 t, ;r ,' %z `{ ui' fit. f . 5 ~ $ ~$,$0 4t rt a ~, 4r _ ~ )a" ~uP .lf• fr7, .l4 f 7 .a/s"~'7'~'~`U7u6.Bu~ ~' ~ .f ,~ ~._ .2 T~ brw a 5ra -Jfs. 22ta'7.~a 3038,~~ :o~} „ ;,, tt t. at ,.:~:`r 1 }.~ ~ t I 3x27<'~~ .2+ ~ 11 rr n !, tf -I--_...._.,,~.~•L~ ~ AI+WiG' /z!'< u p .~+. ( } ry I,V~ ta.3 7Lj Dr. 30x8. -1 Q V !• 1 ~ES~ ~~' II~~-~11U (Lf 4J.,V "(~ .~ % ` 'Y~~.." ~k~~N ~,~ r1-f-s =~- 9~tZ, ~a6to.o'7 08.5 ;f ' 1:~F711 Y~1~~ Lf31J~rr<)c~ ~r ~.~ 3~3C 9 ~47TTQ3 ~a .~2 p~-;~ _ _.., 1,. ow fi4 a L;,~ ~: ,~ .~fl ,2'~~03 Q+~s .,. `~2~ ~t~ Y31 nl ~~ -..IBS. !'~~?,~ ,~r r! i? rr r '' y ~'Iz` X '7'~ cress o~rcr~ fi Tubr>J ~raa .~4,ao •OD 'iz`"» h ~?'3~~s ~z _ 7" ~i{binJ -~ t- 4 7~rTlJ y...C~ 2,20 :tL.`d ~'~.6~ ~~~J~~ '7'. 9 H-21 Packer Repair • _~ - t ,i.ls'a`. I~ ;1 - ~_ ~~-~, ~,~F~__~~-r_ ~~ ~; ~ `~r~C_.~~)'~~ .a ,.,il; L. ~.~. ~,T ~~r'J ~~_ _. ~ _i tl. ~~;Y_8: ~~F~'_`_•f c'?_ _i~ ~f __.. Pc~>>etrt~ti JI7 ~incC ,"~1~~'?I ~~-,>~ ~~'~ t~`all;i i-~li , :t~~n ~~~~~r ~i~=ta1l®s, Ca+~~l~y ~1 au I 'C ~ .~. o - {3tra~~ge ~rrni~ill;~tian ', 1,e,€1. ~ ~?~' -I i':% ,-_. _?118 .~ ~.8 - hG ~ ;ir:: -. ~ ~ `~" 0 i~i~iase F'I-t;tilP t°'; ~i~IC' ie,al. ~o I:..~.I ~ ~ ~, ' ~. (t~l~ '__":~ ~L~t ;yr~i 3 i__ .i f E ._~~,~ _ _ -~. z "I 10 H-21 Packer Repair • ~.t.-~ ~-_~, ~.~,~~,:~ c~aa_ ~~..~.~,~ ~ ~__,~ =.~:L F t.~;-ti~E~~~`,~ T~:~;T~.~`. ~4',FC ~i~ ~~,tri; i_~n~ ~_~,,,.. F~ ~'~;F°LC~F':T[:~~,.,~~L~-.~h,.~ ~~4i~ T , =.~e~ ~.~`5 ~. , -.:r~~~ ~_ ~ ~, , ~_ :: F err` rt,-, ,~.nal~.~_.. ~ Th:~~t-n::,~c~~ Pr'A~~tr,Y~€~xn ~racf ~4~tetlt Lt~„ _`~ ti~~alii ~s Da~yti~ge ~c~ttttig~:tr~tion ~. a~,t{~ .~ 1'e+~ .File 3 J-8 ( n~._ .r,; _ ~ "~ _- 1 +~k~! ~i~ .a_-fl ~ _.,..~t =~.~~~. 11 H-21 Packer Repair • ,~ , ~- ~ .~ ~?_~.. Lf1L. t_ _ ... 1 i~ - i '. ' -` ~ I t - ,_. .v~ i? fr ~ ~ylir~i~~l~a~t ID = ~.?"~~" '~ '~i" ~-~!~" C~71~ ~ [~ ~~F~L~ ~J "i ,~~~~ +'~7. "ffF`,^; ~. ~~, ,~G.}iYy2tG~~t^`[!(.}^^~~y ~A~ >> ~, I _'~.„'`'[~--I q~U ~iJr TC1F' ~~ 7" E4~t~ ur}€i4' Y44S . ~. .~., , t''` `'(.. ~ j'~ ~j5 i 'U C,L ~~}fl L `1~6 iY it ~~, i1l`~ ~~, 1 ~ a , . ~ ~ I ~ I '~3 C ': i. ~ , ~ ~ _ ~ d ~~, ~ r_' ~ ~ i ~i~1 ,` ~~~~ (~ t . ~ ., 8961' _ ...y I i .~.~_..o.......~t _. ..-,... ~ ...,~--. ~. i. . t _ ,~ .. I ... 3 ~_ 77 Li,~t 1'i.A i x '~ ~'I r r `f, \( ~l ~ 1 -. ~ :~~'~~u" ~1_I~~iE~ 7 1,25. ~ "~ Y ~ F} ~~ r~~ ~ r ."~ 1 t ~i li ~~ 1. "~' ~~ 1~_~€-1 ''Cry -- W __ n-~ r'r _ ; r~ I ~~ ~ ~= .r~:~ rv r i~X ~ +t_~~ €~~ ~' ,~ , STATE OF ALASKA '\ ALA~J OIL AND GAS CONSERVATION COMrvll...ŠION REPORT OF SUNDRY WELL OPERATIONS o Stimulate D Ot¡~ 2 1 2006 D WaiverD T_æmrR.~ C C .. D Re-enter Suspended Weli ,.8h ons. OrnmlSSIOn 5. Permit to Drill N :mr~ra~e Exploratory D! 186-0710 Service 6. API Number: 50-029-21575-00-00 9. Well Name and Number: 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Rj Stratigraphic L: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 76.51 KB 8. Property Designation: ADL-028284 11. Present Well Condition Summary: Total Depth measured 9961 feet true vertical 9179.76 feet Effective Depth measured 9919 feet true vertical 9146.59 feet Casing Length Size MD Conductor 80 20" x 30" 30 - 110 Surface 2663 13-3/8" 72# L-80 29 - 2692 Production 9119 9-5/8" 47# L-80 28 - 9147 Liner 1057 7" 29# L-80 8904 - 9961 ijf_ÇfI)lEQ. H-21 10. Field/Pool(s): Prudhoe Bay Field/ Prudhoe Oil Pool Plugs (measured) 8865 Junk (measured) None TVD Burst Collapse 30 - 110 29 - 2691.98 4930 2670 28 - 8520.54 6870 4760 8317.71 - 9179.76 8160 7020 Perforation depth: Measured depth: 9516 - 9550 Closed True Vertical depth: 8824.29 - 8851.76 ,",' K~ì Clì c" 2l'Hf; , \~ \1~\\\'Fr) f f'JJ {,s, (J,) '".-' , '~):,~ '/1 .,,1. ,,'I, 'i. .~.. . ' .,¡."W Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 27237 1611 0 SHUT-I N 15. Well Class after Droposed work: Exploratory r Development ;;¡ 16. Well Status after proposed work: Oil ¡;¡ Gas C WAG r Tubing: (size, grade, and measured depth) 5-1/2" 17# 4-1/2" 12.6# Packers and SSSV (type and measured depth) 5-1/2" TIW HBBP Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 593 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal L-80 L-80 27 - 8838 8838 - 8946 8838 RBDMS 8Ft FIB ,2 ?' 2006 Tubing pressure 1695 Service r GINJ C WINJ r WDSPL r Sundry Number or N/A if C.O. Exempt: N/A Printed Name Sharmaine Vestal ! Title Data Mgmt Engr Signatu~¥'~" '~.:/ Phone 564-4424 Form 10-404 Revised 04/2004 0 R \ G \ N A L Date 2/22/2006 Submit Original Only ) ) H-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE I SUMMARY 1/13/2006 SET BAKER 2.5" IBP AT 8865' MID-ELEMENT DEPTH, FN IS LOCATED INSIDE 4 1/2" TUBING. IBP IS 11' LONG, HAS A 1.375" FISHNECK, 1840# DOWN JAR TO EQUALIZE, 5500# UP JAR TO RELEASE. IBP ALSO HAS TWO 5 3/4" SEALING ELEMENTS AND ONE 1" STIFFENER RING. TIED INTO TUBING TALLY. SLACKED OFF ON IBP TO CONFIRM SET BEFORE POOH. **NOTIFY DSO OF WELL STATUS** FLUIDS PUMPED BBLS 1 Diesel 1 TOTAL H-21 (PTD #1860710) Classified as Problem Well e e Subject: H-21 (PTD#1860710) Classified a~Problem Well From,: "Reeves, Donald F" <ReevesDf@bp.cöm> Date: Thu, 29 Dec 2005 14:25:27 -0900 . '.' .'. Tiff 'i~PB,"" . ,Area Mgr" <GPBG' .' L@bp.com>, "~... <ibv~n:Ross @bp.com:>;l!rNSU· "W W eIrOper~iê( . ..peMs<>r" <f~~TJrADWW OperationSSu~l~'j p:com>, "G~B, Wells:,ppt Bng". . <G~B~ellsOptEng@bp.com>,t'A'GCC J 1m ~egg" <JimJegg@adml. "'AOG~CWWinton A:uÞ¢it (E-mail).....<wintonai:T.state.ak.us~.. "NS . Co~p ., ti()l1;,:supervf~df;h <NSUAnWWL&:C~: f:.~§or@bp.cÆh>,:,~· <join ut~@bp.com>, "GPB,Optimization En'tij~zationEn~@·.··.. . ~~, .~. - ~r:;,~dCO\, ~~m>, " p.cml> ikê'':~Mike.W'"'' .. .~c,om>, ,~PB".... cqf'~.W Well I '. '.. &i.W~,~" SUAD'YWellfute ityE¡ineer@JtP.~m>, !,acl( L/', .. ..W@bP;~~m>,..> CÐ~~U:M"' CODY 0 (VECO COdy.MCCo1tÙJ®bP.CO.. Holt, Ry. . VECO)~yan.Ho1t@bijí:o~ .... .'. m " ',T' .i-<.!K- Hello All, Well H-21 (PTD #1860710) has sustained casing pressure on the IA and has been classified as a Problem well. Wellhead pressures on 12/26/05 were 2360/2140Nac. The well failed a TIFL on 12/26/05. The plan forward for this well is as follows: 1. SL: Set DSSSV 2. DHD: Re- TIFL Attached is a wellbore schematic. Please call if you have any questions. «H-21.pdf» Thanks, Donald Reeves Well Integrity Engineer - Filling in for Anna Dube 907-659-5102 907-659-5100 Pgr 1154 ;:¡;;;.«(" l\j'f:Ji.h~~í¡;·r, ",'\i¡iI~ ,;" "'......./ í ..:..:.:..' Content-Description: H-21.pdf Content-Type: application/octet-stream Content-Encoding: base64 ::J-A <;~'Þ (ps: ) 2¡AO Þ~f' (F;') 6'£.70 to U;r:l{ P 3(.,ð¿,o ðl( fRJ Q) 4cè 2. ¿, tfqlc ~fA.t f' '-:-) ,. ~c?4ti (2f1a(D~ 1 of 1 12/30/2005 10:30 AM TREE = 6-3/8" fv1CEVOY WB..LHEAO = fv1CEVOY A CTUA TOR = OTIS KB. ELEV = 76.51' H-21 I SAFETY NOTES: IA X OA COMM. BF. ELEV = 47.51' KOP- 5050' 2044' H 5-1/2" OTIS SSSV LAND NIP, 10 = 4.562" I Max Angle = 38 @ 9850' . OatumMO- 9581' OatumTVO - 8800' SS GAS LIFT MANDRELS ST JIll) lVO DEV TYPE VLV LA TCH PORT DATE 5 3019 3019 0 CA DIVIY RM - 08/31/04 13-318" CSG, 72#, L-80, 10 - 12.347" 2692' 1-4 ~ 4 5316 5305 20 CA DIVIY RM - 08/31/04 3 7259 6943 38 CA DIVIY RM - 08/31/04 l 2 8495 7975 32 OTIS DIVIY RA - 10/19/86 1 8692 8141 33 CA DIVIY RM - 08/31/04 Minimum ID = 3.725" @ 8916' 4-1/2" OTIS XN NIPPLE 8763' H5-1/2" OTIS XA SLIDING SLV, D - 4.562" I I I ...----i. 8823' HTIW OVERSHOT SEAL ASSY f 8831' 3-318" BKR IBP (06/30/03) 1 5-1/2" lEG, 17#, L-80, .0232 bpf, 10 = 4.892" 8838' I ;8 ~ 8838' 1-19-518" x 5-1/2" TlW HBBP A<R, ID =4.75" I ~ ---r ITOP OF 4-1/2" TBG 8838' r-- 8838' 5-1/2" x 4-1/2" XO 1 . I 8881' 1-14-1/2" OTIS X NIP, 10 = 3.813" ITOP OF 7" LNR 8904' . I 8916' H4-1/2" OTIS XN NIP, D = 3.725" I 14-1/2" TAILPIPE, 12.6#, L-80, .0152 bpf, 10 = 3.958" 8946' I 8946' 4-1/2" BKR lEG TAL, 10= 3.958" I I 8942' 1-1 ELMO TT LOGGED 09/25194 I 19-5/8" CSG, 47#, L-80, 10=8.681" 9147 I .. .. ÆRFORA TION SUMVlARY REF LOG: GEARI-lð.RT-BHCS 05/12/86 I 9212' MARKER JOINT 1 ANGLEAT TOP PERF: 36 @ 9476' Note: Refer to Production DB for historcal perf data SIZE SPF INTERVAL OpnlSqz [)II.TE 3_3/8" 6 9476 - 9481 S 01/20194 3-318" 6 9490 - 9506 S 01/20/94 [ 3_318" 6 9516 - 9526 0 04112/94 3_318" 12 9526 - 9536 0 01/23194 3_318" 6 9540 - 9550 0 01/25194 3-318" 6 9565 - 9575 S 01/20/94 3-318" 6 9585 - 9606 S 01/20/94 2-7/8" 4 9680 - 9722 S 01/20/94 I PBTD I 9919' 17" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 9961' DATE 05/16/86 09/20/01 11/08/02 02/09/03 05/03/03 06/30/03 REV BY COI'VTlll8'-nS ORIGINAL COM PLETION CORRtCTIONS WAIVERSAFEfY NOTE DELETEWAlVffi SAFETY NOT GLV UPDATE SET IBP & CO RRECTION [)II. TE REV BY COMMENTS 08/31/04 WRRITI. GLV C/O PRUOHO E BA Y UNIT WELL: 1-1-21 PERMIT No: 1860710 A A No: 50-029-21575-00 SEC21, T11 N, R13E, 534' FNL & 1266' FEL BP Exploration (Alaska) RNlKAK KBltlh A 1D1TP A 1D/KK BJIINKK Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 05/08/03 Color Well Job # Log Description Date Blueline Prints CD E-02A ~ c~ --~_.]~ -7 MEMORY PROD PROFILE 03115103 E-31A ~,~['~--/'~ ~ MEMORY PROD PROFILE 08108/02 M-29A ~ ~ O~ PDC & TEMPE~TURE 04/15103 F-04A ~ ~-f~O 23097 MCNL 03/02103 H-21 t ~'O~ ~ 23074 RST-SIGMA 0~/30103 D.S. ~-32A ~- ~,~ 23083 MCN~BO~X 02/02103 D.s. ~-os, /ffS~V 2308~ RST-S,~=, 0~/=3/03 ~D.S. 7-29B ~-~;~ 23096 MCNL 02/15103 'D.S. J5-38A ,~O~-0/~' 23089 LINER TOP TIE-IN MG~CCL 02/10103 D.S. J5~8A~OO ~ 23098 MCNL 02119103 _ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH '1'O: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: HAY 1 3 2005 ,~OANNEE) SEPt 5 20[13 Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATT'N: Beth Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 2772 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay 05/08/03 Color Well Job # Log Description Date Blueline Prints CD E-02A j ~ '~ '"-{ .-~,"~ ~IEMORY PROD PROFILE 03115103 1 E-31A' .~.,~.?~[r~'J-' ~/IEM6RY PROD PROFILE .... 08/08/02 M-29A -~,~0)~'7 z'~.(~ PDC & TEMPERATURE 04/15/03 1 . .. F-O4A"~(~l~- ~f '~ 23097 MCNL 03/02/03 1 1 H-21 ..... ~'~1~"'~ ! _ 23074 RST-SIGMA "' 01/30/03 1 ~ .... D.S. 1-32A-30~-- ~'_~'~ 23083' MCNL/BORAX ..... 02/02/03 :1 t . . D.S. 5-06A I'~5''O~' 23056 RST-SIGMA 01/23/03 1 D.S. 7-29B .i .C~'~,,..~, 23096 MCNL " 02/15/03 1 1 D.S'.' 1~-38A I .~ I,~ ; ~)~1, 23089 LINER TOP TII~-IN MGR/CCL' 02/10)03 D.S. 15.-4SA !.~,~' ,--~ 230.98 MCNL 02/19/03 1 1 '- , , .... , , ........... ...... ,, , , , ,,, PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth C:ANN L, SEP 0 ..9 2003 f12_h2 l_bp- respon se_ll- 26-02. txt subject: RE: PBU 02-1lA, F-12, and H-21 (Class B3 wells) returned to produ ction Date: Tue, 26 Nov 2002 18:29:17 -0600 From: "Rossberg, R Steven" <RossbeRS@BP.com> To: "'Tom Maunder'" <tom_maunder~admi n. state, ak. us>, "Nsu, ADW wel I Integri ty Engi neer" <NSUADWWel 11ntegri tyEngi neer@BP, corn> CC: "NSU, ADW well Operations Supervisor" <NSUADWWel 10perati onsSupervi sor~BP, corn>, "Frazier, Randy B" <Frazi eRB~BP, corn>, AO6CC North slope office <aogcc_prudhoe_bay@admi n. state, ak. us>, Jim Regg <~ i m regg~admi n. state, ak. us>, M1 ke-Bi ll <mi ke_bi 11 ~admi n. state, ak. us>, cammy oechsl i <¢ammy_oechsl i ~admi n. state, ak. us>, Daniel T Seamount JR <dan_seamount~admi n. state, ak. us>, "6ray, Thomas B" <6ray. TB~BP.com>, "Jacobsen, Rosanne M" <JacobsRM~BP.com>, "NSU, ADW well Operations Supervisor" <NSUADWWel 1 Ope rati onsSupervi sor@BP, corn>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&Compl eti onSupervi sor~BP;,com>, "NSU, ADW well Integrity Engineer <NSUADWWelllntegrityEngineer~BP.com>, "Phillips, chris J" <PhillicJ~BP.com> Tom, This note is in response to your E-mail of November 22, 2002, expessing disagreement with BP's assessment of wells H-21 and F-12 . BP believes that diagnostic testing indicates that these wells contain two competent barriers; thereby, meeting both BP internal waiver policy and AO~CC stipulations as stated in your letter of october 29, 2002. The following is intended to clarif,y our testin~ procedures and provide a more detailed explaination of BP $ rational or waivering these wells and returning them to production. H-21: The integrity of the tubing, including the packer and wellhead packoffs is confirmed by TIFL or MIT. In the case of H-21, a passing TIFL indicating zero pressure response and no measurable fluid level rise in the TA , confirmed the integrity of the tubing hanger seals and the tubing. A positive pressure packoff test (PPPOT) performed on H-21, or any other well, is intended to pressure test the void between the upper and lower packoffs. A PPPOT iS not used as the defining criteria for tubing integrity. A failure simply indicates one of the seal elements is leaking, but does not definitively confirm or negate tubing integrity. If the body seal in the tubing packoff would have been leaking, there would have been either fluid level or pressure response in the IA. AS pointed out in your EM, OA integrity was demonstrated by MIT. In combination, the passing TIFL and the successsful MITOA demonstates two compentant barriers. BP has found through experience that 'the results of failing PPPOT$ will normally not change over time and it is our practice not to retest after a failure. The PPPOT performed on 4/19/02 failed. This was the rational used in our decison not to retest the tubing hanger packoffs in well H-21. Therefore, pretest casing, annuli and tubing pressures for the PPPOT were not included in the data submitted to the AO~CC. F-12: Page 1 fl2_h 2 l_bp- res pon s e_II- 26- 02. txt we agree with your observation that there is a gap in the recording of fluid level data on the TIFL. This TIFL was certified as passing based on available fluid level data and the fact that there was no pressure response in the IA. BP believes this test is valid and confirms tubing integriy; however, in order to supply the complete data set, we will perform a second TIFL. AS explained above, failing PPPOTS do not define integrity. This applies to both the tubing and casing. Tn F-12, the upper tubing seals were confirmed by the passing TIFL. LeaKing seal s would have resulted i n a fl uid level and/or pressure response in the IA. The production casing packoff was confirmed by the passing MITOA. Had these seals been leaking there would have been pressure response in both the IA and OA. In combination, the passing TIFL and the successsful MITOA demonstates two compentant barriers. BP believes that overall well integrity has been adequately demonstrated for both wells H-21 and F-12. We agree that there is a data gap in the F-12 TIFL and will retest within 30 days; however, outside of this data ga.p, we believe that the TIFL in question adequately defines integrity. It ~s our position that these wells are safe to produce and that we have sufficiently met criteria defined in BP policy and the AOGCC stipulations. As requested I have attached copies of the H-21 and F-12 wellbore diagrams. If you would like to discuss this further, please call me. Regards, Steve Rossberg (~BPU well s Manager 564-5637 -Original Message From: Tom Maunder [mailto:tom_maunder~admin.state.ak.us] sent: Friday, November 22, 2002 3:51 PM TO: NSU, ADW well Integrity Engineer Cc: NSU, ADW well operations Supervisor; Rossberg, R Steven; Frazier, Randy B; AOGCC North slope office; Jim Regg; Mike Bill; Cammy Oechsli; Daniel T Seamount ]R subject: Re: PBU 02-1lA, F-12, and H-21 (Class B3 wells) returned to producti on Joe, John, et al: we have received two messages from Problem wells regarding the startup of 4 B3 type wells. The specific wells are DS 02-1lA, H-21, F-12 and os 02-18A We call your attention to the commission's letter of October 29, 2002 to Mr. Randy Frazier (copy attached), where the necessary integrity requirements for returning the "A/B3" wells to operation were listed. In Item 3, it is noted that, ..."the report must include pre-test pressures in all casing annuli and the shut in tubing pressure." Initial pressures are noted on MITs and TIFLS, however initial pressures are not noted on packoff tests This information should be included on future reports. Item ~ requires that "Any well exhibiting communication across more than 2 barriers must be secured." ~e have examined the information submitted and in 2 cases DO NOT AGREE that the conditions necessary to satisfy the 2 barrier requirement have been met. The specific wells that we feel have Page 2 f12_h2 l_bp- response_il- 26-02. txt not met the requirements of the october 29 letter and BP's own internal criteria as explained to us are H-21 and F-12. with regard to H-21, the MIT OA and TIFL appear to satisfactorily demonstrate that the OA has pressure integrity and that there was no measured fluid rise in the IA. The tubing hanger packoff test FAILEO and it is specifically noted that the tubing hanger neck seals were leaking when the test was performed April 19, 2002. Please explain how the requirements of the commission's letter and BP' s own internal poli cy for competent tubing (including tubi ng packer and packoffs) has been satisfied? we also find it interesting that a more recent packoff test has not been conducted as opposed to one 6 months in the past. The information supplied for the other wells were much closer in time. with regard to F-12, both the tubing hanger and production casing packoffs are listed as FAILING. The TIFL has contradictory information recorded on it and it appears incomplete. A1 though some information is recorded for the 6' 45 observation, the fluid level at that time is not recorded, one is left to infer that the fluid level did not change from the previous observation, however that may not be valid. Again, please explain how the requi rements of the commission's letter BP's own internal policy for competent tubing (including tubing packer and packoffs) has been satisfied? You are requested to re-test and confi rm the packoff (tubing hanger and production casing) competency on wells H-21 and F-12 and the TIFL on F-12 and submit the information to the commission. Successfully passing these tests in conjunction wi th the earlier testing will confirm the tubing as a barrier on the subject wells. If the tests are not successful, the wells must be secured until the competency of the tubing can be demonstrated. Please contact Jim Regg at 793-1236 or myself at 793-1250 with any questions. The requested test results should be available for the Commission's inspection (email response is acceptable) on Tuesday November 26. Please also include a current wellbore drawing for the subject wells and plan to include a well drawing with subsequent test information submissions. Your field personnel should also contact the North Slope Inspector at 659-2714 or page them at 659-3607 approximately 24 hours in advance of the work so that the Inspector may witness the testing as they are able. Tom Maunder, PE AOGCC "NSU, ADW well Integrity Engineer" wrote' Gentlemen,The following "B3" category wells have been returned to production' F-12 (on line 11/08/02 ~ 20:00), 02-1lA (on line 11/09/02 @ 11:00), and H-21 (on line 11/10/02 ~ 18'00). Attached please find the test records that demonstrate the two competent barriers required to produce these wells.oave Reemfor Joe Anders 659-5102 Mobil · 943-1154 Pager' 659-5100, x1154 Page 3 Name: H-21. pdf Type: Encoding: Name: F-12.pdf Type: Encoding: f12_h21_bp-response_ll-26-02.txt H-21.pdf Acrobat (appl i cati on/pdf) quoted-p ri ntabl e F-12. pdf AC robat (appl i cati on/pdf) quoted-pri ntabl e Page 4 TREE = 6-3/8" IVICEVOY WELLHEAD = MCEVOYI i ~llll~ .~ SAFE-FY NOTES: ***IA X OA COMM. OPERATING ^cru^TO.: OT,S I-I-21 , SSU.E OFT.E ,3-.,8" ^.NU.US MUST .OT KB. ELEV = 76.51'= = ~-- EXCEED 2000 PSI (11/02/02 WAIVER)*** BF. ELEV = 47.51' KOP = 5050' Datum MD = 9581' Datum TVD = 8800' SS GAS LIFT MANDRELS ~, ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 8692 8065 33 OTIS IRA L [ ~ 88[~.~~qTIVV PBR SEAL ASSY REFLOG: GEARHART-BHCS 05/12/86 ' I 9212' ANGLE AT TOP PEP, F: 36 @ 9476' Note: Refer to Production DB for historical perf data II SEE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9476 - 9481 S 01/20/94 3-3/8" 6 9490 - 9506 S 01/20/94 r'l LJ 3-3/8" 6 9516 - 9526 O 04/12/94 3-3/8" 12 9526-9536 O 01/23/94 3-3/8" 6 9540 - 9550 O 01/25/94 3-3/8" 6 9565 - 9575 S 01/20/94 3-3/8" 6 9585 - 9606 S 01/20/94 2-7/8" 4 9680 - 9722 S 01/20/94 DATE REV BY COIV~E~I'S I DATE REV BY GOhlvl~qTS F~UIhHOE BAY UNIT 05116166: ORIGll~ L ¢OM~LE'I'ION I WELl..: H-21 02/16/01 SIS-SLT CONVE~TEDTO CANVAS i FERMITNo: 1860710 03/01/01 SIS-LG FINAL APl No: 50-029-21575-00 09/20/01 RN/KAK CORRECTIONS Sec. 21, T11N, R13E 11/08/02 KB/th WAIVER SAFETY NOTE BP E~ploration (Alaska) PERFORATION SUIVivlARY REFLOG: GEARHART-BHCS 05/12/86 ANGLE AT TOP PEP, F: 36 @ 9476' Note: Refer to Production DB for historical perf data SEE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 9476 - 9481 S 01/20/94 3-3/8" 6 9490 - 9506 S 01/20/94 3-3/8" 6 9516 - 9526 O 04/12/94 3-3/8" 12 9526 -9536 O 01/23/94 3-3/8" 6 9540 - 9550 O 01/25/94 3-3/8" 6 9565 - 9575 S 01/20/94 3-3/8" 6 9585 - 9606 S 01/20/94 2-7/8" 4 9680 - 9722 S 01/20/94 DATE REV BY COIVIVIENTS DATE REV BY cOrvlVIENTS 05/16/86 ORIGINAL COMPLETION 02/16/01 SIS-SLT CONVERTED TO CANVAS 03/01/01 SIS-LG FINAL 09/20/01 RN/KAK CORRECTIONS 11/08/02 KB/th WAIV ER SA FETY NOTE MEMORANDUM -TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, <~,~i-~.~.~,~ DATE: April 22, 2001 Commissioner Wl ~ ~' i Tom Maunder, ~~~ P. I. Supervisor % I~' ~ \ FROM: Lou Gdrnaldi, SUBJECT: Petroleum Inspector SVS Misc. tests 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. Merv Liddeiow (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 groat results. The well houses were all dean 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. Attachment: SVS PBU H-pad 4-22-01 LG.XLS . NON-C.ONFIDENTIAL SVS PBU H..l:md 4-22-01 LG Alaska Oil and Gas Conservation Commission Safety Valve System.. Test Report Operator: BPX Operator Rep: Merv Liddelow AOGCC Rep: Lou Grimaldi Submitted By: Lou G. Date: Field/Unit/Pad: Prudhoe Bay field, H-pad Separator psi: LPS 157 HPS 22-Apr 650 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& 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-II 1800680 157 125 100 P P OIL H-12 1800670 H-13 1810170 650 550 525 P P OIL H-14A 1980680 H-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 H-24 1853050 157 125 115 P P OIL H-25 1852680 650 550 550 P P OIL H-26 1852770 157 125 95 P P OIL H-27 1852360 H-28 1880440 H-29A 1980380 650 5501 530 P P OIL H-30 1880350 650 550: 525 P P OIL H-31 1940140 H-32 1940250 157 125 100! P P OIL H-33 1940380 650 550 515! P P OIL H-34 1971640 157 125i 125 P P OIL H-35 1951490 650! 550 515 P P OIL H-36A 2000250 H-37 1971020! 157 125 125 P P OIL W~'l/16/O! 20 Components: p~_~el~a~ll~es: 0 F~sr~ pad0~q_~-~ Well Number Permit Separ Number PSI Set PSI L/P Trip Remarks: Great test, nO failures. Test Code 'Test[ TestI Date Code] CodeI Passed Oil, WAG, GINJ, GAS or CYCLE RJF 1/16/01 Page 2 of 2 SVS PBU H pad 4-22-01 LG LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 26 May 1995 RE: Transmittal of Data Sent by: PRIORITY MAIL Dear Sir/Madam, Enclosed, please find the data as described below: H-21 (42-21%1~-133~.. H-33 (32-21-11-13). F-34 (44-35-12-13) # DESCRIPTION 1 PLS FINAL BL+RF 1PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF ECC No. Run # 1 5973.03 Run # 1 6178.03 Run # 1 6181.04 Please sign and re~Rodney D. Paul~s ~ Atlas Wireline Se~ces ~ B Street// L /-'-) Anch~ge, AK 99~ .. ' Recezved bv~~ ~ ~ Date- ~ ,'% ~ ,.~ STATE ~,"~KA OIL AND GAS CONSERVATION COMMI~ )N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other × 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 534'SNL, 1266' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 2362' SNL, 928' WEL, SEC. 22, T11N, R13E, UPM At effective depth 2666' SNL, 164' WEL, SEC. 22, T11N, R13E, UMI At total depth 2704' SNL, 189' WEL, SEC. 22, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 9961 feet 9179 feet Plugs (measured) 6. Datum elevation (DF or KB) KBE = 76.51 AMSL 7. Unit or Property name Prudhoe Bay Un# 8. Well number H-21 (13-22-11-13) PBU 9. Permit number/approval number 86-71 / 10. APl number 50- 029-21575 11. Field/Pool Prudhoe Oil Pool Effective depth: measured 9893 feet true vertical 9049 feet Junk (measured) Casing Length Size Structural -- Conductor 62 20X30 Surface 2644 13-3/8 Intermediate 9100 9-5/8 Production -- Liner 1057 7 Perforation depth: measured 9516-9534', 9540-9550', Cemented Measured depth True vertical depth BKB 8 cuyds 110 110 3723 cf 2692 2692 575 cf 9148 8521 419 cf 8904-9961 8317-9179 {Sqzd 9476'-9481', 9490-9506', 9565-9575', 9585-9605', 9680'-9722'} true vertical subsea 8747'-8762',8767'-8775', {Sqzd 8715'-8719',8726'-8739', 8787'-8795', 8803'-8819', 8879'-8913'} Tubing (size, grade, and measured depth) 5-1/2"L-80 to 8838' with 4-1/2" tailpipe to 8946' Packers and SSSV (type and measured depth) 9-5/8" TlWpacker at 8838'; 5-1/2" ball valve nipple at 2044' feet 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure SI 2284 9291 1869 0 Tubing Pressure 250 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended 17. I hereby certify that t?e forecming is true and correct to the best of my knowledge. Signed (~-'J.~ ~. ~//'¢::2,/v~ Title Senior TechnicalAssistantll Form 10-404 Rev 06/15/88 Service Date ,~-/$o ~ SUBMIT IN DUPLICATE 01/18/94 WELL H-21(13-22-11-13) Reperf/NRWO Operation A NRWO GSO Maraseal Gel was performed using the following fluids below: SUMMARY Well looked like a "drinker" from the start. Some operational delays due to trouble with Nowcam's pump. Pumped 45 bbl 12% HCI/20% Xylene per program, but could not evaluate WHP response because well was on a vacuum. However, coil pressure did drop by several hundred psi during the acid stimulation. Pre - cement injecfivity was 7.5 BPM at 425 psi. Spotted FW spacers both above and below the perfs to keep cement seperated from seawater. Laid in the cement blind, and did not see a pressure response until 30 bbl of cement out the nozzle. Ramped conservatively to 3000 psi. MI's measurements, however, indicated only 5 bbl cement put behind pipe. The remainder of the delay before the pressure response was due to void space in the tubing. Well showed a definite leak at the end o f the squeeze period, which got worse during the reverse out. Final injecfivity was 1.5 bpm at 1720 psi. Suspect that SqUeeze is leaking in at least Zone 3. Plan is to back lift gas into the well. to surge any peff debris/unsound cement out of the perfs, then resqueeze. - CEMENT SUMMARy .. FIRST STAGE (18bbl) · 15.8 ppg Class "G" low fluid loss cement including Lab thickening time:. ' 8-hfs; 30.:min @ 165 BHCT 0.62% FL-33 "Lab fluid loss: 42.4 CC/30 min 0.1% CD-32 Field fluid loss: 40.8 CC/30 min .~ 0.33% R-11 Live cell loss: (22 1 g HS'FP'6L "Lab AP1 filter cake: " Field API filter cake: 7/8" SECOND STAGE (14 bbl): 15.8ppg Class "G" high fluid loss cement includingLab thickening time: 8hfs, 20 min @ 165 BHCT 0.45% FL-33 Lab fluid loss: 60 CC/30 rain 0.1% CD-32 Field fluid loss: 60.4CC/30 min 0.35% R-11 Live cell loss: (I2 1 g HS FP-6L Lab API filter cake: 7/8" TOTAL BBL pumped 32 Field API filter cake: TOTAL BBL recovered 27 Live cell cake: 2.0" · RECEIVED · MAY 17 1995 Alaska Oil & Gas Cons. Commission 1-1/16" 353 422 46 296 25 FLUIDS PUMPED BBLS. DESCRIPTION Bullhead Sea Water SW Circulate down coil. 15 % HC1 with 20 % Xylene SW Overflush Acid and Displace Coil Effluent Water (Preflush) Page 2 32 5 74 657 30 35 WELL H-21(13-22-11-13) Class "G" Cement ) Effluent Water (Postflush) Sea Water (Displacemen0 Sea Water (Jetting and Reversing) Biozan Methanol 01120194 A NRWO Maraseal Gel was performed using the following fluids below: SUMMARY Fluid level was driven down with lift gas last night. Opened well to flowline and bled WHP from 1100 to 250. Shut wing. WHP built up to 1100 while RIH. Initial injectivity was only 1.2 BPM @ 1900 psi. This is less than at the end of the reverse out on the 18 th. Ordered 15 bbl 12 % HC1 / 20 % Xylene and proceeded to cool sump. Got good acid response with post-acid injectivity of 2 BPM @ 380 psi. Unfortunately, obtained bbl/bbl returns before cement was due at the nozzle. Ramped up squeeze aggressively and it looked like we put 1 bbl cement behind pipe. .Recovered total of 25 bbl cmt using 358 bbl sw. Dropped ball and jetted peris at 1.5 bpm. performed second reverse out. Well pressure tested @ 2300 JFT. Backed in lift gas recovering 80 bbl sw. POOH, close swab and circulated 50 bbl sw to insure coil clean for mud motor job. F/P coil w/35 bbl meth and rd. NOTE: The previous two squeezes both broke on reverse out. Requested BP settlement tests on both lab and field cement blends for this job. CEMENT SUMMARY 15.8 ppg Class "G" cement including 0.62% FL-33 Lab fluid loss: 0.1% CD-32 Field fluid loss: 0.33% R-11 Live cell loss: 1 g HS FP-6L Lab API filter cake: 27 BBL pumped 25 BBL recovered Lab thickening time: 8hfs, 30min @ 165 BHCT 42.4 CC 40.0 CC 7/8" Field API filter cake: 3/4" Live cell cake: 2 3/4" ACID SUMMARY 12 % HCL W/20% XYLENE 25 PPT FERROTROL 210 4 GPT ACI-274 4 GPT NE-41 7 GPT S-500 Page 3 1/25/94 WELL H-21(13-22-11-13) 8 359 16 69 18 27 5 48 495 0 35 FLUIDS PUMPED BBLS. DESCRIFrlON Pump for freeze protection while RIH. SW Circulate Sump, rtns to surface. 12 % HC1 with 20 % Xylene SW Overflush Acid and Displace Coil Effluent Water (Preflush) Class "G" Cement ) Effluent Water (Postflush) Sea Water (Displacemen0 Sea Water (Jetting and Reversing) Biozan Methanol The following interval were reperforated using 3 3/8" guns, 6 SPF, random orientation and 60° phasing. 9526' - 9536' MD 9540' - 9550' MD 4/12/94 The following interval were reperforated using 3 3/8" guns, 6 SPF, random Orientation and 60° phasing. 9516, - 9536' MD RECEIVED MAY 1 7 1995 N~ka Oil & Gas Cons. Commission Anchota, i~ ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 28 February 1994 RE: Transmittal of Data ECC #: 5973.01 Data: NONE Dear Sir/Madam, Reference: BP H-21 (42-21-11-13) PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Prints/Films: 1 COLLAR LOG FINAL BL 1 COLLAR LOG FINAL RF Sent by U.S. MAIL Run # 1 Run # {~ Please sign and return to: Atlas Wireline Services Petrophysical Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Date: ALASKA OIL & GAS CONSERVATION COMMISSION Attn. LARRY GRANT 3001 PORCUPINE DR. ANCHORAGE AK, 99501. USA Date: 27 April 1994 RE: Transmittal of Data Sent by: ANCHORAGE EXPRS Dear Sir/Madam, Enclosed, please find the data as described below: Y-36 (41-27-11-13) DESCRIPTION 1 CN/GR FINAL BL ~ CN/GR FINAL RF SEPIA X-28 (11-07-10-14) 1 SBT/GR/CC~ FINAL BL 1 GR/CCL JEWL.FINAL BL ~ SBT/GR/CCL RF SEPIA _ 1 GR/CCL JEWL.RF SEPIA 1 PFC/PERF FINAL BL /~'PFC/PERF RF SEPIA q~j~ X-35 (11-12-10-13) 7(--'Z~-- H-04 ~--~lq X-28 (11-07-10-14) I GR/CCL JEWL.FINAL BL fl GR/CCL JEWL.RF SEPIA 1PFC/PERF FINAL BL /~ PFC/PERF RF SEPIA 1 DIFF.TEMP. FINAL BL /1 DIFF.TEMP. RF SEPIA i PFC/PERF FINAL BL /'I"PFC/PERF RF SEPIA ~O-C~1 H-21 (42-21-11-13) 1 PFC/PERF FINAL BL -~ PFC/PERF RF SEPIA ~'0~ F-42 (22-35-12-13) 1 CN/GR FINAL BL /~ CN/GR FINAL RF SEPIA ,,~ r ~- K-11 (32-33-12-14) C[L-~'''-' ?"2~ H-33 (32-21-11-13) 1 CN/GR FINAL BL 1 CN/GR FINAL RF SEPIA 1 PFC/PERF FINAL BL ~ PFC/PERF RF SEPIA ECC No. Run # 1 6054.03 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 Run # 1 6103.01 5608.03 6168.01 4952.01 4112.03 6103.02 5973.02 5953.04 6189.00 6178.01 Cont/ ~\~ R-34 (13-34-12-13) I PFC/GR/CCL FINAL BL ~'1 PFC/~R/OOL RF S~.P~A Run # 1 6083.05 Run Please sign and return to: Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Attn. Rodney D. Paulson Received. by: Please sign and return to: Sonya Wallace (MB 3-3) Petrotechnical Data Center BP Exploration (Alaska) Inc. 900 East Benson Boulevard Anchorage, Alaska 99508 Received by: Date: BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/24/93 T# 84687 BPX/PBU ~LOGS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-37)-I~'OT-d PERF 06/11/93 #1 A-37 - SBL 06/11/93 #1 C-22~~ PERF 06/10/93 #1 D-28~-~PRODUCTION LOG 06/06/93 #1 H-15~[-~O[ CCL/PERF 06/08/93 #1 H-21~-7~ PRODUCTION LOG 06/09/93 #1 H-28~-~ PERF 06/10/93 #1 J-01~~ PRODUCTION LOG 06/10/93 #1 J-14 ~75 PRODUCTION LOG 06/10/93 #1 J-23~7-~ PRODUCTION LOG 06/11/93 #1 x-19A _l 06/09/93 #1 10500.00-10725.00 ATLAS 5 " 10150.00-10744.00 ATLAS 5 " 98'50.00-10056.00 ATLAS 5 " 10650.00-11030.00 ATLAS 5 " 11200.00-11380.00 ATLAS 5 " 9300.00- 9840.00 ATLAS 5 " 11700.00-12137.00 ATLAS 5 " 8750.00- 9090.00 ATLAS 5 " 10250.00-10517.00 ATLAS 5 " 9500.00- 9685.00 ATLAS 5 " 8340.00-10124.00 ATLAS 5 " Information Control Well Records ~,L,[ ,A OIL AND GAS CONSERVATION COMMIS, ,..;-- STATE OF ALASKA REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~. Stimulate Plugging~ .. Pull tubing . AItercasing Repair well . . , -2. Name of oPerator ._. Bp..Explora!!ion (Alaska)/nc. . ., 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 TYpe of Well: Development Exploratory Stratigraphic Service RECEIVED OCT - B Alaska 0il & Bas Cons. 'Anchorage measured true vertical 9961feet Plugs (measured) 9179feet 4. Location of well at surface 534' SNL, 1266' WEL, SEC. 21, T11N, R13E, UPM At top of productive interval 2362' SNL, 928' WEL, SEC. 22, T11N, R13E, UPM At effective depth 2666' SNL, 164' WEL, SEC. 22, T11N, R13E, UMI At total depth 2704' SNL, 189' WEL, SEC. 22, T11N, R13E, UPM 2, present WelI Condition' summary" Total depth: Perforate_ × Other 6. Datum elevation (DF or KB) KBE = 76.51 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-21 (13-22-11-13) PBU 9. Permit number/approval nu~ber ' 86- 71 / 10. APl number .50- 029-21575 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9893feet Junk (measured) 9049feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size Cemented Measured depth True vertical depth .. BKB 62 20X30 8 cu yds 110 110 2644 13-3/8 3723 cf 2692 2692 9100 9-5/8 575 cf 9148 8521 .. 1057 7 419 cf 8904-9961 9490-9506', 9516-9534', 9540-9550', 9565-9575', 9585-9605' 8317-9179 true vertical subsea 8880-8914' Tubing (size, grade, and measured depth) 5-1/2" L-BO to 8838' with 4-1/2" tailpipe to 8946' Packers and SSSV (type and measured depth) 9-5/8" TIWpacker at 8838'; 5-1/2" ball valve nipple at 2044' 13. Stimulation or cement squeeze summary Intervals treated (measured) 9476-9481 8/18/91 The additional intervals was perforated using 3 3/8 gun diameter, 6 SPF, 30' orientation and 60° phasing. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation , Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1630 ~./'"~'1'165 4700 0 5000 J .... 16000~-~' 7800 0 15, Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations ..... Oil X Gas Suspended. Li7. I hereby~ c§rtify ihat th-e f~omOo[F~-i~ true_and, COrrect t° the best of my kr;OwJ~dge. Signed~fl(~L/J ~1 ~ ~~ - Title SeniorTochnicalAssistant, ~Form -10~404 ~ev 06/i5/8-'8 / ....... Tubing Pressure 730 38O Service Date/~/~~, SUBMIT IN DOPLIOATE BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519.6612 (907) 561.5111 DATE: 11/26/91 T# 83043 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. U-13 PERF 11/18/91 #1 H-21 PRODUCTION LOG 11/16/91 #1 10250.00-11472.00 SCH 9350.00- 9885.00 SCH Information Control Well Records Adrian J. Martin BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevarcl P.O. Box 196612 Anchorage, Alaska 99519.6612 (907) 561-5111 TO: DISTRIBUTION Date :09/16/91 T~'0 FROM: Information Control Well Records LR2-1 SUBJECT: BP CASED HOLE FINALS Enclosed is your copy of the material listed below. Well Records at (907) 564-,H45. If you have any questions, please contact BP A-26- C-35- W-10' H-21 - W-11 -' S-07- h-24- A-31 ' J-09 ~ W-20" B-23-' X-18" F-30- CHEM CUT HP/TEMP CCL PERF PERF PERF PERF HPfTEMP CL CL/CHEM CUT HP/TEMP CL PERF PERF PERF PERF 08/30/91 #1 08/04/91 #1 07/16/91 #1 08/18/91 #1 07/20/91 #1 07/10/91 #1 07/31/91 #1 08/21/91 #1 07/31/91 #1 07/19/91 #1 08/25/91 #1 07/24/91 #1 08/13/91 #1 N/A-10019 HLS N/A 9122-9629 HLS 5" 13817-14400 HLS 5" 9150-9670 HLS 5" 13070-13468 HLS 5" 10400-11230 HLS 5" 9551-9880 HLS 5" 8900-9265 HLS 5" 9551-9870 HLS 5" 9300-9800 HLS 5" 9682-9942 HLS 5" 10700-11025 HLS 5" 11830-12450 HLS 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA STATE OF ALASKA AL~..,KA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL OPERATIONS 1. Operation's performed: Operation shutdown __. Stimulate_._. Plugging. Pull tubing .... Alter casing .._. Repair well Type of Well: ECEIVED 2. Name of operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface E34' SNL, 1266' WEL, SEO. 21, T11N, R13E, UPM At top of productive Interval 2362' SNL, 928' WEL, SEC. 22, T11N, R13E, UPM NOV - 6 1990 At effective depth 2666' SNL, 164' WEL, SEC. 22, TI IN, R13E, UMI ~ j~j ~t ~ COltS..Co._r~~t At total depth ~-'"'~" ~ ' 9961 feet Plugs (measured) 9179feet 9893feet Junk (measured') 9049feet 2704' SNL, 189' WEI., SEC. 22, TI IN, R13E, UPM i i i 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Perforate. x,_ Other __ 6. Datum elevation (DF or KB) KBE, 76.51 AMSL fe~ .... 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-21 (13.22-11-13) PBU .. 9. Permit number/approval number 86-71 / 9O-488 10. APl number 50- 029-21575 11. Field/Pool Prudhoe 011 Pool Casing Structural Conductor Surface Intermediate Production Uner Perforation depth: Length 62 2644 9100 1057 measured Size Cemented Measured depth True vertical depth BKB 20X30 8 cu yds 110 110 13-3/8 3723 d 2692 2692 9-5/8 575 cf 9148 8521 7 419 cf 8904-9961 8317-9179 9490-9506', 9516-9534; 9540-9550', 9565-9575; 9585-9605' true vertical subsea 8880-8914' Tubing (size, grade, and measured depth) 5-1/2" L-80 to 8838' with 4-1/2" tailpipe to 8946' Packers and SSSV (type and measured depth) 9-5/8' T/Wpacker at 8838;' 5-1~2'ball valve nipple at 2044' 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment Treatment description including volumes used and final pressure 14. Representative Daily Averane Production c~r Iniection Data 'OiI-Bbl Gas-Mcf - Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1630 1165 4700 0 730 Subsequent to operation 5000 16000 7800 0 15. Affachments 16. Status of well classification as: Copies of Logs and Surveys run Daffy Report/gf Well Operations X Oil X Gas .. Suspended 17. l hereby cg~t~ that the fo~oi~ is true and correct ,o the best of my knowledge. 380 Service SUBMIT IN DUPLICATE WELL H-2! (13-22-11-13~ PBU __ ~DDITIONAL PERFORATION OPERATION Wc perforated thc following additional intervals on June 25, 1990: 9490'-9506' MD BKB 9516'-9534' MI) BKB 9540'-9550' MD BKB 9565'-9575' MD BKB 9585'-9605' MD BKB The above intervals were shot with 3-3/8" HSD guns, 6 spf, 4lB Hyperjet II charges, 60° phasing and random orient. Well was tested and put on production. mr/! 0/27/90 BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson 8oulevarcl I~:). Box 196612 Ancl~orage, Alaska 99519-6612 (907) 561-511i TO: DISTRIBUTION Date :08/27/90 T#:81520 FROM: SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed beloW. If you have ariy questions, please contact BP Well Records at (907) 564-~.~.45. ' V/B-13 TDT-P Borax 08/22/90 #1 9400-10832 Sch 5" ~'I-I-21 Prod-F 08/21/90 #1 9300-9887 $ch 5" v~Z-13 Packer/Gun Pos. 08/21/90 #1 12400-12635 Sch 5" V'Z-13 CBT 08/21/90 #1 12058-12989 Sch 5" vZ-13 CET 08/21/90 #1 12058-13008 Sch 5" DiStribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL · PHILLIPS RESERVOIR RECEIVED AUG ,.,z 0 1990 Alaska Oil & Gas Cons. uommission Anchorage -~':-~.: -, ~ .,:-~ ? . .,.~..:~ · ... ~- , .. . . ,_~.___ ....... . BP EXPLORATION BP Exl31oration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (g07) 561-5111 TO: DISTRIBUTION Date: 06/29/90 T#:81321 FROM' SUBJECT: Information Control Well Records LR2-1 BP CASED HOLE FINALS Enclosed is your copy of the material listed below. If you have any questions, pi'ease contact BP Well Records at (907) 564-~,!?.5. A-10 CCL 06/23/90#1 8900-10384 SCH A-10 PERF 06/23/90 #1 9050-10100 SCH A-31 P~E~J= 06/21/90 #1 9450-9723 SCH F-26 PREF 06/21/90 #1 10250-10525 SCH H-21 -~PERF --- 06/25/90 #~ 9200-9750 SCH W-17 TEMP 06/23/90 #1 11338-11806 SCH W-21 PROD LOG 06/22/90 #1 10600-11230 $CH W-21 TDT-P BORAX 06/24/90 #1 10580-10250 $CH -W-27 CNL 06/24/90 #1 10760-11640 .- SCH Z-01 PERF 06/22/90 #1 10410-10756 SCH # 5" 5" 5" 5" -- 5" 5" 5" 5" Distribution: ARCO CHEVRON EXXON GEOSCIENCES MOBIL PHILLIPS RESERVOIR STATE OF ALASKA ARCHIVES £ .V Alaska Oil & Gas Cons. ~omm~SSiOn Anchorage ~ STATE OF ALASKA ,~"~ _~ ._ASKA OIL AND GAS CONSERVATION COM! ION APPLICATION FOR SUNDRY AppR '{I [LG=J N A L 1. Type of Request: Abandon Suspend Operation Shutdown , Re-enter suspended well Alter casing Repair well __ Plugging .... Time extension Stimulate Change approved program .. Pull tubing Variance Perforate X Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Locatior~ of well at surface 534' SNL, 1266' WEL, Sec. 21, T11N, R13E, UPM At top of productive interval 2362' SNL, 928°WEL, Sec. 22, T11N, R13E, UPM At effective depth 2666' SNL, 164 WEL, Sec. 22, T11N, R13E, uMI At total depth 2704' SNL, 189' WEL, Sec. 22, T11N, R13E, UPM 12. Present well condition summary Total depth: measured true vertical BKB 5. Type of Well: Development X . Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 9961 feet Plugs (measured) 9179 feet KBE, 76.51 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number H-21 (13-22-11-13) PBU 9. Permit number 86-71 10. APl number 50- 029-21575 '11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 9893 feet Junk (measured) BKB 9049 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 62 20x30 8 cu yds 110 110 2644 13 3/8 3723 cf 2692 2692 9100 9 5/8 575 cf 9148 8521 1057 7 419 cf measured 9680'-9722' 8904-9961 8317.9179 true vertical (Subsea) 8880'-8914' Tubing (size, grade, and measured depth) 5 1/2" L-80 to 8838' with 4 1/2" tailpipe to 8946' Gas Cons. Comt,';is$io~,~ Anchoraffa Packers and SSSV (type and measured depth) 9 5/8" TIW packer at 8838'; 5 1/2" ball valve nipple at 2044' 13. Attachments Description summary of proposal 3( Detailed operations program ' _ BOP sketch 14. Estimated date for commencing operation June 1990 16. If proposal was verbally approved Oil X Gas Name of at, rover Date approved Service 17., herabY.~/ify_that,the, f~go~,ji~)is..J~. ~/ /J/',.._z. true a.nd correct ,o the best of my knowledge. Signed ~ ~ ~/"~ T[tleSupervisorGrav~yDralna~te i/ ' /2 " FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity. BOP Test.. Location clearance Mechanical Integrity Test Subsequent form required 10- ORIGINAL SIGNED BY Approved by order of the Commission I nNNIF (~, ~M!TH Form 10-403 Rev 06/15/88 15. Status of well classification as: Suspended Date JApproval No. C~ ~_~; Commissioner Approvea Copy J~turr~ed o _ SUBMIT IN TRIPLICATE WELL H-21 (13-22-11-13)) PBI, I ADD'L. PERFORATION We propose to perforate the following additional intervals dudng June 1990: 9490'-9506'MD BKB 9516'-9534'MD BKB 9540'-9550'MD BKB 9565'-9575'MD BKB 9585'-9605'MD BKB A lUbricator will be installed and tested to 3500 psi for all well work. The well will be placed on production immediately following perforating operations, then tested. Ik1:6/8/90 BOWEN P~,...;KO FF FLOW TUBES & PACKOFF HAND GREASE SEAL FLOWTUBE PUMP FL GREASE LINE FLOWLINE VALVE RISER GREASE MANIFOLD GREASE PUMP , ~GREASE RESERVOIR BOP BP EXPLORATION BP Exoloration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anct~orage, Alaska 99519-6612 (907) 561-5111 To: Distribution Date: 03/15/90 Transmittal: 80970 From: Information Control Well Records LR2-1 Subject: DP CASED HOLE FINAL LOGS Enclosed is your copy of the material listed below. If you have any questions, please contact BP Well Records at (907) 564-4445. C-14 Tubing Puncher 03/10/90 #1 9945-10270 Sch H-21 TDT-P Borax 03/09/90 #1 9130-9886 Sch 5" J-08 Collar 03/09/90 #1 12040-12284 Atlas 5" M-12i Perf 03/07/90 #1 9960-10313 Sdh 5" W-40 TDT-P 03/08/90 #1 9917-10531 Sch 5" Z-30 CET 03/08/90 #1 13990-14902 Sch 5" Z-30 CBT 03/08/90. #1 14402-14884 Sch 5" Z-30 TCP Gun Positioning 03/08/90 #1 14287-14560 Sch 5" Distribution: ARCO CHEVRON GEOSCIE~CES MOBIL PHILLIPS RESERVOIR ARCHIVES RE MAR 2 2 1990 A!~ska 0il & t~as Cons. Com~'~ssto.t~--'" Anchorage BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 To: From: Subject: Distribution Information Control Well Records LR2-1 ~P CASED HOLE FINAL LOGS Date: 05-AUG-89 Transmittal: 80232 Enclosed is your copy of the material listed below. If questions, please contact BP Well Records at (907)564-4445. you have C-10 E-07 E-28 H-05 H-21 H-29 J-05 N-03 M-15 R-08 R-20 Temp 07/22/89 91 11500-11800 PITS 07/22/89 ~1 9100-9438 GR 07/21/89 91 8800-10613 Prod-F 07/19/89 ~1 11200-11558 GR/Caliper 07/21/89 #1 8700-9897 Prod-F 07/14/89 91 9100-9639 Prod-F 07/12/89 91 9850-10338 Prod-F 07/15/89 ~1 2900-11620 Temp 07/16/89 91 Surf-9560 Prod-F 07/18/89 91 10800-11180 Inj 07/20/89 #1 10850-12024 Camco 5" Camco Camco 5" Camco Camco 5" Camco 5" Camco Camco Camco 1"/5" Camco Camco 5" any Distribution: ARCO CHEVRON EXXON GEOSCIENCES HOUSTON MOBIL PHILLIPS ~,tanda~d Product;an Camp 900 Ea~,~ PO. Bo,, 196~i2' Ancho,r age. (907) 564-51 I I DALLAS ARCO CHEVRON E,~CXON TEXACO TO: - MO B IL PHILLIPS STATE OF ALASKA GEOSC IENCES RESERVOIR REFERENCE: ARCHIVES SAPC CASED HOLE FINAL LOGS INOEXED STANDARD ALASKA, PRODUCTION 07/07/88 Da te: 79062 TI: The following material ls belng submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this offlce: · A -02 ~ B-09 E-18 ~"'~H-21 R-06 U-13 Spinner 06/25/88 #1 11150-11490 Sch 5" CET 06/23/88 #1 8700-10086 Sch 5" Completion Record 06/21/88 #2 9710-11160 Sch 5" CNL 06/26/88 #1 9100-9898 Sch 5" Leak Det/Temp 06/29/88 #1 8600-9370 Sch 5" Production Log 06/28/88 #1 11050-11458 Sch 5" Rece I ved (~1 Company 18.70. Jennifer Dietz ~ NFO~T I ON CONTROC We I ~ ~ecord$ t~2- I Standa,d Alaska I~ocluction Company 90'0 ~OSt ~.en%on 8oulevo,d P.O. ~a 196612 Ancho~oge, A~s~o ~519-66 ~7~ 564-51 I I ARCO EXXON PHILLIPS STATE OF AK STANDARD ALASKA PRODUCTION Date: 07/05/88 79041 SYSTE~ (Transmittal & Tape) ARmieS SAPC MAGNETIC LIS TAPES & LISTINGS ..'Ihe following material is being sutm~itted herewith. Please acknowledge receip~ bi signing a copy of this letter and returning it to this office: .... H-21 CH/CNL 06/28/88 #1 9093.0-9918.5 · Sch #72832 1600bpi API#50-029-21575 Tape Pos. #05888 ARCHIVES ONLY: H-21 CH/CNL Field tape 06/26/88 Sch#72832 #1 800bpi Tape Pos. #0! * EXXON: An Asterisk (*) next to a lis' have received the Tape(s) and Listing(s) service company. Please confirm this. ~ove means you should ~rectly from the respective Received Date A un;t o! Ihe o~';g;nol Stondo,d C~I Co"~pony founded *n Cle-elnnd. C~,o. ,n 1870 Jennifer Dietz ~TION C~L Well Records iR2-1 Standawd Alaska Pwoduction Compan~/''~ 900 Eos! Benson Boul~ d PO Box 196612 Anchofoge, AIosho 99519-6612 !907) 564.5 11 I INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA STANDARD ALASKA PRODUCTION Date: 08/05/87 78106 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following ma?erlal Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and re?urnlng i? to this office: A-1 A-22 A-26 A-29 A-32 A-35 D-9 D-25 D-26 D-27 D-28 D-29 G-19 G-25 G-31 H-21 H-22 H-24 H-26 J-22 U-2 07/09/87 Camco Static Gradient 07/12/87 " " " 07/09/87 " " " 07/11/87 " " " 07/13/87 " " " 07/13/87 " " " 07/21;87 " " " 07/10/87 " " " 07/10/87 " " " 07/07/87 " ". " 07/22/87 " " 07/22/87 " " " 07/08/87 " " " 07/08/87 " " " 07/07/87 " " " 07/25/87 " " " 07/25/87 " " " 07/25/87 " " " 07/25/87 " " " ~07/27/87 " " " 07/17/87 " " " U-6 07/17/87 " " " 0-8 " " - i', -- '"'-') u-12 07115187' " "/~ 7 II I X-2 07/27/8 ,, , Date / ~ . [./ .--,.m,~e,[O~ Wel I Records LR2-1 · " / / ' _.. o_ ¢.as C,o~s. ~,u,, ..... ................. DALLAS INDEXED _ ARCO C~{EVRON EXXON TEXACO TO: HOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUCTION Date: 04/06/87 TI: 77814 REFERENCE: SA.PC CASED HOLE FINAL LOGS The roi lowing material Is being submitted he~ewltho Please acknowledge receipt by signing a copy of this leHer and returning It-to this office; _o ., B-8 B-30 D.-29 G-25 H-21 J-19 JX-2 i~-2 R-26 R-27 8-11 ' Perf. Record 02/24/87 g2 9350-9758 Sch 5" Cont. Flow/Spinner/Temp/Hydro 03/12/87 gl 10700-12287 GO 5" Production Profile 03/29/87 gl 9700-9990 Camco 5" Perf. Record 03/26/87 gl 9195-10506 Sch ~" ProduCtion Log 03/27/87 gl 9290-9900 Sch 5" CH/CNL: 03/22/87 gl 9550-10245 GO 5" Cont. Flow/Spinner/Temp/Fluid DensitY 03/08/87 gl 9900-11660 GO Perf. Record , :, 03/02/87 #1 8520-9430 Sch 5" Temp/Leak Detection 03/26/87 #1 2630-7840 Camco 5" Production'Profile 03/16/87 #1 9300-9670 Camco 5" Collar 11/08/86 #1 8410-9780 Dres 5" ,~ecb I ved Date · A un,f of the o,,gmol 5tondo,d 0,1 Co,,'.pony Founded in ,:le-elond. 0~,o. ,n 1870 Victoria Aldridge INFORHAT ION CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 Eo$! ~n$On Boulevo* PO. Bo~ )96612 Anchorage. Alaska 99.519-6612 (907! ,564-5 ! I I DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES INDEXED STANDARD ALASKA PRODUCTION Date: 01/07/87 TO: TI: 77646 REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: C-32 Perf. Record 08/14/86 #1 9220-10398 Sch 5" D-1 " " 07/21/86 #1 9010-9778 Sch 5" D-24 Per.f~ Record 07/28/86 #1 9690-11060 Sch 5" D-25 Perf. Record 07/26/86 #1 9990-10876 Sch 5" F-5 Tubing Puncher 08/16/86 #1 Sch 5" F-5 EPL .: 08/17/86 #1 0-9650 Sch 5" F-5 Tubing Puncher 08/21/86 9300-9663 Sch 5" F-9 Collar 07/28/86 #1 8500-8810 Sch 5" F-18 Perf. Record 07/19/86 #1 11210-12220 Sch 5" F-23 CCL-tie-in 12/31/86 #1 9500-10480 camco 5" H-21 Temp. 12/27/86 #1 2858-9827 Camco 5" J-2 GR 12/31/86 #1' 9000-10333 Camco 5" M-4' Production Profile 01/01/87 #1 11150-11630 Camco 5" M-23 'Production Profile 12/30/86 #1 9350-9850 Camco 5" M-28 Injection Profile 01/02/87 #1 8580-9160 Camco 5" S-15 EPL 07/07/86 '#1 11200-11750 Sch 5" S-19 FLowmeter 12/29/86 #2 9500-10050 Camco 5" U-13 Perf. Record 07/25/86 #1 10195-11473 Sch 5" X-14 Perf. Record 08/07/86 #1 10650-11510 Sch 5" ~/~aSk~L 0il & Corm. Commission Date Anchorafle A umt al the orig;nol Stondo,d Oil Co,-pony Victoria Aldridge INFORHAT I ON CONTROL Nel I Records LR2-1 Standard Alaska ~'~ Production Company 900 East Benson Boulevo,d P.O. Boa 196612 Anchorage. AIo.,ko 99.519-661:2 1907) 564-511 I INDEXED DALLAS ARCO CHEVRON EXXON TEXACO Date: 01/06/87, MOBIL TI: 77645 PHILLIPS STATE OF ALASKA GEOSC IENCES STANDARD ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: D-27 Perf. Record 08/13/86 #1 8600-9688 Sch 5" D-28 Perf. Record 07/30/86 #1 9500-11108 Sch 5" E-7 'Perf. Record 07/23/86 #1 8850-9440 Sch 5" E-7 Perf. Record 08/15/86 #1 9330-9438 Sch 5" E-9 Perf. Record 08/22/86 #1 10500-10900 Sch 5" G-I Perf. Record 08/26/86 #1 8700-10051 Sch 5" G-19 Perf. Record 08/29/86 #1 10680-11524 Sch H-21 Perf. Record 08/11/86 #1 9200-9930 Sch H-22 Perf. Record 08/12/86 #1 8690-9940 Sch N-3 Perf. Record 08/10/86 #1 10900-11746 Sch N~3 Perf. Record 08/20/86 #2 10900-11708 Sch 5" Q-5 Perf. Record 07/20/86 #1 9250-10318 Sch 5" Q-3 Perf. Record 07/27/86 #2 8795-9170 Sch Rece l red ic toria .~ Aldridge /z / .% ..... ..., _ ....... ~ ~ -- l'l~'eRIv~T ION CONTROL Date. ~.~/ klas.ka .Oil & Gas Cous. (JOillllll*]L~lm: . Well Records LR2-1 ^ ..,, 0, ,h. 0.,.;~, S,o~o.a o, c~o., "-~*.~i 'Anchorage Founded ,n Cleveland. Oh;o. ,n 1870 DALLAS ARCO CHEVRON TO: EXXON TEXACO MOBIL PHILLIPS STATE'~i;~OF'ALASKA GEOSCIENCES REFERENCE: SAPC CASED HOLE FINAL LOGS INDEXED ., 'FANDARD ALASKA PRODUCTION Date: 11/13/86 Tt: 77515 The following material Is belng submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: A-29 Caliper 10/22/86 #1 2-10310 Camco 5" B-8 Caliper 10/23/86 #1 18-8740 Camco 2" B-24 Temp. 11/02/86' gl 5400-9728 Camco 5" D-10 Caliper 10/24/86 ' gl 38-9789 Camco 2" G-5 CH/CNL (3 3/8") 06/14/86 #1 10300-11160 Sch 5" G-19 CBL 06/23/86 #1 10226-11539 Sch 5" G-19 CBT 06/26/86 gl 10100-11544 Sch 5" H-21 CBT 06/06/86 #I 8750-9916 Sch 5" H-25 Perf. Record 06/22/86 gl 9500-10752 Sch 5" J-1 Flowmeter 11/03/86 gl 8700-9120 Camco 5" M-14 EPL 09/04/86 #3 10250-10750 Sch 5" Q-7 CNL (3 3/8") 06/17/86 #3 10950-12152 Sch 5" R-26A Temp. 10/20/86 gl Surf-2000 Camco 2" S-ii Spinner 10/19/86 #- 9100-9650 Otis 5" X-15 Caliper 10/26/86 #1 29-8855 Camco 2" X-23 Collar 06/12/86 #1 10071-10190 Sch 5" Y-23 CBL 06/22/86 gl 10005-11604 Sch 5" Race i ved O Al~sk~ Oil & G~s Corm. fou,~ded ,n Clevelond. ~,o. ,n 1870 Victoria Aldridge INFC)PJ~ATION CONTROL Well Records LR2-1 Standawd Alaska Production Compan~ 900 Eost Benson Bout. d P.O. Box 19661'2 ~-' An,cho~'oge, AIoska 99~ 19-66 J907) .564-511 I DALLAS ARCO CHEVRON EXXON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA' GEOSCIENCES (Transmittal Only) INDEXED .,. STANDARD ALASKA PRODUCTION Date: 09/11/86 TI: 77323 · REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The follOwing material Is being submitted herewith. Please acknowledge receipt by signing a copy of this leal'er and returning it to this office: Flowing Gradient 08/19/86 Camco " " 08/23/86 " BHPD & PBU 08/10/86 GO Static 09/05/86 Otis Static 08/30/86 Camco Static 09/06/86 Otis Static 08/29/86 Camco Static ' 08/30/86 Camco Static 09/04/86 Otis Static 08/20/86 Camco Static 08/27/86 Camco BHPD & PBU 08/08/86 'GO BHPD & PBU 08/02/86 GO BHPD~& PBU 08/02/86 GO Roco I ved Victoria Aldridge LR2-1 I NFORHAT I ON CONTROL Well Records LR2-1 A u,,'e al the o,,gi~w~l Stoncf(,,d CM Co,-p(,,,y tau-dad ,n Cleveland. 0~,o. ,. 1870 Standard Alaska Production Compa~'x 900 East Benson Boc ~'d P.O. Box 196612 ~ Anchorage, Alaska 99519-6612 (907) 564-5111 August 27, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. chatterton Well H-21 (13-22-11-13).'PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our sub- sequent repOrt of perforating the well. PFB: JAM ~ Enclosures (12) J. L. Haas, MB12-1 Well RecOrds, LR2-1 H-2I Well File Yours very truly, P. F. Barth, Supervisor Reservoir/Production Surveillance Unit I RECEIVED AUG 2 8 1986 Alaska Oil & Gas Cons. Commission Anchorage A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA ALA/"~% OIL AND GAS CONSERVATION COI'/"'~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other [] 2. Name of Operator 5. STANDARD ALASKA PRODUCTION COMPANY 3. Address 6. · P. O. BOX 196612, ANCHORAGE, ALASKA 99519-6612 4. Location of well at surface 7. 534' SNL, 1266' WEL, Sec. 21, TllN, R13E, UPM At top of productive interval 2362' SNL, 28' EWL, Sec. 22, TllN, R13E, UPM At effective depth' 2681' SNL, 177' EWL, Sec. 22, TllN, R13E, UPM At total depth 2704' SNL, 189' EWL, Sec. 22, TllN, R13E, UPM Datum elevation (DF or KB) KBE. = 76.51 Feet Unit or Property name Prudhoe Bay Unit Well number H-21 (13-22-11-13) PBU 8. Approval number 212 9. APl number 50-- 029-21575 10. Pool Prudhoe Oil Pool 11. Present well condition summary Total depth: measured 9961 true vertical 9179 feet Plugs (measured) feet ~BKB Effective depth: measured 9919 feet Junk (measured) true vertical 9146 feet :BKB Casing Length Size Cemented Structural -- Conductor 62' 20"x30" 8 cu.yds. Surface 2644' 13 3/8" 3723 c.f. Intermediate 9100' 9 5/8" 575 c.f. Production __ Liner 1057 ' 7" 419 c.f. Perforation depth: measured 9680' - 9722' true vertical (subsea) 8879' - 8913" Tubing (size, grade and measured depth) 5 1/2" L-80 to 8838' with 4 1/2" tailPipe to 8946' Packers and SSSV'(type and measured depth) 9 5/8" TIW packer at 8838'; 5 1/2" Otis SSSV at 2044' Measured depth 110' 2692' 9148' 8904'-9961' /rue Vertical depth BKB 110' 2692' 8521' 8317'-9179' RECEIVED AUG 2 8 i986 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Alaska 0il & 6as Cons. Commission Anchorage 13. Representative Dai!y Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5200 3250 1144 0 275 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TitleSupvr. Res/Prod. Surveillance I Form 10-404 Rev. 12-1-85 Date (~'./~.,(~, Submit i~'bupl~cate PERFORATING DATA - Well H-21 (13-22-11-13) PBU 8/9/86 'Pressure tested tubing and inner annulus. 8/11/86 . , 8/18/86 Installed and tested lubricator to 3500 psi for all well work. Rigged up Schlumberger and perforated the fOllowing interval for initial production using 2 7/8" Hyperdome guns at 4 spf: 9680' - 9722' MD (8879' - 8913' TVDss) All depths are referenced to BHCS/GR, 5/12/86. Put well on production and tested. Shut well in for static pressure survey. 8/20/86 Ran initial static pressure/temperature survey at 8800'TVDss. 8/22/86 Set and tested SSSV in ball valve nipple at 2044'. Well on production. jR 8/25/86 RECEIVED AUG 2 8 ! 86 Alaska Oil & Gas Cons. Comm,~n Standard Alaska Production Compa 900 Eo$! Benson Bc .~rd P.O. Box 196612 Anchoroge. Alosko 99519-6617 {907) 564-51 I I INDEXED . , DALLAS ARCO STANDARD CHEVRON ALASKA PRODUCTION EXXON Date: 06/10/86 TEXACO TO: T#: 77105 MAP~THON MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: TELECO MAGNETIC DIRECTIONAL SURVEY(S) The followlng material Is being submitted herewith. Please acknowledge recelpt by slgning a copy of thls letter and returning It to this offlce: H-21 H-22 Y-20 ¥-20 Y-20 Teleco Survey Job #496 Teleco Survey Job #500 Teleco Survey Job #495 MWD & Single Shot GCT Job # 71557 05/12/86 To AOGCC 06/13/86 05/28/86 To AOGCC 07/02/86 05/28/86 05/27/86 06/08/86 9 ......... Alaska Oil & Gas Cons. Commission Anchorage Roca 1 red Date ~Ov,'ded ,,, (]l*'~elo,,~l (.)h,o ,,, IH/I) Victoria Aldridge LR2-1 INFORMAT ION CONTROL Well Records LR2-1 Standard Alaska Production Compa~ 900 Eost Benson Bo~. ,rd P,O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 June 24, 1986 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Well H-21 (13-22-11-13) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. PFB:JAM~~j Enclosures (9) cc: J. L. Haas (MB12-1) H-21 Well File Yours very truly, P~. Fo Barth, Supervisor Reservoir/Production Surveillance Unit I RECE[VED J U N 2 6 ..... .',~ ,~', Oas Cons. Commission A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE Of ALASKA ALAS?'--~.OIL AND GAS CONSERVATION COMF"'&SION APPLICA, iON FOR SUNDRY APr'ROVALS 1. Type of Request: AbandOn [] Suspend ~ Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing .~ Amend order F. Perforate Z2 Other 2. Name of Operator 5. STANDARD ALASKA PRODUCTI°N COF~'ARY 3. Address 6. P. O. BOX 196612, ANCHO~, ALASKA 99519-6612 4. Location of 'well at surface 7. 534' SNL, 1266' WEL, Sec. 21, TllN, R13E, UPM At top of productive interval 2362' SNL, 28' EWL, Sec, 22, .TllN, R13E, UPM At effective depth 2681.' SNL, 177' EWL, Sec. 22, TllN, R13E, UPM At total depth 2704' SNL, 189' EWL, SeC. 22:, TllN, R13E, UPM Datum elevation (DF or KB) KBE = 76.51 feet Unit or Property name Prudhoe Bay Unit Well number H-21 (13-22-11-13) PBU 8. Permit number 86-71 9. APl number 50-- 029-21575 10. Pool ~Nudhoe Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Cas i ng Length Structural . -.- Conductor. 62 ' Surface 2644' Intermediate 9100 ' Production -- Liner 1057' Perforation depth: measured 9961 feet Plugs (measured) 9179 feet BKB 9919 feet Junk (measured) 9146 feet BKB Size Cemented Measured depth 20"x30"' 8 cu.yds. 110' 13 3/8" 3723 c.f. 2692' 9 5/8" 575 c.f. 9148' True Vertical depth BY,.B 110' 2692' 8521' 7" 419 c.f. 8904'-9961' 8317'-9179' true vertical Tubing (size, grade and measured depth) 5 1/2" L-80 to 8838" with 4' 1/2" tailpipe to 8946' Packers and SSSV(type and measured depth) 9 5/8" TIW packer at 8858'; 5 1/2''' ball valve nipple at 2044' 12.Attachments Description summary ofproposal [] Detailed operations program BOP sketch 13. Estimated date for commencing operation June/July 1986 14. If proposal was verbally approved Name of approver Date approved 15, I hereby certify that thews true and correct to the best of my knowledge ~//~ ~,//~ S~d /,~- Titlesupvr. Res./Prod. Surveillance IDate P. F. Barth Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. ,~'/ [] Plug integrity [] BOP Test [] Location clearanceI c:,~/ ~ Approved by Form 10-403 Approved Copy Returned _-- Commissioner by order of the commission Date & -"~ Submit in triplicate Well H-21 (13-22-11-13) PBU INITIAL PERFORATING PROPOSAL We propose to perforate the following interval for initial production during June/July 1986 at 4 spf: 9680' - 9722' MD (8879' - 8913' TVDss) Ref. BHCS/GR, 5/12/86 A lubricator will be installed and tested to 3500 psi for all well work. A SSSV will be set and tested in the ball valve nipple at 2044' at the completion of operations. jm 6/16/86 BASIC SYSTEM MAKEUP BOWEN PACKOFF' HAND PUMP GREASE SEAL ' FLOWTUBE FLOWLINE GREASE LINE FLOWLINE VALVE RISER GREASE , )t/~ ~ MANIFOLD LGREASE i RESERVO{R BOP " ARCO EXXON STANDARD ?\i .&,",t'~ ~RC')DU('I lt.;IN Da:e: 06/06/86 PHILLIPS TO: ~: 77101 STATE OF AK PDBY Systems ~Transmittal Only) SAPC MAGNETIC LIS TAPES & LISTINGS The following material is beirg sutmitted herewith. Please acknowledge receipt by signing a copy of this letter and retumin9 it to this office: R-27 OH LIS 03/29/86 #1 H-21 OH 05/12/86 Sch #71382 Tape Pos. #77101 GO #347235 Tape Pos. #04072 - * E)LXON: An Asterisk (*) next to a listing above means you should have received the Tape(s) and _ Listing(s_) direct]~ from the respective service c°mpany' /?lea~ c°~rm7 t~~ ~ Victoria Aldridge LR2-1 Date - =- Well RecoraS LR2-1 ~,.,,, ,.~ .e,e ~,,.!,.w,i %t,,,.,t,,,,! ( ~.t ~. ,,...&~,.., INDEXED TO: DALLAS ARCO CHEVRON EXXON TEXACO MARATHON STANDARD AL. ASKA PRODUC TI( )N Date: 06/04/86 T#: 77 084 MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES REFERENCE: SAPC OPEN HOLE FINAL LOGS The following materlal is being submltted herewith. Please acknowledge recelpt by slgnlng a copy of this letter and returning It to thls offlce: DAL/UNIT/STATE: H-2i DIL 05/12/86 #i 8900-9964 GO 5" & 2': H-21 BHCS 05/12/86 #1 8900-9936 GO 5" & 2" H-21 CDL/CNLog-Poro 05/13/86 #1 9122-9966 GO 5" & 2" H-21 CDL/CNLog-Raw 05/13/86 #1 9122-9966 GO 5" & 2" STATE ONLY: DIRECTIONAL SURVEYS Magnetic Single Shot Directional Survey Date: 5,-10~-86 JobJ/: 0586-001 Gyroscopic Directional Survey~ _--~Date: =--~.86 JobJJ: ~-BO-60033 Teleco Survey ~D Recel v~d Date ' [ / . . ~ .~ k,~.:.~,s. ~ ..... ' ........ ,,, .... ,, ..... ,, ...... ,,,,,, ~ .... ~l~sXa u~, ~ ~,' 7, ....... .,~ ~ :"'"" STATE OF ALASKA "~ ~ ALASK-A~,~L AND GAS CONSERVATION C~,vIMISSlON WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well /~ OIL ~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Standard Alaska Production Company 86-71 3. Address 8. APl Number P.. O. Box 196612 Anchorage, Alaska 99519-6612 50-029-21575 4. Location of well at surface 9. Unit or Lease Name 'I'~A:r'ION$~- Prudhoe Bay Unit 534' SNL, i266' WEL, Sec. 21, TilN, R13E, UM VERIFIED i 10. Well Number At Top Producing Interval Surf. ~ H-2 1 (13-22-11-13) 2362'SNL, 28' EWL, 'Sec. 22, TllN, R13E, UM At Total Depth B.H. '~,,, . ~ 11. Field and Pool 2704' SNL, 189' EWL, Sec. 22, Ti!N, R13E, gM ..... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool KBE = 76.51 ft. ]ADT, 28284 12. Date spudded 13. Date I.D. Reached 14. Date Comps, Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 4-30--86 5-13-86 5-16-86I N/A feet MSL one 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 9961'MD 9179'TVD 9919'MD 9146'TVD YES~ NO[] 2044' feetMD 2020 Ft. 22. Type Electric or Other Logs Run DIL..BHCS, CDL/CNLog-Poro, CDL/CNLog-raw 23. CASING, LINER AND CEMENTING RECORD ..... SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" Conductor Surface 110' 8 cu. yds. concrete · 13~3/8" 72~. L-80 Surface 2692 17%" 3258 cu. ft. Parma. E 465 cu.ft. Per~ 9~5/8". 47~, L-8O-NSC£:Surface 4574' 12¼" 574 cu. ft. Class G 1% CFR-2+.8% HR-7 9-5/8" 47# L-80 -BUtt ~:~,~" 9148' 12¼" 7" 29~ L-80 8904' 9961' 8%" 419 cu.ft. Class G+].%CFR 2+5% KC1 ,, 24. Perforations open to Production (MD+TvD of Top and Bottom and 25. TUBING RECORD , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5%" L-80 17~: 8946' 8838' MD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9-5/8" x 13-3/8" Annulus 300 ex. Permafrost · type C cement followed by 125 bbls Arctic Pack , 27. pRODucTION TEsT Date First Production I Method of operation (Flowing, gas lift, etc.) ! 'Date of Test Hours Tested PRODUCTION ~FoR OI L-BBL GAS-MCF 'WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ ' I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28.m CORE DATA____~__--.%., ¢ I'% Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Subr~c~ c~(%~h~s{ V JUN Alaska 0ii & Gas Cons. (;0mm%ss~0~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE '~, 30. GEOLOGIC MARKrCRS .... FORMATION TESTS NAM E I nclu de interval tested, pressure data, all fluids recovered and gray ity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sag 9185' 8552 ' Shublik A 9221' 8581' Zone 4 9324' 8667' (Top Ivishak/Sa: derochit) 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Division ~ Signed (~ ~_~ ~_~O,,~ Drilling /3/ ' ' Title Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jec[ion, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Sohio Daily Drilling Report -- PBU April 29, 1986 at 0600 hours Rig' Nabors 18-E Well' H-..°_~l (42-21-11-13) AFE # 120355 0600 Depth' O' Day' -1 24-Hour Ftg' O' Water Used' ,.00 Current Operation' R/U Subbase off hole. Rigging up on H-21. MUD TYPE- WT' VIS' PV' YP' FL' SOLIDS: TEMP'°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0576H' J U N 1 ~ A~aska Oil & Gas Cons. Sohio Daily Drilling Report -- PBU April 30, 1986 at 0600 hours Rig' Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 0600 Depth: O' Day: -2 24-Hour Ftg: O' Water Used' 1800 Current Operation: Rig move and rig up. Set substructure and complexes. Mix spud mud. MUD TYPE- WT' VIS: PV: YP' FL' SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION i i COORDINATES DLS 0576H: Sohio Daily Drilling Report -- PBU May l, 1986 at 0600 hours Rig' Nabors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth' 2700' Day' 1 24-Hour Ftg' 2700' Water Used' 2675 Current Operation' Short trip1 Drill to 629', POH change bit. RIH. Drill to 1770'. POH change bit~ RIH. Drill to 2700'. Short trip. MUD TYPE-Gel/Water WT:91I VIS:200 PV-18 YP-48 FL-14 SOLIDS'5.5 TEMP:48°F SURVEY M~D A, NGL~, DIRECTION .. TVD SECTION COORDINATES DL__~S 0576H. Sohio Daily Drilling Report -- PBU ~lay 2, 1986 at 0600 hours Rig' ~abors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth' 2700' Day: - ~ 24-Hour Ftg: O' Water Used: 0 Current Operation: N/U Flowline. POH. Rig up and run 13-3/8" casing. Cement casing with 1652 sx Permafrost E followed by 500 sx Permafrost cement. Land casing. N/U BOPE. MUD TYPE-Gel/Water WT:9.0 VIS'34 PV'5 YP:9 FL:21 SOLIDS'5 TEMP:N/A°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS , _ 0576H' Sohio Daily Dril!ing Report -- PBU May 3, 1986 at 0600 hours Rig: Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 0600 Depth: 4444' Day' 3 24-Hour Ftg' 1744' Water Used: 1500 Current Operation: Drilling. Test BOPE RIH and drill cement from 2528' to 2650'. Test casing to 3000 psi. Drill to 2750'. Ran FIT to .67 psi/ft. Drilling at 4444'. MUD TYPE-Gel/Water WT:9.1 VIS:34 PV:5 YP:ll FL:23 SOLIDS:S.5 TEMP:68°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0576H- Sohio Daily Drilling Report -- PBU ~.:ay 4, 1986 at 0600 hours Rig- Nabors 18-E Well- H-21 (42-21-11-13) , , AFE # 120355 Current Operation: RIH. 0600 Depth: 5228' Day- 4 24-Hour Ftg' 784' Water Used' 1575 Drill to 4894'. Trip for bit and BHA. Dynadrill' to 5228'. Trip for BHA. MUD TYPE-Gel/Water WT:9.2 VIS:35 PV'4 YP:9 FL:19 SOLIDS-7 TEMP:71 °F SURVEY , ,,MD .A,,NGLE DIRECTION TVD SECTION COORDINATES DLS 1 4851 1.1 S10E 4851 O. O0 SO. O0 'EO. O0 2 4944 3.9 S30.7E 4944 3.94 S3.80 El. 41 3 5037 8.5 S35, 6E 5036 13.98 S12.21 E6.90 4 5130 13.8 S41 ~ 3E 5128 31.92 S26.30 E18.09 O. O0 3.12 4.97 5.81 0576H: Sohio Daily Drilling Report -- PBU May 5, 1986 at 0600 hours Rig: Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 Current Operation: Ori 11 i ng. Drill to 5844'. 0600 Depth- 6365' Day: 5 24-Hour Ftg' 1137' Water Used- 1400 -Trip for bit and BNA. Dril li ng at 6365'. MUD TYPE-Gel/Water WT:9.3 VIS-35 PV-4 YP:7 FL:16 SOLIDS:7 TEMP:79°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES 6 5331 21.1 S49E 5319 92.03 S68.57 E62.85 8 5518 25.8 S46.5E 5490 164.52 Sl18.95 El17.72 l0 5736 30.5 S46.5E 5682 265.46 S190.31 E192.33 12 6137 33.2 S47.6E 6021 475.67 S338.67 E342.07 0576H' DLS · , 2.79 2.47 1 .g6 0.47 Sohio Daily Drilling Report -- PBU May 6, 1986 at 0600 hours Rig: Nabors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth' 7374' Day- 6 24-Hour Ftg' 1009' Water Used' 1 Current Operation: Repair rig. Drill to 6669'. Trip for bit and BHA. Drill to 7374'. PON to casing for clutch repair. MUD TYPE-Gel/Resi hex WT:9.5 VIS:35 PV-6 YP-7 FL'6.8 SOLIDS:8.5 TEMP:89°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS _ 13 6448 33.2 S46.9E 6281 642 S454 E473 O. 12 14 6607 33.0 S45E 6414 727 S515 E536 0.66 1'5 6919' 35.1 S43.4E 6673 899 S640 E657 O. 73 16 7137 36.1 S43.7E 6850 1024 S732 E745 0.47 17 7292 37.2 S44.1E 6974 lll5 S799 E809 0.73 0576H' Sohio Daily Dril!ing Report -- PBU May 7, 1986 at 0600 hours Rig' NaborS 18-E AFE # ]20355 Well- H-21 (42-21-11-13) 0600 Depth: 7929' Day: 7 24-Hour Ftg: 555' Water Used: 1050 Current Operation: Dril 1 lng and survey Trip for bit and BHA. Dynadrill from 7374 to 7500'. Trip for bit and BHA, Ream Dynadrill runj Drilling at 7929'. MUD TYPE-Ge]/Resi nex WT:9.7 VIS:37 PV:8 YP:5 FL:6.4 SOLIDS:9.5 TEMP:83°F SURVEY _ MD ANGLE DIRECTION .. 17 7292 37.8 S44E 18 7536 32.7 S30.7E TVD SECTION COORDINATES · ' DLS 6974 1115 S799 E809 J73 7174 1255 S910 E894 3' 64 0576H: Sohio Daily Drilling Report -- PBU May 8, 1986 at 0600 hours Rig' Nabors 18-E AFE # 120355 Well- H-21 (42-21-11-13) 0600 Depth: 8660' Day: 8 24-Hour Ftg' 731' Water Used: 1400 Current Operation: Drilling ahead. Drill to 8046'. Trip for bit. Drilling at 8660'. MUD TYPE-GelResinex WT:9.7 VIS:39 PV-9 YP-7 FL:6.0 SOLIDS:9.5 TEMP:92°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 19 7859 32.3 S30.4E 7447 1428 S1059 E982 20 8473 32.1 S26.2E 7966 1753 S1347 El137 0576H- 0.13 .37 Sohio Daily Drilling Report -- PBU May 9, 1986 at 0600 hours Rig: Nabors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth: 9160' Day: 9 24-Nour Ftg: 500' Water Used: 1575 Current Operation: Circul att ng Drill to 8961' Trip for bit and BHA. Drill 9160'. Short ~rip. CBU. to 12-1/4" TO at MUD TYPE-GEL/RESINEX WT:9.7 VIS:36 PV:7 YP:4 FL:6.8 SOLIDS:9.5 TEMP:94'F SURVEY_ MD ANGLE DIRECTION 'TVD SECTION COORDINATES DLS 21 8861 33.2 S23.3E 8293 1960 S1537 E1225 0.49 22 9030 32'8 S20..5E 8485 2052 S1653 E1271 0.59 0576H:' Sohio Daily Drilling Report -- PBU May 10, 1986 at 0600 hours · Rig' Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 .. 0600 Depth: 9160' Day' 10 24-Hour Ftg: O' Water Used' 1050 Current Operation: RIH with 8 1/2" BHA CBU, POH. Ran 9 5/8" casing to 9147'. Cemented with 500 sks Class G. Installed and tested packoff. Test BOPE. RIH with 8 1/2" bit. MUD TYPE-Gel/Resi hex WT:9.7 VIS:36 PV:7 YP:4 FL:6.4 SOLIDS:9.5 TEMP:90°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0576H: Sohio Daily Drilling Report -- PBU May l l, 1986 at 0600 hours Rig: Nabors 18-E Well' H-21 (42-21-11-13) AFE # 1203~;5 0600 Depth' 91 71' Day: 11 24-Hour Ftg: 11' Water Used: 1400 Current Operation:. RIH. Drilled FC and 50' cement. Test casing to 3000 psi. Drilled FS and ll' new hole. Bit stopped drilling. POH. Ran junk basket. No recovery. RIH wi th new bit. MUD TYPE-GEL WT:9.0 VIS:39 PV:5 YP'5 FL:6.8 SOLIDS:4.5 TEMP: °F SURVEY MD ANGLE DIRECTION TVD SECTION _ COORDINATES DLS 0576H: Sohio Daily Drilling Report -- PBU May 12, 1986 at 0600 hours Rig: Nabors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth- 9725' Day- 12 24-Hour Ftg: 554' Water Used: 1400 Current Operation: Drilling Drilling 8 1/2" hole at 9725'. MUD TYPE-GEL WT'9.0 VIS:35 PV:4 YP:4 FL:8 SOLIDS:4.5 TEMP:gg'F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES iiii n i i · i DLS 0576H: Sohio Daily Drilling Report -- PBU May 13, 1986 at 0600 hours Rig: Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 0600 Depth- 9761' Day' 1 3 24-Hour Ftg- 236' Water Used- 700 Current Operation: RIH. Drilled to 9961'. Short trip. CBU. POH. RIH for wiper trip. Ran open ho l'e logs. MUD TYPE-GEL WT:9.0 VIS:38 PV:7 YP'5 FL'8.2 SOLIDS:5 TEMP:IOS°F _SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES m i ii DLS 0576H: Sohio Daily Drilling Report -- PBU May 14, 1986 at 0600 hours Rig' Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 0600 Depth' 9961' Day- 14 24-Hour Ftg' O' Water Used- 350 Current Operation: Drilling Cement. Made wiper trip. Ran 7" liner from 8904 to 9961'. Cemented with 355 sks Class G with 5% KC1. POH. RIH and tag cement at 8518'. Dril 1 ing cement'. MUD TYPE-GEL/Water WT:9.0 'VIS:37 PV:6 YP:5 FL:8 SOLIDS:5 TEMP:N/A°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES ,1 , , , -. DLS 0576H: .. Sohio Daily Drilling Report -- PBU May 15, 1986 at 0600 hours Rig' Nabors 18-E Well- H-21 (42-21-11-13) AFE # 120355 0600 Depth: 9919' Day: 14 24-Hour Ftg: ' Water Used: 700 Current Operation: Oi spl acing w/ Na C1. Drill cement to 8897'. CBU. POH. RIH with 6" bit and 7" scraper. Test liner lap to 3000 psi. Clean out cement in top of liner. Drill cement from 9677 to FC at 9920'. CBU. Displace hole with 9.6 ppg Na C1 MUD TYPE-Nacl brine WT: VIS- PV: YP: FL: SOLIDS- TEMP:N/A°F SURVEY MD A)~LE DIRECTION TVD SECTION COORD I NATES DLS 0576H: Sohio Daily Drilling Report -- PBU May 16, 1986 at 0600 hours Rig- Nabors 18-E Well' H-21 (42-21-11-13) AFE # 120355 0600 Depth: 9919' Day: 16 24-Hour Ftg: ' Water Used: 525 Current Operation' Rig uP to displace tbg w/DSL. Displaced well wi th 9.6 ppg Na CL. Test liner to 3000 psi. PON. Ran $ 1/2" tubing with tail at 8946', packer at 8838', 5 GLM's and ball valve at 2044'. Installed tree and tested to 5000 psi. Prepare to displace tubing to diesel. MUD TYPE-Na CL. WT:9.6 VIS: PV: YP: FL: SOLIDS: TEMP:°F SURVEY MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0576H: S°hio Daily Drilling Report -- PBU May 17, 1986 at 0600 hours Rig' Nabors 18-E Well' H-21 ~42-21-11-13) AFE # 120355 0600 Depth' 9919' Day- 1 7 24-Hour Ftg' ' Water Used- Current Operation: Rig release. Di spl aced tubing wi th diesel. Set and test packer. Downsqueezed annulus with 300 sks Permafrost C followed by 125 bbls Arctic Pack. Released rig at 1000 hrs 5/16/86. Spud to release 1-6.1 days. MUD TYPE- WT: VIS: PV: YP- FL' SOLIDS: TEMP:°F SURVEy .MD ANGLE DIRECTION TVD SECTION COORDINATES DLS 0576H' · . TE£rl Teleco Oilfield Servic~~ ~Alaska Inc. ~~;e~=~ 61 16 Nielson Way ,, .. ' Anchorage, AK 99502 (907) 562-2646 May 19, 1986 M JOB # 496 TAK STANDARD ALASKA PRODUCTION CO. WELL: H-21 PRUDHOE BAY NABORS 1SE Please find attached a copy of the computer calculated MWD directional surveys for the above mentioned well. We at Teleco appreciate this opportunity to provide service to Standard Alaska ProductiOn COmpany. ~ Teleco is committed to' providing the highest quality of service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Pat Havard Field Service Supervisor PH/el Enclosures A ~Jlll~'l' COMPANY TELECO oILFIELD SERVICS JOB 496 SURVEY CALCULATIONS **************************************** Date 05/12/86 . Page 1 Company: STANDARD ALASKA PROD. Well: H -21 Location: PRUDHOE BAY . Rig. NABORS 1SE TELECO Job # 496 TAK Grid Correction: Magnetic Declination: Total Correction: Proposed Direction: 0.00 degrees 31.50 degrees 31.50 degrees 145.85 degrees RADIUS OF CURVATURE CALCULATION **************************************** MEAS .. DIRECTION TRUE VERTICAL' COORDINATES CLOSURE DOG LEG DEPTH INCL AZIMUTH BEARING VERT DEPTH SECTION N/S E/W DIST ANGLE S~.VERITY feet deg deg deg/min feet feet . feet feet feet deg deg/100 ' **************************************************************************************************** TIE-IN 4851.00 1.1 170.0 S 10 00 E 4851.00 0.00 0.00N 0.00E 0.00 N 90.000E 0.000 TELECO MWD 4944.00 3.9 149.3 S 30 42 E 4943.90 3.91 3.78S 1.40E 4.03 S 20.350E 3.115 5057.00 5130.00 5237.00 5331.00 8.5 .144.4 S 35 36 E 13.8 138.7 S 41 18 E 18.5 132.0 S 48 00 E 21.1 131.0 S 49 00 E 5056.21 16.11 13.99S 8.07E 16.15 S 29.978E 4.094 5127.80 30.17 25.04S 16.84E 5230.55 59.41 46.19S 37.74E 5318.99 90.26 67.29S 61.58E 30.17 S 33.927E 59.65 S 39.248E 91.22 S 42.465E 7.407 4.718 2.789 .TELECO Jub # 496 TAK MEAS DIRECTION DEPTH INCL AZIMUTH BEARING 05/12/86 Page 2 TRUE VERTICAL COORDINATES CLOSURE DOG LEG VERT DEPTH SECTION N/S E/W DIST ANGLE SEVERITY feet deg deg deg/min feet feet feet feet feet deg deg/100 ' ***************************************************************************************************** ~ 5424.00 23.5 132.8 S 47 12 E 5405.03 124.50 90.85S 5518.00 25.8 133.5 S 46 30 E 5490.45 162.74 117.66S 5641.00 28.7 133.5 S 46 30 E 5599.79 217.76 156.45S 5736.00 30.5 134.5 S 45 30 E 5682.39 263.68 189.04S 5798.00 32.1 134.5 S 45 30 E 5735.36 295.26 211.63S 6137.00 33.2 132.4 S 47 36 E 6020.79 473.88 337.40S 6448.00 33.2 133.1 S 46 54 E 6281.03 639.74 453.00S 6607.00 33.0 135.0 S 45 00 E 6414.22 724.73 513.37S 6919.00 35.1 136.6 S 43 24 E 6672.72 896.73 638.60S 7137.00 36.1 136.3 S 43 42 E 6849.97 1021.93 730.57S 7292.00 37.2 135.9 S 44 06 E 6974.32 1113.11 797.23S 7536.00 32.7 149.3 S 30 42 E 7174.27 1252.31 908.00S 7859.00 32.3 149.6 S 30 24 E 7446.68 1425.51 1057.45S 7976.00 32.2 150.3 S 29 42 E 7545.63 1487.79 1111.49S 8473.00 32.1 153.8 S 26 12 E' 7966.42 1750.67 1345.08S 8896.00 33.2 156.7 S 23 18 E 8322.58 1975.79 1552.30S 9090.00 32.8 159.5 S 20 30 E 8485.28 2079.03 1650.33S 87.85E 126.38 S 44.036E 2.683 116.45E 165.54 S 44.702E 2.467 157.27E 221.84 S 45.151E 2.358 191.03E 268.76 S 45.299E 1.965 213.99E 300.96 S 45.318E 2.581 346.76E 483.82 S 45.783E 0.466 471.80E 654.07 S 46.165E 0.123 534.21E 740.90 S 46.140E 0.664 655.99E 915.49 S 45.770E 0.732 743.42E 1042.31 807.58E 1134.80 892.26E 1273.02 980.47E 1442.05 1011.73E 1503.00 1135.67E 1760.39 1231.20E 1981.29 1270.61E 2082.79 S 45.500E 0.466 S 45.369E 0.726 S 44.499E 3.638 S 42.837E 0.134 S 42.310E 0.331 S 40.175E 0.375 S 38.420E 0.452 S 37.593E 0.813 TELECO D i 1 ~ i ~ ld S~rv i PLAN VIEW ' 400 8OO 1200 "' 1600 o m 2000 2400 · 2800 9200 9600 0 400 800 12.00 1600 2000 2400 EAST (?t) TELECO Oi 1 ~ i e 1 d Sarv ices VERTICAL PROJECTION .J LU 0 4500 5000 55OO 6O0O 6500 7000 7500 8000 8500 go00 :. 500 1000 1500 2000 2500 9000 SOHIO ALASKA PETROLEUM CO. PAD. H (42.-21-11.13) H'21 Controll.ed, Dril.ling Consultants, Inc. LES HENDERSON 3334552 %'% CONI,. ILLED DRILLING CONSULTA , INC. 4234. KINGSTON BR. Anchorage, Alaska 99504 (907) 333.1552 May 18, 1986 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch 6-612 .Anchorage, AK 99502 RE: Magnetic Single Shot Survey Job No. 0586-001 Well H-21 (42-21-11-13) Prudhoe Bay Field North Slope, Alaska Date of Survey: 5-01 to 5-10-86 Dear Mr. Rose: Please find enclosed the "Original" and six (6) copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this survey was Radius of Curvature. The depth of the survey was 4851 to 9160. Thank you for giving us this opportunity to be of service. Yours very truly, nts,~Inc. T~rry enderson /'""~') Directional Supervisor SOHIO ALASKA PETROLEUM JOB NO A-0586-00'i MAGNETIC SINGLE SHOT SURVEY WELL ENGINEER TERRY HENDERSON SURVEY DA'TE O1 C_~.M?UT_~_D._F. OR ~.DC BY OCE~NTECH(F~ L~'NDSEY & AS~OC J PROPOS~'r~ DIR ~- . ........ . ~ . ~34-09E ................................. :. _ RECORD OF SURVEY TRUE D M DEG, D M S 4~.,ol O0 47?4,49 SIO.OOE O0 S 4944 3 54 4943 90 4867.39 ~:'::0~._ ?OE ,.:,~, 78 S .5037 .... 8. 30 5036 51,30 i3 48 5i27 52,37 18 30 5230 5.~! 2_!_ ...... 6 53i8 5424 23 30 54 04 5518 25 48 5490 564i 28 42 b.~ 33 55 29 7.7 77 20 53 5736 30 30 5682. 13 5798 32 6 5735.il 6137 33 12 6020.53 6448 33 12 6280,77 66 07 33 0 6413.96 69i9 35 6 66~''~ ,,.- ,46 71,.37 36 6 6849.71 7292 37 12 6974,07 75~6 32 42 7174,0~ 7_~9..S2. I.~ 7446.42 84.7~ .32 6 7965,99 8861 33 12 9292.67 5i53,78 5242,22 S49 OOE 5328,26 S47 20E 54i3,69 S45 50E 5523,02 S46 50E i57,65 S 5605,62 545 5OE 1'B0,25 S 5658,60 S45 5OE 2i2.82 S 5944,02 S4'? 60E 338.59 S 6204,26 S46 90E 454, i8 S 6337,45 S45,OOE 5t4,55 S 6595.95 343 , 4OE 639 . 78 S 6773,20 S4S.TOE 731 .76 S 6897,56 S44. tOE 798.42 S 7097,50 S30,TOE 909,18 S 7369,91 $30,40E !058,64 S 7889.48 S26,2OE 1346,66 $ 8216,i6 S23,~0E 1536.73 S $48 OOE 47.42 S 38 97 E 68.5i S 62 8i E 92,08 S 89 07 E ii8.89 S 117 67 E i58 52 E 192 27 E 215 25 E 348 Ot E 473 06 E 5~5 47 E 657 25 E 744 68 E 808 83 E 893 52 E . 9~1 73 E 1136 81E i224 44 E 61 92 i28. 167 223 270 302 485 655 742, 28 S ,57 S 49 S 70 S 55 S 80 S 62 .S 44 4'2 22 E 2 451 1.37.52 45 is ~4 E ~ 9i-4 ....................... 45 i9 29 E 2 58i 246 45 47 iOE 374 39:~ 46 9 58 E t23 5'29 43 .................................... 46 8 27 E S76~._~9q ~"~ 9i7,22 1044.04 1136,53 1274.75 t443.78 t762,33 1964,89 SOHIO WELL S:[NGLE SHOT SURVEY .) JOB NO A-.0586-001 COMPU TE~;::'-- 09 KB EL. EV 7e,. 5'! FT~ '~i-E-'A'S': ...... ~R-'i F-T VERT Z CAL DEPTH ANGLE DEPTH D H 909'0 :32 48 8484,73 REL:~k:D OF SURVEY SUB DRIFT TOT~'L'"-COOR'D~NAT'~S C L 0 S U R 'E'S ....... SEVERITY SECTION' SEA D I REC O I STRNCE ANGLE: DEG,~ t'0-'0~'~ .................... D-'~T- DEG, D t'i S 9160 ~2 48 BOTTOM HOLE CLOSURE :2120,96 FEET RT S 37' 15 52 E :5~HIO WELL SINGLE SHOT SURVEY ,JOB NO A-0586-00t PIEASURED DEPTH AND OTHER DATA F'::,F: EVERY EVEN t O0 FEET OF SUB SEA DEPTH, ) KB EL, EV 7,::;.5i F"?. TRUE MEASURED VERTICAL ~LB H[>-'TVD VERTICAL ..... DE'PTH DEPTH SEA DIFFERENCE cORRECTiON TOTAL COORDINATES O O. -77 0 0 . O0 S 4877 4877, 4800 0 O ,64 S 4977 4977, 4900 0 0 6, 07 S 5078 5077, 5000 i i I, ,66 $ 518i 5i77. 51OO 4. 3 35,82 S ................................. 5286 5277. 5200 9, 5 ...~=~, 12 S 5393 5377, 5300 ~; 7 83,94 S 55'03 5477, 5408 25 1 0 i 14,38 S 00 Ef 2 .'.3~ E ~ 08 E 26 95 E ~_]~, 5'0 '~6 E 80 iS E ............................... t~2 9i E 561 5 5577, 5500 38 i 2 57~ 0 5677· 56 O O -.~-~° i 4 '5847 5777. 5'700 70 5965 5877 · 58 O.O 89 i 8 6084 5977. 5900 ~- 07' 19 6204 6077. ~OOO is7 2o 6'32 3 6i 77, 6 i O0 '~4~, i 9 .............. 6443 6277. 6200 i 66 20 ..................... 6562 6376 , 6300 i 85 i 9 i49,09 S i49 50 E i87.95 S 1'89 94 E 275.07 S 279'75'E ........................................... Jig.i6 S $26 8'7 E 363.33 S 375,03 E 407.~ ~ 423,i~ E 452,28 S 47i.03 E 497,40 S 518,i6 E 6802 6924 7047 7170 7295 7419 7539 " 765-8 7776 7895 8013 8249 8~67 8485 8604 8722 6477, 6577, 6677, 6777 6877 6977 7076 7i77 7277 7377 7476 7577 7677 7777. 7877, 7977, 8077, 8177. 6400 205 6500 2'25 6600 247 6700 270 6800 293 7000 342 7100 36'2 7280 7300 399 7400 4!~ 7500 436 7608 454 7708 4-72 7800 4'90 7900 508 8000 ~'~ 20 543.65 $ 564 37 E .............................................................. 22 64i,87 S 23 693.42 S 23 745,94 S 25 799,76 S 24 854,93 S 20 9~8,56 S i9 965,64 S 18 1020.46 S 19 ~075.04 S 18 ~29,88 S 18 1185.05 S 18 1240,57 S 18 1296.42 S 18 !352.59 S t9 i409,57 S i8 1467,73 S 659 22 E 708 I2 E , 758 25 E ~ Si 0 i2 E 857.38 E 894 34 E 926 96 E 959 30 E 991 31 E t022 65 E .......................................... i 053 16 E i082,85 E 1111,70 E 1139,72 E tt67,i0 E i193,95 E ) SOHIO i~ELL SHOT SURVEY ) JOB NO ~-0586- .... !_'!_E__,g_...,?_,U.~.E~ DEPTH ¢4f4D OTHER DATA F~;'?R .EVEP..~¢ EVEN !..0o FEET_OF SUB SEC:'., DEPTH, ) COMPI3TER- 0"!? NAY $6 t<B ELEV 76,5'! FT, TRUE . MEA~URE~ ~¢ERTICAL SUB MI> TV[:: VERTICAL ...... "' ~: ........ ? ~.n ..... .................... ~.T.H. DEPTH ~E~ DIFFERENCE ~ORRE~TI~N TOTAL COORDINATES .............. 88.42 9080 9.!. 6 '~:~ 8,2 8377, 8300 584 ' 8544 8467 SOHIO ,,..lOB NO .q-0586-OOl E:. ~,.. E, 7' '.'.S, 5 ! F T TRUE H'EASURED VERTICAL SUB ..... DEPTH DEPTH SEA T JT~4L L:OOR~ ZNATES ................0 O, --.. ,.. ,.'-"~'. ' ......... , O0 '~.:, .......... . O 8 5000 5008, 4923. 8,'f5 $ 4,i5 E 6000 5906. 5829. ~"~. · .......... 7000 6739, 6662, ~7~,75 S 689,43 E 8'000 7566, 7489~ 1~3,90 R I019,28 E ........... 9.i ~ o 8544 ....... 8_.4_~'~:~.., ........ ~.~:_~.7._,_,~..6._.__~ ............... ~..~_~4.23 E HORIZONTAL VIEW STANDARD OIL PRODUCTION WELL H-21 (42.-21-11-1:5) RADIUS OF CURVATURE MAGNETIC SINGLE SHOT SCALE: I"= I000' MAY 12, 1986 ALL DEPTHS SHOWN ARE TVD June 11, 1986 Mr. Michael D. Martin Standard AK Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Our BOSS Gyroscopic Survey Job No. AK-BO-60033 Well: H-21 (Sec.21 TllN R13E) Prudhoe Bay, Alaska Survey Date: June 7, 1986 Operator: T. McGuire .. Mr. Martin: Please find enclosed the "Original'' and sixteen (16) copies of our BOSS Gyroscopic Survey on the aboVe well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 SPERRY-SUN. WELLi SURVEYINO~COMPANY ":~ : PAGE STANDARD AK PROD. CO. H-21 PRUDHOE BAY ALASKA VERTICAL SECTION CALCULATED ALONG CLOSURE ANCHORAGE ALASKA DATE Of SURVEY dLINE 7, COMPUTATION DATE BOSS GYROSCOPIC SURVEY dUNE 9,,~1986 dOB NUMBER AK-BO-60033 · ~.'!'i ~ i.. KELLY, BUSHING ELEV. = '-'~i OPERATOR-T. MCGLIIRE 1986 76.51 FT.. TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 0 O. L~O -76.51 COURSE INCLINATION DEO MIN 0 0 COURSE DOG-LEG TOTAL DIRECTION SEVERITY RECTANGULAR COORDINATES DEGREES DEG/1OO NORTH/SOUTH: EAST/WEST N O. 0 E 0.00 0.00 0.00 VERTICAL SECTIC~ O. O0 1 O0 1 O0. O0 ~,...°':'. 49 200 .--00. O0 123.49 --~0-0 ~-"'"' ...... ~00. O0 .7~-~ ~"'-~c/ 400 400. O0 323.49 500 500. O0 423, 49 60'0 5'~9 ;aG-- ~.~.~. ...... · ~<~ 48 0 16 S 32.19 W 0 16 S 38.19 W 0 11 S 22.89 W 0 22 S 21.50 W 0.27 0.20 S 0.13 W 0.03 0.58 S 0.40 W 0.03 0.94 S 0.68 W 0.09 1.26 S 0.88 W 0,18 1.71 S 1.07 W 0 18 S 18. 0 W 0.08 2.26 S 1.27 W 0.10 O. 26 0.40 O. 55 O. 83 1.17 700 800 900 · ' 1000 1100 1'2-0-0 1300 1400 1500 1600 1700 1-8-Ob 1900 2000 2-I O0 2200 2300 2'400 2500 2600 699.99 623.48 799.99 723.48 8-9~7~9 .... 823'~"48 999.99 923.48 1099.99 1023.48 1299.99 1223.48 1399.99 1323.48 0 20 S 29.39 W 0.08 0 20 S 14.19 W 0.09 '. 1-4~...9~..9-8' I4'23'J-4'7 · .. 15 ~9.98 1523.47 .' :. ::': · 1699.98 1623.47 ...... f7~:0.98 1899.98 1823.47 1999.98 1923.47 209g~-98 ...... 2-023~-4'7 2199.98 2123.47 2299.~8 2223.47 2.77 S 3.32 S 3%-78--S 4.07 S 4.17 'S 'I. 49 W 1.71 W 2.23 W 2.67 W 3.05 W 3.35 W 3.64 W 4.16 S 4.25 S 4.31 S 1.47 1.80 2.14 1.98 1. ?A--- 1.66 1.55 23-9.~.. 98~2323-,'-47' 2499.98 2423.47 2599.98 2523.47 O' 9 ':::s781.80 w. .:'o. o6 · · 4. ol--S o ::'" :.:. :. J i..! s ::.36' 8o.. w : 'i'- o.:28::::" ::4.58' -'' O: 16:: 62' 50 W . :. ::":0.42 ' '4.73 S '27C30 .... 269-9~98---'2623':4'7 2800 2799.98 2723.47 2900 2899.98.. ~.~'~'-'3. 47 0 12 0 3 0 0 O' 1 .... 0 6 0 15 0~2-'2 ' ' 0 9 0 5 N"273-/i-0 ' W O. 17 S 60.50 E 0.26 N 4.60 E 0.07 .¢~6~-0-N 0~4 S 14.30 E.:;.: .0.09 S 77.30 E 0.23 S-%Ti3-O--E S 33.39 E O. 26 S 23.19 E 0.08 O-Z-CY4 O. 03 O. 04 0-----7' 0 7 S 29.19 E 0 6 S 27.50 E 4.46 S 4.31 $ 4.33 S 4.45 S 4.59 S 4.77 S 5.02' S 5.20 S 5.58 S 5.76 S j.¢. 91 W 4.24 W 4.65 W 4.93 W 4.95 W 4.91 W 4.9-i--~ 4.89 W 4.64 W 4. i-i--I~' 3.73 W 3.62 W 3-.-'55-W 3.44 W 3.35 W 1.34 07~ O. 82 O. 86 O. O. 97 1.23 1.67 2.09 2.30 2-,-4-9-- 2.72 ' 2.92 ,: 'ING COMPANY PAGE 2 STANDARD AK PROD. H-21 P~I]DHO£ BAY ALASKA CO. ANCHORAGE ALASKA COMPUTATION DATE JUNE 9,.:: DATE OF SURVEY JUNE 7. 1..~86 BL~S:_~ GYROSCOPIC SURVEY JOB NUMBER AK-BO-60033 .KELLY BUSHING ELEV. = OPERATOR-T. MCGUIRE 76'.51.FT.': ' ' VERTICAL SECTION CALCULATED -'==' ~ ALuNo CLOSURE TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL ..... M'~o~ED i' ~L~T'i'C'~i-~-~'ERT~'C:'AL ':ij~iOL'~'i~i~t¥iON':.'-[I~'R~-~i-~~'I~'E~'~-~' ~ ' I ....... REC~TANGL LAR COORD I NATES DEPTH DEPTH DEPTH DEG. MI N EAST/WEST DEGREES : .".; ..':: !'"' i!i~ i-.!,.:. ~-.:! '_~:~.:-::-:.'.:i: < ': ~" "' ': 3000 .... 2'.~.~.~-8------'2.~.~2-3~, 47 ' 0 6 S 28, 10 E O, 02 ~, 'P2 S :Si. 26 W 3100 309S/.98 3023.47 0 15 S 21.10 W 0.21 &.22 S 3.30 W 3200 3199.97 3123.46 0 12 S 31.50 W 0.07 6.59 S 3.48 W 3300 32:~/=?T;~-3'223'~-4-~; &]-~-4~ 3.68 W 3400 3399.97 3323.46 S 0.' 07 · ':. :. 7.3~: S 3.94 W 3500 349.9, 97 3423.46 . ~..:.-~ .o.~ .~ 7,80 S ".'.. i 4.21 W VERTICAL 3699.97 3623.46 3799, 97 3723.46 3999.96 .... 3.923, 45 : 4099..' 95 4023.44 "4-~~ ..... 4i~74-4 4277.75 4223.4~ 439~. ~4 4323.43 0 26 S 40.30 W 0 24 S 22.39 W o 32 s ~750 w 0 41 S 23.89 W 0 31 S 24.89 W ~i'.: DEG/IOO.::'.'NORTH/SOUTH 8.27 S 4.42 W SECTIONi 3.53 3.72 3.93 :i..4.14 -: 4.41 0.19 8.84 S 4.75 W 0.14 9.46 S 5.14 W 0]-i-1 i' OV-/'7--~ :'. :i.!.ii:' 0.08 ":...:' ' :i:".::10. 90 · S 5.87 W :i-:~i~ilo. 17'i: :i'; ':"'::: 11.~8's.: ~.3o w 4.69 5. O0 5.78 .:.,? ' i. . 6, 20 0.08 12...,5 S 6.77 W 6.65 0.15 13.52 S 7.~°c' W 0.16 14.49 S 7.66 W 7.21 7.77 8700 3800 3~00 4000 4100 4300 4400 4500 4600 4700 48O'0 4.~00 4~50 5000 5050 .. 5100 5I~0 5200 5250 5300 ' 5400 5500 479~9~ - 472'3]-4"1' 0 ' '34 ...... S~13--~-8:.~-i4 O. 0-3 17. ')9 S 4899, 89 4823.38 2 0 S 22.10 E 1.58 20.11 S 4949,81 4873.30 4 13 S 30.69 E 4.53 22.51 S 4'~9W,~.57 ' : 4-92'3~-0'5 ' 6 .:'55 ' ' ~--~4:-5-0-:'E:'::.::..: ' ~,45 26, 58 S 5049,06 4972.55 9:> 11.. S' :4.54 . 32 35 S . - . 5098.21 5021.70 58' ~" 37,50:"E~i.'::::: ::'::.::~5.~6~ ': :" 39.76 s 51-4-~:-874---507-0-:-3:2 14 ~ S 40.89 E 6.01 48.73 S 51.94.87 5118.36 17 22 S 44.39 E 5.34 58...o2 S 5242.37 5165.86 18 56 S 45.80 E 3.26 69.91 S 5~8~-~-5'/) ' 5212.9.9 20 4 S: 46.30 E : 2.30 81 . 50 S 7.96, W 8.22 W 8.50 W 8.76 W 8.22 W 6.95 W 4.30 O. 32 5.11 W W E 12.48 E 21.90 E 32.94 E 9.40 44.97 10.07 12.12 14.82 19. ~8 - · 26.69 '35.87 :" 47.42 61.13 76.41 92.73 5382.52 5306.01 ':':22 57" :::::::::::::::::::::::. :.12.90 106 59 S 71 72 E : - ::..~ . : i .. . · . . 5473.67 53:97.16 ' ' 25 35 S :46.69 E:' '2.64 . 134.63 S 101.77 E ~8.47 168.50 STANDARD AK PROD.. CO. H-21 PRUDHOE BAY ALASKA SPERRY-SUN WELL :_~LRVEYING · COMPANY DATE OF SURVEY dLINE 7, COMPUTATION DATE BOSS GYROSCOPIC SURVEY dUNE .................................................. .9, 1.986 JOB- ............................ NUMBER AK-B,J-60)c~z~;- ..... ='" ..... ~ '~ ~ KELLY BUSHING ELEV. = OPERATOR-T. MCGLIIRE PAGE. 3 1986 76.51 FT. VERTICAL SECTION CALCULATED ALONG CLOSURE TRUE MEASURED VER DEPTH DEPTH 5600 5700 5800 5900 6000 6100 ~=,LIB-$EA COURSE COURSE DOG-LEG TOTAL ...... ~ ....... ~ ................. -=7 ................ ~ ............... ~ ..... ,4 ........................... ~~ VERTIc. AL INL. LINATIoN DIRE[.TION .. sEVERITY RECTANOLILAR COORDINATES DEPTH DEG · MI N DEGREES DEG/100 NORTH/SOUTH EAST/WEST 5562.98 5486.47 27 49'" S 46.30 E 5650.48 5573. P7 30 3 S 45.3.9 E 5736.05 565.9.54 32 13 S 45.50 E 58-20~i& 5'74~T~4''~ ~.lo~~-~ ...... ~--4~.~ 60 E 5~03.71 5827.20 33 23 S,45.60 E 5987.22 5910.71 33 22 S 45.50 E VERTICAL SECTIC~N 2.24 165.57 S 134.36 E 212.34 2.28 199.27 S 1.69.06 E 259.67 2.17 235.55 S 205..92 E 3'10.32 '1%-~-' 273.43 S 244.53 E 363.28 0.13 311.86 S 283.78 E 417.07 0.06 350.3.9 S 323.06 E 470.~5 6200 6300 6400 ~500 6600 6700 6070.63 5.9.94.12 6153.8.9 6077.37 6237.1~ 6160.68 &o~O.._,o 6~44.07 6404.13 6327.62 6487'66 6411.14 ~800~6570,-54 6900 6652..62 6576.11 7000 6734.03 6657.52 71-00--'&;8-1-4]92~6738~I 7200 168.95.22 6818.71 7300 6.974.82 68~8.31 7~0 7~55~-00 7450 70.96.13 701.9.62 7500 7137..96 7061.45 33 34 33 41 33 28 ....... 33 ..:~1 ' 33 :..7 ~,..:, ..,.~,, .. ._"{._"i .... -.{. 35 12 35 47 · . ''L~I~'~' , ' . . 37 '-33 '~ 3~---5! . ' 33 28 32 55 S 45.19 E 0.27 38.9.16 S 44.80 E 0.25 428.33 S 44.60 E 0.26 467.65 S--4-;4~i-O--E 0:-~2'8 .... 50'7-~-1' T--S' S ..43.8.9 E -. O. 41' 546' 64' S 43.39 E 0.53 586.42 S~4-3-2-'D--E CjT~. f 62722 ! S 43.10 E 0.75. 668.95 S 43.50 E 0.62 711.21 4~-3TS'¥~-E. )0';-.;4-4'" 75-3-~8-.9--~ 43.60:E :!'i.~: ,.0.:71 .:: 7.97.12 S 43.30 E . 0.66 841.05 S 34.50 E 7.34 ..o08.57 S 31. 0 E 3..98 .931.58 S 362.30 E 401.47 E 440.38 E 4-7'8]~--E-- 517.13 E 555.08 E 632.37 E 672.1.9 E 7i-2T-~3--E 753.65 E -7.95.27 E ~3-4~77--E 851.88 E 866.6.9 E 525.00 579.35 633.68 ~-8'7~-4-- 742.03 7.96.21 ~851.41--- 907.80 965.08 1081. . 1141.47 l~-OD~7~ 1229.07 1256.43 7550 7600 7700 7306.55 7230.04 32 16 7900 7475.29 7398.78 32 28 8000 7559.60 7483.09 32 05 8100~76-43~-74~75~7~-23 ........ 32----49 8200 7727.61 7651.10 33 8300 7811.23 7734.71 33 22 717~;~-. 08 7'103':-45 -- ~2----4-8--~--~i)~E '7222.07 7145.56 32 26 S 30':10 2.9.89 E:: :.' 28.50 E 27.80 E 27-69: E~.:: ': 26, 89 :E : o.-~;-0 O- 75 - O. 20 O. 23 O. 40 0.3~ ' O. 37 978.25 1024.5.9 - 1118.44 1165.85 .... 1-2-I3-:'7:4--S · 1262.02 0.49. ' 1310.76 S ov,~l E 894.05 E 920.80 E 947~]~-E 972.93 E 998.30 E '~'~-~-~' 10~.~ E 1048.52 E 1073.68 E 1310.43 1363.82 ~4"i7.26 1470.80 1524.30 1632.15 '1686.64 WE 4". STANDARD AK PROD. H-21 PR'OD~-OE 'BAY CO. ANCHORAGE ALASKA COMPUTATION DATE UUNE :~ VERTICAL SE:C'TION CALCULATED ALONG _.LO:_~URE DATE OF SURVEY dUNE 7, BOSS GYROSCOPIC SURVEY 1:86 dOB NUMBER AK.-BO-60033 KELLY BUSHING ELEV. = OPERATOR-T.. MCGU I RE TRUE SUB-SEA COURSE COURSE DOG-LEG TOTAL MEASURED '.: VERT I'CAL VERT'I~OAE' 'INCL I'N'~TI'ON' J' ~ Dlq~OT]:ON i. 7 SEVEWIrT~/, .i REC'TANGUL/~R~E.~D I NATES' VERTI CALl:." DEPTH ' DEPTH DEPTH ::.".~:ii: :~.' DEG '...:.M I N DEGREES ::~.: .:i':i:!;:.~. DEO/1 O0 !"'7 NORTH/SOUTH 'i:.:EAST/WEST ." 8 ~ 00 I 78'95. O1 --781-8¥50 32 ''48 ' 'S' 26',' O' e 8500 797:. 37 7902.86 32 9 S 25. 0 E 0.84 1408.10 S 1121.11 E 1793.90 8600 8063.86 7987.34 32 31 S 24.30 E 0.52 1456.72 S 1143.42 E 1846.71 8800 .': 8231.03 8154.52 8900 8314.02 8237.51 S'! 22,:30 :?.0,: 80 :~' 9090 8472..52 87:~6. Ol :::3 6 S 21 . 10 E O. 43 91 O0 8480.90 8404.39 33 5 S 20.8: e 1.12 ::.'.'.::.1556.:'94::.:S 1188,1: E '.:'1:54'88 .... ::'1608.:31S 1209.95 E 2009,66 1659.73 S 1230.46 E 2063.79 1705 81 S 1248.'~ . ~ E 2111.99 1710.91S 1250.25 E 2117.32 9300 9400 9500I 9600 9700 8646.91 - 8570.40 '?:::.:::: 1289.39 e '8729.40 8652. ' ':':::.1.23 1.1867.73 S' .1310.~,7 E 8810 .--8 9-------8 734'~-38~-----'3'5 8891.55 8815.04 36 31 S 24.89 E 0.78 8971.91 ~ = 889~,.40 36 31 S 26.10 E 0.71 .~800 W051.5',5 897EC-. 4~ .... :~ : ..................... .:. 7 ::::.....:7:.... S.'.26,&9..E'."....'....0.7-0 9850 :.: 9091 ' 62 9015.11 '.'-.: .' .'":'.' ::::::::::::: ::::::?:?::::::: ::. S :'27,'::1 :::::::::::::?::::: :' '::':" 1.'58 9<200 : 9131.09 9054.58 ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 19: E ::::::':: :: ' 0.00 .~W61' I I ~'1'7.9~-.25 .... 9-I-02.--74 "37 "'51' ' S' 2'7.1".'?' E 0~-0-0 1974.73 S 1358.01 E 2028.45 S 1383.63 E ... 2-0~'.~-~C ' . 14~.'2~--E 2109.27 S ":' '::. :::.' 1"4;'4.08 E 2136, 56 S 1438.11 E ...... 21~-9 .--8~--L~ ' 1-455:-22--E 2225.84 ..~ 2281.157':! 2396.4~ 2455.33 2575.47 2612~~ HORIZONTAL DISPLACEMENT = 2612.65 FEET AT SOUTH 33 DEG. 50 MIN. EAST AT MD = 9961 THE CALCULATION PROCEDuREs ARE:: : 'BASED : :ON THE. Ll~:?b~ ::THREE DIM£NSIONAL RADIUS OF CURVATURE METHOD STANDARD AK PROD. F:O. H-21 PRUDHOE ~-AY SPERRY-SUN WELL' SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE .JUNE 9, 1986 PAGE. 5 DATE OF SURVEY dUNE 7, 1986 JOB NUMBER AK-BO-60033 ALASKA KELLY BUSHING ELEV. = 76.51 FT. OPERATOR-T. MCGUIRE MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES ',' MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 0 O. O0 -76.51 1000 999.99 923.48 ~000' 1 :-~9~.~ ;~8 1"923';"47 3000 2999.98 2923.47 4000 3999.96 3923.45 5000 48~'~-;-'57 .... 4'923';"05-- 6000 5903.71 5827.20 7000 6734.03 6657.52 80'00 7559~6'0 ~000 8397.30 8320.79 9961 9179.25 9102.74 0.00 O. O0 O. O0 4.07 8 2.23 W 0.01 0.01 4";-L~3--S -- 47.~'I--W 0';--c~'2 0';-01 5.92 S 3.26 W 0.02 0.00 10..~0 S 5.87 W 0.04 0.02 2-&-; ~-~,8-S --'~]-~-¢F-i;:l '0-~-4~ d'.-39 3!1.86 S 283.78 E 96.29 95.85 711.21 S 672.1m E 265.97 169.69 1 '1-6-:57-8-5'-S :' ' .~8.--9-~.0--E 4-4'c~W0 1'7~.'-4D 1659.73 S .::1230..46'E :-' ?602.70 :::162,30 2169,86 S :- 1455.22 E 781.75 179,04 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. STANDARD AK PROD. H-21 PRU~iHOE ' BAY ALASKA CO. YINO COMPANY ANCHORAGE ALASKA COMPUTATION DATE ,.JUNE 9,': 1986 .::i: i i:ii PAGE 6 DATE OF SURVEY dUNE 7, 1986 :dOB NUMBER AK-BO-60033 KELLY BUSHING ELEV. =" ~:76, 51'!:: OPERATOR-T. MCOUIRE .. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TI~OE VERTICAL DEPTH VERT I CAL '" ':: ! .'RECTANGLILAR co'oRD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE · ... VERTIE. AL CORRECT I ON 0 76 276 376 z~76 576 676 876 0.00 76.51 276.51 376.51 476T5'1' 576.51 676.5.1 876.51 -76.51 0.00 200.00 300.00 --40'0;~)'0 500.00 600.00 O. O0 O. O0 0.11 S 0.07 W :'";"'i'0.86'S- !'"0.62 W 1'19 S :-:": 0.85 W 1.57 S 1.01 W O. O0 O. O0 O. O0 Om 0.00 :':: '":" '0. O. O0 O. 00 O0 O0 0.00 0.00 800.00 2.14 S 1.23 W 2.65 S 1.42 W 3, 70' .S .,:"::: 1 :. 85 '. W'!:?i 0.01 O. O0 O. O1 0.00 O. O0 O. '01 O. O0 976 976.51 900. O0 4.02' 'S'I'?I 1-07~ f-O7Z-_;-,-5'l ........... fO-OOTO0 4.17--S 2.13'W 0.01 2.56 W 0.01 O. O0 O. O0 1176 1276 1476 1576 1676 1776 1176.51 1276.51 1476- 51 1576,51 1676.51 1776.51 1100.00 4.16 S 2.98 W O. 1200.00 4.21 S 3.28 W O. I'~OOTOO'. : .~'~'47721 e5 o. 1400.00 :'. ::::4'~0 S': ':' ::"'":'3.. O. W 1500.0~ .::..." :: ?:4.46 :'S '15 W O. 1600. O0 4.79 S 4T~5--W o. 1700.00 4.54 S 4.89 W O. O1 O. O0 O1 O. O0 O1 O1 02 O. O0 · 0.00 O. 00 02 02 O. O0 O0 ~=.TANDARD AK PROD. H-21 PRUDHOE BAY CO. ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE JUNE 9, 1986 DATE Of SURVEY ,.ILINE 7, 1986 JOB NUMBER AK-BO-60033 KELLY BUSHING ELEV. = OPERATOR-T. MCGUIRE 76.51 PAGE. 7 FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL ·.RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 1876 1.976 20'76 ' ' 2176 2276 2"~-76 2476 2576 1876.51 1800.00 1976.51 1900.00 ' '207~75'1 2000':'00 2176,51 2100,00 2276,51 2200,00 '23'7~'~'5'i--'23~:-~0 2476.51 2400,00 2576.51 2500.00 2776 2776.51 2700, O0 2876 2876.51 2800. O0 2976.:. ..... 2976,-51 .... 2900:-00 3076 3076, 51 3000, O0 3176 3176, 51 3100, O0 327~ ~27~:-5"1 3-200~-00 3376 . 3376,51 3300,00 3476 3476, 51 3400, O0 3576 35'7~-~-5 i 350~, O0 3676 3676.51 3600, O0 4.'30 S 4.98 W 0.02 4,34 S ' 4,91 W 0,02 4'~33-~ 4'7~i--~ 0.-02 4,41 S 4,.90. W 0,02 · . 4,57 S 4,75 W 0,02 O, O0 O, O0 O, O0 O, O0 O, O0 4,71 S 4.96 S 5,17 S 5 ,-:~-3--~ 5.54 '::'S 5.72 S ~;'-8-;':.;--'~ 6,12 S 6.51 S · 7,27 S 7, 71 S 4, 2~- W O. 02 O, O0 3, 77 W 0,02 0.00 3,64 W 0,02 0.00 3.47 W O. 02 0.00 3,37 W 0.02 0,00 3,28 W 3,26 W 3,43 W · "..~.:':.',: 3. 87 W ' 4,15'W O. 02 0.02 O. 03 · 0-.-0~.-~ · .. ' O. 03 ·' O. 03 0. O0 O, 00 O. O0 O-,-Ob · 0.00 O. O0 8,14 S 8,70 S 4.38 W 4.64 W O, 03 O, 03 O, O0 O. O0 PAGE 8 STANDARD AK PROD. H-21 CO. ANCHORAGE ALASKA COMPUTATION DATE PRUDHOE BAY ALASKA ,...IUNE 9, 1986, DATE OF SURVEY JLINE 7, 1986 dOB NUMBER AK-BO-60033 KELLY BUoHINI3 ELEV. = OPERATOR-T. MCGUIRE 76,51 FT.¸ MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRIL1E S-FJ~-.:-,"'~A ":"'.'' TOTAL:' .::.....:. ::.......i. i~ VERTICAL VERTICAL RECTANGULAR. cOORDI NATES'~iI D'TVD ' DEPTH DEPTH NORTH/SOUTH .... EAST/WEST :::' DIFFERENCE VERTICAL CORRECTION 3776 3776.51 3700.00 9.31 S 5.07 W 3876 3876.51 3800. O0 9.99 S 5.39 W .?,976 .... 39'7-~-5I~3900-['00 '10.~3'-S ........ 5;-8~--~ - ' 4076 4076.51 4000.00 11.48 S 6.17 W 417~ 417~.51 4100.00 12.35 S &.68 W 4~6 4~6~'I' ~'C~CL-O0 1%~'7--~ 7.1 O' W 4376 4376.51 4300. O0 14.30 S 7.56 W 4476 4476.51 4400.00 15.13 S 7.~1 W 4676 4776 4E:76 .... 4976 5077 ~18o--/. 5286 5393 5615 .4676.51 4600.00 4776.51 4700.00 4976.51 4900.00 5076.51 5000.00 ?" 17.176 S '8,70 W 24.48 S 5.70 W 36.29 S 2.50 E 51-7-6--7.51 5276.51 5200. O0 ' :.' ',:"-'78.22 S -'":' ..:::~::::41 53 E 5376.51 5300. O0 ';. '104.88 'S ' :.'; ~: ". ':69.87 E 5~7~-,~-~ .... 5'40(~b0 135.57~ 102.76 E 5576.51 5500. O0 170.50 S 139.52 E O. 03 O. 04 O. 04 O. 05 O. O0 O. O0 0-7~:~'0 O. O0 0.01 O. 05 O. 06 O. 06 0'07 O. 07 '.::' 0.07 O. O0 O. O0 O. O0 0-70o ..... ':"!:" '. O. O0 O. O0 0;~0~ O. 29 1.36 4-~-~ 1 6.98 O. 20 1.07 2.95 5.35 7.32 26.64 38.79 9.66 12.14 SPERRY-SUN WELL SURVEYINO COMPANY ANCHORAOE ALASKA E;TANDARD AK PROD. CO. H-21 PRUDHOE BAY ALASKA COMPUTATION DATE dUNE 9, 1986 DATE OF SURVEY dUNE 7, 1986 dOB NUMBER AK-BO-60033 KELLY BUSHING- ELEV. = OPERATOR-T. MCGLIIRE 76,51 PAGE FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH MEASURED DEPTH TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5730 5676.51 5600.00 5847 5776.51 5700.00 5'~7~5876'~'51 ..... 5800,"00 6087 5976.51 5900.00 6207 6076.51 6000.00 ~327 .... ~'1-7~'~-51 ......~'i00',-00 6447 6276.5'1 6200.00 6567 6376.51 6300.00 6807 6576.51 6500.00 6929 6676.51 6600.00 7052 6776~5'1~'~6700;"00 7176 6876.51 6800.00 7302 6976.51 6900.00 7426 ~' 7076T'51 '70'00~'00 7545 :. 7176.51 7100.00 7664 7276.51 7200.00 7782 '"737-6~-5-1 730-/F~00 7901 7476.51 7400.00 209.85 S 179.79 E 253.48 S 224.17 E 345.45 S >b.:-;~318.03 E 391.91S 365.07 E --'4~9%-0'3--S 53.57 71.37 9'07~i 110.67 130.54 ~'50~6'8 486.17 533.65 :630.20 681.26 --733~ 7 --S 786.93 842. O0 458.62 E 504.63 E ~J-~,O%-OO'E 596,. 17 E -~? ,: 643.89 E 743.95 E 796.15 E :.953.01S 1008.15 S : 911.35 E 1'063.'~1"S '' ~42'.66-E 1119.12 S 973.30 E 170.63 1.90.51 .230.73 252.73 275'~-..~-0 300.09 325.61 3-4'9'.-80 ' ~, ... ~6~. ~ 387.97 424.94 14.78 17.80 'i-9'~-54 19.76 1.9.87 19.95 19.88 20.62 22. O0 24.1'.--.,' 25.53 2zV.-l'i~ 1~.59 18.58 1-8.-~d7 18.60 STANDARD AK PROD. H-21 P-~O'DHO£ BAY ALASKA CO. SPERRY-SUN WELL sUR~E¥I N0:ICOMPANY ANCHORAGE ALASKA COMPUTATION DATE dUNE 9, 1986 PAGE DATE OF SURVEY dUNE 7, 1~ dOB NUMBER AK-BO-60033 KELLY BUSHING ELEV. = OPERATOR-T. MCGLIIRE 76.51 MEASURED DEPTH INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH F~LIE ~c~L~---~._~EA TOTAE~' ' ' VERTICAL VERTICAL RECTANGULAR COORDINATES ::'.MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST:'DIFFERENCE VERTICAL CORRECTION 8020 7576.51 7500.00 8139 7676.51 7600.00 8~58----777~751" 7700'";-0'0 8377 7876.51 7800.00 8496. 7976.51 7900.00 8~:~5 -' 8-07~.,-5"1--~000':'00 8734 8176.51 8100.00 8854 8276.51 8200.00 8~75"- 8~'7--~-~-.5-i .... 8o00.00~ ....................... 9094 8476.51 8400.00 9215 8576.51 8500.00 --~335'~8~'7'~;~'5i '860(F~0 9457 8776.51 8700.00 9581 8876.51 8800.00 9-705 89-7~'51--8900-~D0 9830 9076.51 9000.00 9957 9176.51 9100.00 9-9-~1 :'91-79'J25 '91'0~j74 1175.41 S 1003.34 E 443.56 1232.51 S 1033.06 E 462.49 1~2-9L3-~. ~8--~,~ -. ' 1-(~,~:B~-. ~'L~--E 481.92 1348.92 $ !092.77 E 501.48 1406.47 S I120.35 E 520.'11 18.62 18.9:'-: 19.43 19.56 18.63 1464.07 S 1146.74 E 538.50 1523.42 S 1173.45 E 557.81 1585.13 S 1200.41E 578.37 1646.90 ~ 1225.49 E ::598.57 :'::-1708'24 S .: 1249.22 E :':":.'-'618.25 1770.79 S 1272.50 E 638.49 1S. 19. 20. 39 31 56 20. 19. 20. 19 68 24 1~-~o.89 1898.17 1964.63 2098.85 2167.96 2169.86 1296.62 E 659.17 1323.43 E 681.04 1353.32 E 704.78 ' .... 11:-!1385.13 E 729.21 20.68 21.86 23.74 24.44 ' :1418.'74 E 1454.24 E 754.37 -781.02 1455.22 E 781.75 25.16 26.64 O. 73 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE--IqEP;'RE~ T--~z'O' ' FO0 T ' MD' '-~'FRC~--~-AD'i OS---CYF ' i_::LIR-V-A -50b. O0 5CRLE :- 1 INCH TO 500.00 / 500.0 PRUDHOE BAT H-21 AK-BO-60088 TRUE NORTH 5TANORRO AK PROD. JUNE ?. 1986 --500.00 --1000.00 --1500.00 --2000.00 --2500. O0 HORIZONTF~L soot oo ~oob. oo PBOJECTION 9961 0.00 2000.00 4000.00 6000.00 8000.00 lOOO0. O0~ SCALE :- 1 INCH TO 2000.00 / 2000.0 PRUOHOE 8AT 5TRNOARO AK PRO0. CO. H-21 JUNE 7, 1986 RK-80-60033 91'79. 9961 VEBTICRL ~obo. oo ~'~o. oo PRE~JECT[ON Form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR. 'WELL NAME AND'N~BER Reports and Materials to be received by.. ~,,.~- ~,,:'" ~ ' Date [ ' Required Date Received Remarks , <Completion Report y ,~,,.~ ~,"'--~[ ~-~, G~ . Well HistO~ y ,~,~, .'Core Chips Core Description , , Inclination Survey ,~ ~ .. ~ _._/~_ ~ ~~ . , , ' Dr~ll Stem Test Reports ~produet~on Test Reports '~' ' ~.,~~.~ 3' - ~~ ' ~i~: , , ...... , ,,,nos Run , , , , , Digitized Data '.' IEMORA D UM St a ,:of Alaska ALASKA C.. _~ /~[D GAS CONSERVATION COMMISSION /o: C.V. Chat~~. DATE: May 8, 1986 Chairman L/v ,,.,.-~ roLE NO.: D.HRH. 24 TH RU: FROM: Commissioner / ~ 0 Harold R. Hawkins Petroleum Inspector TELEPHONE NO.: SUBJECT: BOP Test SAPC H-21 PBU Permit No. 86-71 Prudhoe Oil Pool Thursday, May 1, 1986: I left Standard Alaska Petroleum Company's Y'-P~d,--s-Ubje~t"Of another report, and went to H Pad to witness a BOP test. Friday, May 2, 1986: I witnessed the BOP test on H-21 PRU. There was one failure 0f ia flange on the choke manifold. I filled out an AOGCC report which is attached. In summary, the Nabors 18-E crew replaced an API ring in the choke manifold flange and completed the BOP tests. They were satisfactory. 02-001 A { Rev 1 {3-R4) Inspector STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report . Well Location: Secf/ T//~/ R/~'OM Drilling Contractor Ri Location, General Well Sign~ General Housekeeping O~Rig Reserve Pit Mud Systems Visual Audi Trip Tank Pit Gauge Flow Monitor Gag Detectors BOPE Stack Annular Preventer .-, Pipe Rams Blind Rams Choke Line Valves · '. H.C.R. Valve · Kill Line Valves Check Valve .. Test Pressure ACCUMULATOR SYSTEM Full Charge Pressure opf~ psig Pressure After .CIo.sure /~f psig Pump incr. clos. pres. 200 pSig --- mi~ sec. Full Charge Pressure'Attained: ~ min~~' SeC, Controls: Master Remote ~/~ Blinds switch coverf~ ,Kelly and Floor Safety Valves Upper Kelly Lower Kelly. Ball Type Inside BOP Choke Manifold No. Valves~ No. flanges Test Pressure ~'Zgz~' Test Pressure ~,"z::~ ~/ Test Pressure ,~4"~~ Test Pressure ~4~-~ ~ 0 Test Pressure ,,,~/~ ~ Adjustable Chokes ~-Z~) ~ 'draui an'choke Repair or Replacement of failed equipment to be made within :' days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector April 28, 1986 Mr. R. S. Allan District Drilling Engineer Standard Alaska Production Company P.O. Box 196612 Anchorage, Alaska 99519-6612 -TelecoPy: (907) 276-7542 Re: Prudhoe Bay Unit g-21 Standard Alaska' Production Company Permit No. 86-71 Sur. Loc. 534:SNL, 1266'WEL, Sec. 21, TllN, R13E, UM. Btmhole Loc. 2597'S~, 133'E~L, Sec.22, TllN, R13E, UM. Dear Mr. Allan: Enclosed is the approved revised application for permit to drill the above referenced well. Se provisions of the cover letter, dated April 2, 1986, accompanying the original approved permit are in effect for this revision. Ve t 1! o~rs Chairman o f Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of' EnVironmental Conservation w/o encl. Mr. Doug L. LoWery ·f/"'-,, STATE OF ALASKA ~ ALASKA C.._AND GAS CONSERVATION COI~,,vllSSION PERMIT TO DRILL REVISED 20 AAC 25.005 la. Type of work Drill [] Redrill E]I lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil E~ Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool Standard Alaska Production Company Est. KBE 75' AMSL feet Prudhoe Bay Field 3. Address 6. Property Designation Prudhoe Bay Oil Poo P.O. Box 196612, Anchorage, AK' 99519-6612 ADL 28284 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 534' SNL 1266' WEL Sec. 21 TllN R13E Prudhoe Bay Unit Blanket At top of productive interval 8. Well nurpber Number 2400' SNL 0' WEL Sec. 21 TllN R13E H-21 (42-21-11-13) K00683449-G-14 At total depth ~ 9. Approximate spud date Amount 2597' SNL 133'~Sec. 22 TllN R13E April 29, 1986 $200,000.00~ 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line · 9206' TVIJ A.DEL 28287 2880 feet t-I-7 35 feet 2560 9961'ITD feet 16. To be completed for deviated wells 35u43' 17. Anticipated pressure (see 20 AAC 25.035 Kickoff depth 5000 feet Maximum hole angle 0 Maximum surface 3330 psig At total depth (TVD) 8800 ~,,',390 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) 20" Conductor ~'~ Surfac~ 110' 110' 8 cu. yds. Concrete 17½" 13-3/8' 72¢/ L-80 Butt.. 2650' Surfac~, 2680' 2680' 3723 cu. ft. Perma E&P 12~" 9-5/8" 47# L-80 Butt/ 9141' Surfac~ 9171' 8564' 575 cu. ft. Class G NSCC 8~" 7" 29# L-80 Butt 1040' 8921' 9961 9206' 300 cu. ft. ClassGw/5% 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production ~,i::~ Liner Perforation depth: measured ..... ~ '-' true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch E~ Diverter Sketch [] Drilling program Drilling fluid program E~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25,050 requirements [] 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed , ~, ~ Title D~illing Engineer Date -- Commission, Use Only / / 86-71 50-- 029-21.575 04/02/86 for other requirements Conditions of approval Samples required [] Yes l~No Mud log required E] Yes ~ No Hydrogen sulfide measures [] Yes [] No Directional survey required ~ Yes [] No workin ssure or B 2M; [] ; '~ 5M; [] 10M; [] 15M Required ~/.~~ Other: by order of Approved b Commissioner the commission Date Fnrm ld-4~1Rnv 12-1-RR Submf :ate PROPOSED DRILLING AND COMPLETION PROGRAM WELL H-21 [ 42-21-11-13 ] PBU Install and cement 80' of 20" conductor to surface. The drilling fluid program will consist of an 8.5-9.5 ppg spud mud in the 17-1/2" hole, a 9.0-9.7 ppg water base mud in the 12-1/4" hole and a 9.2 ppg water base mud in the 8-1/2" hole. Drill 17 1/2" hole to 2700' and cement 13 3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 mixed string of Buttress and NSCC to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreezing fluid. Directionally drill 8 1/2" hole to TD. Run 7" liner from TD to 250' inside 9 5/8" casing shoe and cement using Class G cement with 5% KCL. Clean out to 7" float equipment. Change over to 9.6 ppg. NaC1 completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer on internal plastic coated tubing with gas lift mandrels and a sliding sleeve. Set packer 50' above top of liner. A subsurface safety valve with dual control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Suspend well for perforating subsequent to rig release. Tubing Size: 5 1/2",17#,L-80,A/B MODIFIED BTC Tailpipe Size: 4 1/2", 12.6~, L-80, BTC RLB:24-APR-86 PROPOSED DOWNHOLE DIAGRAM WELL H-21 [42-21-11-13] PBU PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2045 13 3/8" Casing Shoe 17 1/2" Open Hole 2680 2700 9 5/8" Packer 7" Tieback Assembly 8870 8921 9 5/8" Casing Shoe 12 1/4" Hole 9171 9176 7" PBTD 9921 7" Liner Shoe 9961 8 1/2" Open Hole 9961 RLB: 23-APR-86 B.O.~% S'TACK CONFI.G,U.~A I,ON 5/8" TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK 2'" KILL UNE DRILLING SPOOL 4" CHOKE LINE HAND GATE GATE GATE HYDR. ASST. ~ GATE PIPE RAMS / 30 40 ~J 40 20 ~0 40 I' : CAMP --J AREA · -.,o H- ,~ (~c~u~l) I 4,,8, ~ · I=, I~ ~'+t~,-~,-''-,, ~ ~ 2~ ~-~1 - I1-1~ THIS SURVEY'. '- , ~,.,o',,',,.,~" ~o,~.,,,.,o:,,.,~" I L F~* ~-~/-//-'~ ~ ~"~' / , i ~'~'"'"""' I PAD D~TAI~ ............................................ I scaue ,': ~oo : I ~' I~PORTiON SCALE I" = I/~ MILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plot represents a location survey mode by me or under my supervision, and that all dimensions and other details are correct. ~"~: ~,, -z.. ~ - x ,,~ Date SURVEYOR REVISED H-21 8, H-22 SURFACE LOCATION, ADD H-23 BHL ~%REVISED H-21 SURFACE LOCATION DDED LOCATION H-22 DDED LOCATION H-21 REVISED H-6, H-7~H-8 (ACTUAL) REVISED H-7 (PROPOSED) REVISED H-6 8 ADD H-7~ H-e ACTUAL 8800' SUB SEA LOCATION H - $, H-4 I~ H- 5 AODED LOCATION ADDED LOCATION H-5, REVISED H-?_ ADDED LOCATION H-4 ADDED LOCATION H-:~, REVISED H-I BOTTOM HOLE LOCATION H-I 4 -25 -86 , 3-11-86 '-- --~' 9- 3-85 8 - 16-85 ~-",¢-~ - :5- 13-78 C,J.R. IZ- 1.5-76 11-2.4-76 C.J.R. I0~~0- ?§ C.J.R. 9-30-71 M.L.S. 9-9-?1 M.L.S. 8-15-?1 M.L,S. ?-14 -71 M. L .S. ,.t-29-71 M. LS. PA D "H" Located in NE I/4 PROTRACTED SEC. 21~ T. II N.~R.13E.~ UMIAT MER.aALASKA Surveyed for B.P. ALASKA INC. Surveyed by F.M. LINDSEY & ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alosk(~ Tl1~'4 R13E SEC 21, SqL=534' WEL=126~' 3 230 430 630 830 1 300 1_~00 14-17 7° LE :ID -/~/~ ~7~ 70 4NO ' ~qNN ~H-$ 7 LEI:ID !~NN 1~.NN ~ , i 2S()' RC,DIUE~MFOET cIRC;EE'-' ~22NQ ~ I T IN ~13E SEC 2l, SNL::240I ' ~EL=()' ............. i $15DUA12:[DRAN018]H21 CLOSAP SHORTT.LIS;6 Search Radius= 1427 7 DEGREE LEAD LINE For proposed well: H-21 [42-21-11-13] Location = W-E S-N TVD(SBS) Top 643306.00 5960254.00 -75.00 Bottom 644958.39 5958435.15 9081.48 Note: All depths in feet Below Kelly Bushing (BKB) ---- 23-APR-1986 --- Closest Approach Analysis --- Date: 23-APR-86 Time: 14:48:25 14:49 Page Closest Approach WELL IDENT /PROPOSED% /NEARBY~ TVD DEPART TVD DEPART A029-2009900 H-1 A029-2010000 H-2 A029-2010300 A029-2010400 H-4 A029-2010600 H-5 A029-2023800 H-6 A029-2024200 H-7 A029-2024700 A029-2048200 H-9 A029-2048400 }{-12 A029-2048500 }{-Il A029-2048700 H-10 A029-2055900 }{-13 A029-2058000 H-14 A029-2059100 H-15 A029-2059200 H-16 A029-2086200 H-17 A029-2088000 H-18 A029-2088300 I-I-19 A029-2089600 H-20 A029-2145600 }{-27 A029-2147800 H-25 A029-2148700 }{-26 11 2 6338 6 11 1 110 6 10 9 00 00 299 0 99 3 98 8 98 5 99.2 7268.8 4772.0 0.0 4711.0 95.1 4839.7 0.0 194.8 102.5 101.8 3.0 CLOSEST DISTANCE 0.0 0.0 0.0 636.2 431.5 6322.2 75.5 419.0 0.0 0.0 0.0 436.2 0.0 100.0 0.I 336.1 0.0 0.0 0.0 236.2 0.0 1.4 0.0 I36.0 0.0 1.2 0.0 35.1 0.0 300.0 l.O 65.0 0.0 100.0 0.2 1558.6 0.0 100.0 0.8 1228.0 0.0 100.0 0.4 1338.2 0.0 100.0 0.4 1448.1 1100.3 6996.9 1462.2 752.3 0.0 4779.3 1012.4 506.2 0.0 6.0 0.0 898.3 0.0 4718.7 770.8 720.2 0.0 100.0 0.2 543.1 0.0 4845.0 809.7 363.2 0.0 3.6 0.0 471.5 0.0 100.0 0.7 471.6 0.0 100.0 0.4 480.2 0.0 100.0 0.2 481.1 0 .0 0.0 0.0 469.1 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 7622.2 1354.3 4552.9 1064.1 -3058.2 5973.9 217.3 3250.9 223.3 -2712.5 5499.4 55.1 3222.3 35.6 1224.3 7441.4 6462.7 -2278.6 520.8 5406.0 824.8 -2042.9 4442.0 703.2 -2027.9 5306.6 20.8 4211.5 547.4 -1100.0 $1$DUA12:[DRAN018]H21 CLOSAP SHORT7.LI$;6 AO 29-2151200 H-24 3.2 0.0 0.0 0.0 517.4 23-APR-1986 14:49 Page 2 SUMMARY The well which comes closest to the proposed well is: A029-2024200 H-7 Closest approach distance = KICK OFF for this run = 35.1 feet 5000.0 feet $1$DUA12:[DRAN018]H21 CLOSAP SHORT.LIS;6 Search Radius= 1427 COURSE LINE For proposed well: H-21 [42-21-11-13] Location = W-E S-N TVD(SBS) Top 643306.00 5960254.00 -75.00 Bottom 644724.35 5958247.29 9081.48 Note: All depths in feet Below Kelly Bushing (BKB) 23-APR-1986 --- Closest Approach Analysis --- Date: 23-APR-86 Time: 14:47:19 14:48 Page WELL IDENT A029-2009900 H-1 A029-2010000 H-2 A029-2010300 H-3 A029-2010400 H-4 A029-2010600 H-5 A029-2023800 A029-2024200 H-7 A029-2024700 H-8 A029-2048200 H-9 A029-2048400 H-12 A029-2048500 H-11 A029-2048700 H-10 A029-2055900 H-X3 A029-2058000 H-14 A029-2059100 H-15 A029-2059200 H-X6 A029-2086200 H-17 A029-2088000 H-15 A029-2088300 H-19 A029-2089600 H-20 A029-2145600 H-27 A029-2147800 H-25 A029-2148700 H-26 Closest Approach /PROPOSEDN /NEARBYN TVD DEPART TVD DEPART 11 2 6404 4 11 1 110 6 10 9 0 0 0 0 299 0 99 3 98 8 98.5 99.2 7046.5 4772.0 0.0 4711.0 95.1 4839.7 0.0 194.8 102.5 101.8 ~.0 CLOSEST DISTANCE 0.0 0.0 0.0 636.2 478.9 6388.2 75.9 363.4 0.0 0.0 0.0 436.2 0.0 100.0 0.1 336.1 0.0 0.0 0.0 236.2 0.0 1.4 0.0 136.0 0.0 1.2 0.0 35.1 0.0 300.0 1.0 65.0 0.0 100.0 0.2 1558.6 0 .0 100.0 0.8 1228.0 0.0 100.0 0.4 1338.2 0.0 100.0 0.4 1448.1 940.4 6743.8 1358.0 846.9 0.0 4779.3 1012.4 506.2 0.0 6.0 0.0 898.3 0.0 4718.7 770.8 720.2 0.0 100.0 0.2 543.1 0.0 4845.0 809.7 363.2 0.0 3.6 0.0 471.5 0.0 100.0 0.7 471.6 0.0 100.0 0.4 480.2 0.0 100.0 0.2 481.1 0.0 0.0 0.0 469.1 Vertical /PROPOSED\ TVD DEPART Intersection /NEARBY% TVD DEPART VERTICAL DISTANCE 6983.6 895.3 4036.8 586.5 -2935.7 5985.3 223.0 3189.7 195.8 -2785.1 5489.0 52.9 3172.9 29.7 -2317.5 7362.1 1167.3 500510~.,, 668.3 -2364.6 . 6505.3 551.4 4363.2 631.0 -2149.4 5301.9 20.0 4208.2 544.8 -1098.6 $1$DUA12: [DRAN018]H21 CLOSAP SHORT.LIS;6 A029-2151200 H-24 3.2 0.0 0.0 SUMMARY The well which comes closest to the proposed well is: A029-2024200 H-7 ClOsest approach distance = KICK OFF for this run = 35.1 feet 5000.0 feet 0.0 517.4 23-APR-1986 14:48 Page 2 MUD WEIGHT CALCULATIONS WELL H-21 [42-21-11-13] Mud Wt. (8 1/2" Hole): 9.2 ppg. P Sag River: P Sadlerochit: P Top Sadlerochit: OB Sag River: OB Top Sadlerochit: Current GOC: 9 5/8" Casing Pt. Top Sag River Top Sadlerochit 3920. 3800. at 8800' TVDSS 3738. 180.84 411.71 8710. TVDBKB 8564. TVDBKB 8572. TVDBKB 8674. TVDBKB CEMENT CALCULATIONS 13 3/8" CASING Measured Depth: 2680. Basis: 2 X Annular volume Total Cement Vol: 3723. [cu ft] Lead Slurry Vol : 3258 [cu ft] Tail Slurry Vol : 465 [cu ft] 9 5/8" CASING Measured Depth: Basis: 500 Sacks Total Cement Vol: Lead Slurry Vol : Tail Slurry Vol : 9171. 575. [cu ft] 575 [cu ft] 0 [cu ft] 7" LINER Measured Depth: 9961. Basis: 1.5 X Annular volume to 9 5/8" shoe + 150 cu ft Total Cement Vol: 300. [cu ft] RLB: 23-APR-86 PIL. I., 'TA~JK. V~I. UH[ T~K Dk'G,4 55ER T^~I K VACctU~l TYPE Choke Manifold Poor Boy Degasser . Brandt VacuumvType Degasser Brandt Dual Tandem Shale Shaker Pioneer Mud Cleaners Pioneer MKI Centrifuge ;TRI~JTION TO PIT 1 - Recording drilling fluid~ pit 'level indicator with both visual and audio warning de~tces at driller's console ' 1 - Trip Tank (75 BBL.) . 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp AgitatOrs April 2, 1986 Mr. R. S. Allan District Drilling Engineer Standard Alaska Production cOmPany P.O. Box 196612 Anchorage, Alaska 99519-6612 -.Telecopy: (907) 276-7542 Re: P~dhoe Bay Unit H- 21 Standard Alaska Production Company Permit No. 86-71 Sur. Loc. 518:SNL, 1266'WEL, Sec. 21, TllN, R13E, UM. Btmhole Loc. 2598'SNL, 5147'WEL, Sec. 22, TllN, R13E, UM. Dear Mr. Allan: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface ~casing shoe is drilled. Where a dtverter system is required, please also notify this office 24 hours prior to commencing equiPment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. truLv~.vQur s _ .× ~-~G. V. ~a~te~ton Chat~an of'~ Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 March 6, 1986 Alaska Oil & Gas Conservation Commission 3001. Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C.V. Chatterton Gentlemen. Well H-21 (42-21-11-13) PBU Enclosed are the following documents in triplicate along with our check for $100.00 to cover the permit filing fee. · 3. 4. 5. 6. Application for Permit to Drill Proposed Drilling Program Outline Proposed Blowout Prevention Diagram Surveyor's Plat showing Well Location Directional Map 20" Diverter Diagram If you have any questions, please call Ted Stagg at $64-5173. Yours very truly, SOHIO ALASKA PETROLEUM COMPANY RSA/MAW/dg/O144D Enclosures cc- C. M. Mason .Well File #17 R. S. Allan Division Drilling Engineer STATE OF ALASKA ALASKA (~,~ AND GAS CONSERVATION COiv, MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL ~] SINGLE ZONE i-~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 9. Unit or lease name 518' SNL, 1266' WEL, Sec. 21, TllN, R13E, UM Prudhoe Bay Unit At top of proposed producing interval 10. Well number 2400' SNL, O' WEL, Sec. 21, TllN, R13E, UM H-21 {42-21-11-13) PBU At total depth 11. Field and pool 2598' SNL, 5147' WEL, Sec. 22, TllN, R13E, UM 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Prudhoe Bay Est. KBE 75' AMSLI ADL 282~B~~. ~%~-~ Prudhoe Oil Pool 12. Bond information (see ~0 AAC 25.025) Type Blanket Surety and/or numbe~afeco Ins. 2975387 Amount $200,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed NW of Deadhorse l0 miles ADL 28287 2682 feet wel) H-13 1500 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 9972 'MD 9209' TVD feet 2560 Al~r±l 7; 1986 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures --3330--psig@ . Surface KICK OFF POINT 5000' feet. MAXIMUM HOLE ANGL~5°52') (see 20 AAC 25.035 (c) (2) 4390 psig@ 8800 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 36" 20" Con(luctor 80' Surfac~ 11 O' I 11 O' 8 17-1/2" 13-3/B" 72# L-80 Butt 2630' Surfac~ 2660'1 2660' 3?20 cu. ft Permafro~' 12-1/4" 9-5/B" 47# L-80 Butt/ 9145' Surfac~ 9175'1 8563' .5?0 NSCC ~ 8 1/2" 7" 29# L-80 Butt 1047' 8925'~, 8360' 9972')~ 9209' 302, cu. ft ClassG+5%) 22. Describe proposed program: See attached drilling and completion program. · · · · _, -23. I hereby certify that the foregoing is true and correct to the best of my knowledge SmGNED . ~. (~ T,TLE Dril 1 ing Engineer DATE '~. The space below for Commission use CONDITIONS OF APPROVAL~ required Mud log required Directional Survey required . ~ k~ /'1 APl number Samples I-lYES ~O []YES ,~NO [~ES []NO~') /..,,/' Permit number Approval date ~-~/. //~ 0~/0~2/~6~ , SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY_ ,COMMISSIONER DATE [ -- ] t ' / ' ~ --~/~~ m by order of the Commission Form 10-401 ~ Submit in triplicate Rev. 7-1-80 CL PROPOSED DRILLING AND COMPLETION PROGRAM WELL H-21 [ 42-21-11-13 ] PBU Install and cement 80' of 20" conductor to surface. Install 20" diverter. D~ill 17 1/2" hole to 2680' and cement 13 3/8" L-80 Buttress casing to surface. Install blowout prevention equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer. Maximum possible bottomhole pressure is 4390 psi at 8800' TVDss based on original resevoir pressure. Maximum possible surface pressure is 3330 psi based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to the 9-5/8" casing point above the Sadlerochit Sandstone. Run 9 5/8" 47# L-80 mixed string of Buttress and NSCC to within 5' of 12 1/4" TD and cement in two stages: First stage using Class G cement around the 9 5/8" shoe. The second stage to be downsqueezed in the 13 3/8" x 9 5/8" annulus followed by nonfreeZing fluid. Directionally drill 8 1/2" hole to TD. Run~7" liner from TD to 250' inside 9 5/8" casing Shoe and cement using Class G cement with 5% KCL. Clean out to 7" float equipment. Change over to 9.6 ppg. NaCl completion fluid. Test casing and lap to 3000 psi. Run 9 5/8" production packer.on internal plastic coated tubing with gas lift mantels and a sliding sleeve. Set packer 50' above top of · liner. A subsurface safety valve with dual. control lines will be placed 50' below base of permafrost. Install and test Xmas tree. Displace tubing to diesel. Set and test packer. Suspend well for perforating subsequent to rig release. Tubing Size: 5 1/2",lT#,L-80,A/B MODIFIED BTC Tailpipe Size: 4 1/2", 12.6#, L-80, BTC Note: 5000' (KBD) KICK OFF POINT CMM: 9-MAR-86 PROPOSED DftWNHOLE DIAGRAM WELL H-21 [42-21-11-13] PBU PROPOSED DEPTH BKB 20" Conductor 110 Ball Valve 2048 13 3/8" Casing Shoe 17 1/2" Open Hole 2660 2680 5 1/2",17#,L-80,A/B MODIFIED BTC, IPC W/7 Gk~'s 9 5/8" Packer 8875 7" Tieback'ASsembly: - 8925 .. 4%", 12.6# .... ~L-80, BTC Tailpipe, w/4%" X and XN Nipples 9 5/8" Casing Shoe 12 1/4" Hole 9175 9180 7" PBTD 9932 7" Liner Shoe 9972 8 1/2" Open Hole 9972 CMM: 9-MAR-86 B'O.P. ,~,TACK CONFIGUR,~'TION - i i i i i 1:5 5/8" TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK 2" KILL UNE DRILLING SPOOL 4" CHOKE LINE HAND HAND GATE GATE GATE PIPE RAMS HYDR. ASST. GATE RECEIVED ~AR 2 4 Gas Cons. Commission PAD DETAIL ' ' SCALE = 00' I~PORTION T. II N.,R. ISE:. SCALE I"= I/;> MILE CERTIFICATE OF SURVEYOR I hereby certify that I am properly registered and licensed to practice land surveying in the State that this plat represents a location survey made l~y~ er under my supervision, and that all dimensions and other details are correct. ~"~ ~,, Date SURVEYOR REVISED H-21 SURFACE LOCATION ADDED LOCATION H-22 ADDED LOCATION REVISED H-6, H-78~H-8 (ACTUAL) REVISED H-7 ( PROPOSED} REVISED H-6 I~ ADD H-71~ H-8 ACTUAL 8800' SUB SEA 1.0CATION H- :5, H-4 8 H- 5 ADDED LOCATION H-6 ADDED LOCATION H-5, REVISED ADDED LOCATION ADDED LOCATION H-3~ REVISED'H-I BOTTOM HOLE LOCATION H-I , H-2 ~-11-86 9-3-85 8 - 16-85 ~- 13-78 C.J.R. 12- 15-76 C.J.R. I 1-24-76 C.J.R. 10-:50-75 C.J.R. 9-:50-71 M.L.S. 9-9-71 M.L.S. 8-1:5-71 M.L.$. 7-14 -71 M. L .$. 3-29-71 M.L.S. II I PA D "H" Located in NE 1)/4 PROTRACTED SEC. 21~ T. II N.~R.13E.~ UMIA¥ MER. iALADKA Surveyed for B.P. ALASKA INC. Surveyed by F M. LINDSEY I~ ASSOC. LAND 6 HYDROGRAPHIC SURVEYO'RS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska iTll~q R13E S~CTI]N 21, S~L=S18' WEL=1263' i~ 3 2 30 ' 430 ~ 30 8 30 1 300 1 700 .i ,. · , FI': /. INI--l'7 ./o LI:RO ' . · 7AA H, Ii¢ 7: LEnD 4AN gNA , / . , ~ ~ H-I~ 7° ~ 7° .EAD . I NE ~ ~n0 ,, ~ : [ ~-0, ~ u.~ ~as Cons. 1 ~NN. · ,, 7 3AN ~~ ~ '$1$DUA12' [DRANOO3]H21_CLOSAP_SHORT7. LIS;8 9-MAR-1986 18:43 --- Closest Appeoach AnalUsis --- Date: 9-MAR-86 Time: 18: 43:34 Search Radius= 1434 7 DEGREE LEAD LINE For proposed well' H-2] [42-21-11-13] Location = W-E S-N TVD(SBS) Top 643306.00 5960270.00 -78.00 Bottom 644799.80 5958613.10 8748.65 Note: All depths in ;eet Below Kelly Bushing (BKB) WELL IDENT A0~9-2009900 !: A0~9-2010000 A0~9-2010300 A029-2010400 H-4 AO~9-=nO 10600 H-5 A0~9-~023800 H-6 A0~9-20~4200 H-7 A0~9-2024700 H-8 A0~9-2048~00 H-9 A0~9-2048400 H-12 A0~9-~048500 H-11 A0~9-8048700 H-lO A0~9-~055900 ~13 A0~9-~0~8000 H-14 AO~-~O~iO0 AO~e-~O~800 H-16 A029-~086~00 H-17 ~18 A0~9-~088300 H-I~ AO~9-~O89&O0 H-~O AO~9-~ ~ H-~ Closest Approach /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART 14.2 0.0 0.0 O. 0 Vertical Intersection CLOsEsT :~" ,,;/PRoPosED\,!, .: ,ij;,i"i' '" /NEARBY\ VER FICA;_ , , DISTANCE TVD DEPART ' : . TVD DEPART D 1STANC-~ 6356.8 444.7 6337.3 75.6 428.3 14. I 0.0 0.0 0.0 452.2 7667.2 1392.4 4581.8 1090.8 -3071. i.Z 113.6 0.0 100.0 0. I 352. I 5995.~ ~7.8 3272.2 233.2 -2,'0~. 4 13.9 0.0 0.0 0.0 1.6 0.0 0.0 0.0 15~. 0 1.6 0.0 302. 0 O. 0 ~.3' 0.0 101. 8 O. 0 101. 5 O. 0 10~. ~ O. 0 7~8~. 0 1116.0 4775. 0 O. 0 0.0 0.0 4714. 0 O. 0 4842. 7 : O. 0 0.0 0.0 197.8 - 0.0 .. .. 103. 3 0.0 104.8 0.0 O. 0 O. 0 51. 0 556,5.8 71. 4 3292. ~oo. o 1. o 49. o O. 0 O. 0 1574. 4 100. 0 O. 8 11244. 0 100. 0 O. 4 1354. I ~ c~ ~oo. o o. ~ ~. c~ CO 831. 5 - ~ 0,96. 7112. 6 -~0~5. '"~"-$~.~D~12: l;DR^NOO33H2] CLOSAP SHORTT. L]'S, 8 '. ~,:A029-2! 51200 .... ' ' *. C ...... ~-'"~4 .............. ."&;*;'~ ~7'?- O. 0 0;' 0"* SUMMARY The weXX uhtch comes closest to the p~oposed ~ell ts: A029-20~4700 H-~ Closest approach distance = 47~0 Feet KICK OFF FOT' this"~T*Un ~' ~'000.0 .,Feet O~ 0 ~-MAR-1986 18:43 Date: 9-MAR-86 Time: 18: 42:57 Search Radius= 1434 COURSE LINE Fo~ proposed well: H-21 [42-21-11-13] Location = W-E S-N TVD(SBS) Top 643306.00 5960270.00 -78.00 Bottom 644586.69 5958443.37 8748.65 Note: All depths in Feet Below Kell9 gushing (BKB) WELL IDENT Closest Approach /PROPOSED\ ''/N£ARBY\ CCOSEST TVD DEPART TVD DEPART DISTANCE Vertical Intersection /PROPOSED\ /NEARBY\ TVD DEPART TVD DEPART A0~9-~009900 H-i 14.2 A0~9-2010000 H-2 6420.0 AO29-2010300 H-3, 14.1 A029-2010400 H-4 113.6 A0~9-2010600 H-5 13.9 A029-2023800 H-6 1.6 H-7 1.6 A029-2024700 H-8 302.0 A029-2048200 H-9 2.3 A029-2048400 H-12 101.8 A029-2048500 H-II 101.5 A0~9-2048700 H-lO 102.2 A029-2055900 H-13 70)4.3 A029-2058000 H-14 477~.0. A0~-2059100 H..-15 0~0' A029-2059200 "' " "' H-16 4714.0 0.0 0.0 0.0 652.2 490. 4 6398. 8 76. 0 371. 0 O. 0 O. 0 O. 0 402. 2 O. 0 100. 0 O. I 3~2. 1 0.0 0.0 0.0 252.2 0.0 0.0 0.0 1152.0 0.0 0.0 0.0 51.0 O. 0 300. 0 1. 0 49. 0 O. 0 O. O' O. 0 1574. 4 O. 0 100. 0 O. 8 1244. 0 O. 0 100. 0 O. 4 1354. 1 O. 0 100.0 O. 4 1464. 1 949. I 6745. 2 1358. 6 846. 6 O. 0 4779.3 1012. 4 509. 9 O. 0 3. O' O. 0 914. 2 · . O. 0 4718. 7 770. 8 728. 4 VE3 FICA:. D I C TANC-' 7018. 4 923. 2 4054. 3 602. 4 -2~,0. 0 6007.2 233. 8 3208. 9 204. 4 -2.:C.;4. ' 5553.~ 68. 4 3236 7 37. 6 7376.~ ~ 1181.9 5018. 1 673. 3 ~517. 0 ~?--. 5aO. ~ 4372. 1 S3~. I A029-2086200 . -' H-17~m:' ::''' ''451}'~'::9'''' ~ ~:. 0'0 4~4' 8 . ' 859' I 318: 1' .'~399' 7., ':~:::''~.':~'~' ;: ;-4aa0' 0 ~, ,.,.:AO~-~ ~-..:; - .... :,: .:~,,.~:;,~' ~ : '-,'~.~.~..,,~ "? ' ' ' '*?"" ~":'""' ........................ AO29-a088300 .... .-~ ~ H-19 . ,': ;0. 0 ~ ' 0:.'0 O. 6 O. 0 474. 0 ~ ~' ~., .: ,::' ~az; 4-' ~. :.~; ;,;~¢i~:~;~:',~!~;;.-.: ;' O'; O ?: "" .;'-i~;,o ,: ~ ~ · A0~9-2147800'- . ...... ::-.~j'.i .Jli":'7" ./?:,' ' . ' '' 0' 7 m ' i~ '470~ 3 ........... . __' O. 4 !: 477..3 0.2 485.4 554. I -2315. -~ -23&2.7 -2149.'2 · AO~9-~l 51 ~00 H-~4 ..... ~'.':~'~ 0. 0 0. 0 0.0 51)4. 7 .- . SUMMARY The well which comes closest to the propased ~ell is' Aoag-aoa47oo H-8 Closest appeoach distance = ~IC~ 0~ Foe this run = 49.0 feet 5000.0 feet FLOWLINE 10 3/4- closes. 10" DIVESTER 12" MAX. DRILLING RISER I 20" 2000 PSI WP ANNULAR PREVENTOR DRILLING SPOOL 20" CONDUCTOR PIPE DIVERTER SYSTEM DETAIL DRILL. DEPT. April 1982 NOTE: DIVERTER ~INE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SURFACE HOLE DIVERTER SYSTEM Two lines venting 90° apart in directions that insure safe down wind venting, and extending to a point at least 100' (feet) from any potential source of ignition. 10 3/4" manual I~Jttetfly valves 10 21/4" 55~ Buttress 10-21/t" HTdraulic Butterfly valve ~ 20" Diver ret S~] w/10 3/4" Side O~t]et. NOTES 1. Ail pipe connections 150# ANSI Flanges or welded connections and secured to prevent movement. 2. Manual 10-3/4" butterfly valves, mechanically connected to insure that one valve is fail- safe open at all times. 3. All turns are 90° (degrees) and targeted. CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc. (l' thru 8) (3) Admin (9 thru 13) 10. (10 and I3) / 12. 13. <4) Casg ~.ff~ (14 ~hru 22) (23 thru 28) Company 1. Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Lease & Well No. YES NO 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ........................................ Will surface casing protect fresh water zones ....................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ 23. 24. 25. 26. 27. 28. Is a diverter system required ....................................... Is the drilling fluid program, schematic and list of equipment adequate Are necessary diagrams and descriptions of Y3;-rtnr cr_d BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OOO~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. (6) OTHER (6) Add: For exploratory and Stratigraphic wells: 29. Are data presented on potential overpressure zones? ................. 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore 'loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. · REMARKS Geology: Engi~eerin~: rev: 04/03/86 6.011 POOL INITIAL GEO. UNIT ON/OFF CLASS STATUS AREA NO. SHORE CHECK LIST FOR NEW WELL PERMITS Company ._~¢ Lease & Well No. ITEM APPROVE DATE Loc 3- (2 thru 8) (9 thru 12) (10 and 12) (13 thru 21) (22 %Hru 26) 1. Is the permit fee attached ........................ 3. Is well located proper distance from property line . 4. Is well located proper distance from other wells .. . 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ... · 7. Is operator the only affected party .................. ' 8. Can permit be approvedbefore ten-day wait .......... [~ · · 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21; 22. 23. 24. 25. 26. 27. YES NO REMARKS A Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate Is conductor string provided ........................................ ~ Is enough cement used to circulate on conductor and surface ......... ~ Will cement tie in surface and intermediate or production strings ... /~ Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... ,~ Will all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ /~ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~'d~d) psig ../~_ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. ~F 0 ~Z ~O Gee logy: En$in~ee3r ing: WVA~ MTM~ HJH ~ SAL~~ -- rev: 03/13/85 6.011 · INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE , , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. DIRECT DIGITAL LOGGING C, OPIPUTE~R PR~OCESSED ANALYSIS GF.4/~a. RT Company STANDARD ALASKA PRODUCTION CO. Well H-21 (42-21-11-1~3) O/H Field PRUDHOE BAY DATE OF JOB: 05-12-86 Count? NORTH~ S,,L. OpE- State ALASKA Countr~ USA C.L I ENT FORMAT DATA~ TAPE L 0 G I ~N F 0 R M A .T 'I 0 N STANDARD FORMAT < L , I , S , Well No,: S~PC H-21 Depth_~: _ 9121, O O to Name.: H-2 ~ ( 42-21 - 11 ,- t 3 '? O,-,'H Field: PRUDHOE BAY DATE OF JOB: 05-12-86 Date: 2~ .... MAY Time: 1:47 PM THU, Page: t L, I, S, TAPE RECORDS REEL HEADER Service name: &~5F01 Previous reel: HEADER Origin: RECORDS Reel name: 347235 Page Continuation #: O1 TAPE HEADER Service name,: &GSF01 Previouz tape: Datm: 86/05/29 Origin: Comments: Tape name: 347235 Continuation #; 01 **** FILE HEADER File Maximum length: 1024 HEADER RECORDS Version #: File type: LO Previous ?ile: Date: Page MNEM CN WN FN COUN STAT CTRY SECT TOWN RAHG EKB EDF EGL PD LHF DNF RUN LCC SON LUN FL LUL ENGI WITN DL TLI BLI TCS TLAB BNT MRT MT MY'IS RM MFST MFSB AMC MCaT MCSS I NFORMAT I ON RECORDS CONTENTS UNIT STANDARD ALASKA PRODUCTION CO. H-2! (42-21-'11-13) O?H PRUDHOE BAY DATE OF NORTH SLOPE ALASKA USA 21 .............. 11N ............. 13E. ,- ........... 76,510 .......... 75.. 51 0 .......... 45,910 .......... KB, KB., ............. llllllIIIIllIIll 3.8 .............. 347235 ........ 76't'1 ,,,,,, NORTH .SLOPE NORTH SLOPE OLSON WALSN 9961., OiO 0 ............ 99'67. 000 ............ $905,000 ............ 9964,000 ........ 15,.000 ....... 23.,308,, ............ 185,00::0 ............. :185,0~0 ............. FRESH FLO. WL:INE 3e..iO0;O ........... .,, 2..,94'0 ..... .......... 3,32;0 ............... 64,080 ............ .. MEASURED .... .... 2,280, ......... ..... .?~,eoo .............. MEASURED ........ (ti II1 ill JOB lil Il(ill iii lllill lit (frill lll llllll Ill llllll III (lllJl III llllll lll llllll 141 Illltl Ill IIIlfl ill llllll Ill ]lllll til If(il· ll( llillI Ill Ill I]IIII lit II~ ·Il ·IllllllII lltllllIil illtllll*l · · · i I I · · I · I 1 I I · ( I l I l I I I · I I Ill·l II(l( IIll( IIIII lllll Illll lllll llfll ilJll I&tll llIll lllll · ((Ill Illllllfllll llllllllllll II(llllllll( lllllllll(ll IIl·llllltll Illlllllllll IIlIllllllll llllllllllll · Ililllllllll Illlllllllll il(lll(llllt llI$1[llllll Illlllilll$1 ~tlltl~lllll tlllllllllll llllllllllll llltlllllllll Illlllltllll(lIlli (llll=llllllilll(I IlllltllllllllllII lllItlllllllt·llll · flllllllllttlllllll Ilelllllllllllllllll }llIllllfIlllllill( TYPE CATG SIZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2 65 0 0 3 ~5 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT .0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 10 65 0 0 10 65 0 0 20 65 0 0 20 65 0 0 20 ~5 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT ;O 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 1 4 68 DEGF 0 t 4 68 0 2 20 65 0 2 20 65 CP 0 2 4 68 OHMH 0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 12 65 OHNM 0 2 4 68 DEGF :0 2 4 68 0 2 12 65 Page COMMENT RECORDS ** This LIS tape was written by Gearhart Industries Wireline Services. ** All curve and tool mnemonics used are those which most closely match *~ Gearhart curve and tool mnemonics0 GEARHART TO SCHLUMBERGER MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FEET DEPT FT TEN MERGE LBS TENS MERGE LBS SP MERGE API SP MERGE API GR MERGE GAPI GR MERGE G'API ILD MERGE OHMM ILD MERGE OHMM ILM MERGE OHMM ILM MERGE OHMM :LL3 MERGE OHMM RLL3 MERGE OHMM DT MERGE US/F DT MERGE US/F CILD COMPUTED MMHO CtLD COMPUT MMHO Page D ~ T ~ ENTRY BLOCKS eeee ENTRY Ol~lllllllllllllllllllllllllllllll ENTRY BLOCK LEGEND e~*~ TYPE DESCRIPTION 0 Terminator ( no more entries ) FORMAT SPECIFICATIONS TYPE SIZE CODE O I 66 Page DATA FORMAT SPECIFICATIONS DATUM SPECIFICATION 8LOCKS **** *************************************** MNEM SER¥[CE SERVICE APl AP1 APl APl FILE ID ORDER # UNIT LOG TYPE CLASS MOD # DEPT 347235 FT 0 0 0 0 0 TENS MERGE 347235 LBS '0 0 0 0 0 SP MERGE 347235 AP[ 0 10 1 0 0 GE MERGE 347235 GAPI 0 54 1 0 0 ILD MERGE 347235 OHMM 0 120 46 0 0 ILM MERGE 347235 OHMM 0 120 44 0 0 RLL3 MERGE 347235 OHMH ~0 220 6 0 0 DT MERGE 347235 US/F 0 8 32 0 0 CILD COMPUT 347235 MMHO 0 68 46 0 0 PRC # SIZE LVL SMPL RC 4 0 1 G8 4 0 1 68 4 0 I G8 4 0 1 68 4 0 I 68 4 0 1 68 4 0 i 68 4 0 1 68 4 0 1 68 PROCESS INDICATORS 000000 000000 000000 000000 000000 000000 000000 080000 000000 000000 000000 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 P~ge DEPT CILD TENS SP DATA 6R RECORDS ILD ILM RLL3 DT Page 999i,5:0:0 i0'00,008 989t,500 9791 ,500 96, ~61 9691.500 86,896 959t . 508 36, 9491,500 34,995 9391 ,SO0 15, t 0'! 929 t ,500 7 · 568. 919:1 , SO0 83 ,. 't 7,6 2049. 000 3357.000 3391.000 3294,000 33.03,000 3323,000 32S9, "000 3313, ~00'0 32:15, '0;00 O, 000 29,500 26,500 35,800 44,800 40,2'0.'0 26,200 64, :3:00 52,60:0 0,000 17.800 1S ,3~00 20,100 21 , 6:00 20. 19.9:00 1 75, SOO 1 ,.32, :000 1 ,000 2,624 10,399 1 1 ,508 27,733 28,576 66,222 32,129 12.023 2,979 2. 767 12.134 1 0.544 23,933 22,,439 40,832 114,025 t0.864 1 .000 4.581 18.836 15,560 23,878 27.479 45.709 304, .088 16,1 O6 0.0.00 89,700 90,500 89.700 77.100 86,800 95,900 60,500 96,9'00 FILE TRAILER Fi la name; &GSF01.001 Maximum length: '1024 TRAILER RECORDS Service name: File type: LO mm Version #: Next ~ile: Date: Page EOF *,** FILE HEADER File name-: &GSF01.0'02 Haximum length: 1024 ~ervice name~ HEADER RECORDS Version File type: LO Previous ~ile: Date: Page 10 MNEM CN WN FN COUN STAT CTRY SECT TOWN RANG EKB EDF EGL PD LMF DMF RUN LCC SON LUN FL LUL ENGI WITN DL TLI .BLI TLAB BHT MRT MT MSS MVIS RM RMF MFST MFSS AMC MCST INFORMATION CONTENTS STANDARD ALASKA PRODUCTION CO, H-21 (42-21-11-13) O?H PRUDHOE BAY DATE OF JOB: NORTH SLOPE ......... ALASKA ......... USA ......... 21,,,.,,...,,i,,.,..,,,, I,,, , 11N .......................... 13E .......................... 76,51 ~0 ....................... 75,,51 0 ....................... 45.,91~0, , ..................... ~S.., , , , . , . , , , , · , , , , , . , , , , KBi,,,lt,,,,,..I,,i..,., ,,,,, 347235 ................. . .... 761t · : NORTH SLOP ........... NORTH SLOPE ........... OLION ........... WALSH ..... ...... 9961 , 000 ..... .................. 996 ?, iO00 ....................... 89~, 000 .................... . . . 99~4,:00;0 ....................... t5,000 ................... . ...... 23.;300 ......................... 185.10:00 ........................ 185..,~, ............ ,.,, ....... FRESH ........... FLOWLilNE ........... 38.,00:0 ....... .................. 2..'94!0 .... ..................... 3 64,!000, , , ......... ............. MEASURED ................... 2,200, ......................... 70. ;O0:O ....... ........... ....... NEASURED ,,.,,. ............... 05-12-86 .... I i I I · i · I I I I I I I I 1 I & ! i' I I & I It111 Il&Il Ill& It·1 RECORDS llllllll llllllll Itllllll llllllll il·fill llmllll lllllll llI·lll lllllll lllllll lllllll Il&1111 l[lll]l lllllll lllllli llilll· ll,lill lllilll lllllll lllllll lllllll ll&llll lllllll UNIT TYPE CATG SiZE CODE 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 2~ 65 0 0 3 65 0 0 3 65 FT O' 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 0 2 79 0 0 10 65 :0 0 10 65 0 0 20 65 0 0 20 65 :0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT :0 3 4 68 FT .0 3 4 68 HR 0 2 4 68 HR :0 4 4 68 DEGF :0 t 4 ~8 DEGF 0 i 4 68 0 2 20 65 0 2 20 65 CP :0 2 4 68 OHMM :0 2 4 68 OHMM 0 2 4 68 DEGF 0 2 4 68 0 2 t2 65 OHMM ;0 2 4 68 DEGF 0 2 4. 68 0 2 12 65 Page 11 COMMENT RECORDS This LIS tape was written by Gearhart Indus&ries Wireline S~rvice~. All curve and tool mnemonics used are tho~e which most closely match Gearhar~ curve and tool mnemonics, GEARHART TO SCHLUMBERGER MNEM DEPTH TEN1, GR'I :OALt'I F,FDCI N.FDC~t RNOBI: DRHOt FCNLI NCNLt' CDL'I: NPHS'1 RAT'I SERVICE UNIT MNEM SERVICE UNIT FEET DEPT FT MERGE LBS TENS MERGE LBS MERGE GAPI GR MERGE GAPI MERGE IN CALI MERGE IN MERGE CPS FFDC MERGE CPS MERGE CPS NFDC MERGE CPS MERGE G?C3 RHOB MERGE G?C3 MERGE G/C3 DRHO MERGE G/C3 MERGE CPS FCNL MERGE CPS MERGE. CPS NCNL MERGE CPS COMPUTED PU DPHI COMPUT PU COMPUTED S:SPU NPHI COMPUT PU OOHPUTED NEAT COMPUT .... Page 12 DATA ENTRY BLOCKS ENTRY ENTRY BLOCK LEGEND ~* TYPE DESCRIPTION O Terminator ( no mope entriez ) FORMAT sPECIFICATIONS TYPE SIZE CODE -0 1 66 13 DATA FORMAT SPEC I F I CAT IONS DATUM ~PEO.IFICATION BLOCKS MNEM SERVICE SERVICE API API API API FILE ID ORDER # UNIT LOG TYPE CLASS MOD # DEPT 347235 FT 0 0 0 0 0 TENS MERGE 347235 LBS .0 0 0 0 GE MERGE 347235 GAPI 0 54 C~LI MERGE 347235 IN 0 24 2 0 FFDC MERGE 347235 CPS 0 98 2 0 NFDC MERGE 34?235 CPS :0 98 RHOB MERGE 347235 G/C3 0 94 DRHO MERGE 347235 G?C3 0 100 1 0 1 FCNL MERGE 347235 CPS 0 78 3t 0 NCNL MERGE 347235'0PS 0 ,76 30 0 DPHI COMPUT 347235 PU 0 :0 0 0 I NPHI COMPUT 347235 PU 0 122 2 0 1 NEAT COMPUT 347~35 .... 0 .0 0 0 1 PRC # SIZE LVL SMPL RC 4 0 1 68 4 0 1 69 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 PROCESS INDICATORS 000000 000000 OOO000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 '000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ,0'00000 000000 P~ge 14 DATA RECORDS DEPT TENS GR CALI FFDC FCNL NCNL DPHI NPHI NRAT 9996.000 0.000 0.000 0,000 0.000 0.~00 0,00!0 160,606 10,058 -999.250 NFDC 0,000 RHOB 0,000 Pag~ 15 DRHO 0.000 9896,000 3435,000 30. I O0 8.690 474.900 198,800 365. ! O0 14, 121 23,107 1 ,805 595,90'0 2,417 , O76 9796,000 3430,090 21.200 9.230 494,000 229,70.0 392,1~00 20,545 21,097 1,665' 570.700 2,311 -. 004 9696,000 3323,000 24,300 8,760 508. 800 ! 6'7,6 00 :335. O0 0 21,6:36 2=.5,186 i . 86 0 232.600 3284,000 26,2:00 17,333 8.890 463,600 ! .581 57{.000 574,900 2,293 2,364 -.001 ,013 9496,~000 3254,0010 22,800 9,120 503,800 '162. i00 3'10,4:00 1 9,8.18 29. '195 2.05:3 9396,~0:0 3352. OOO 21 ,0:00 9,090 549.600 '15~.,~000 314,400 19,152 26,581 1 ,978 929.6,900 3196, !0!00 1 ~03.6'00' 9,58 0 296.900 401 ,.000 542,800 4,182 1 3,917 1 ,295 9196,,,~00 3:t 57,000 ?1 . 1 O0 9,320 503. 200 186,700 ,354,50!0 20,30.3 2.3. 097 1 . 773 576,900 586,00O 499,700 579,200 2,323 2.334 2.581 2,315 ,02.3 O09 -,010 · 007 FILE TRAILER File n~m~: ~G5F01.00~ Maximum lmngth: 1024 TRAILER RECORDS Service name: File type: LO Vepzion ~#: Next ~ile: Date: P~ge 16 EOF ~** EOF G~ LIS TAPE VERIFICATION LISTING ICROI:ILMIED .VP 010.H02 VERIFICATION LISTING PAtE I :~ REEL HEADER ,~ ;ERVICE NAME :EDIT ~ATE :88/06/29 IR IGIN : '.EEL NAME :72832 ',DNTINUATION # :0! 'REVIOUS REEL : :OMMENTS :LIS TAPE, S.A.P.C. H-21, API~ 50-029-215T5 :~ TAPE HEADER ~ ;ERVICE NAME :EDIT ~ATE :88/06/29 IRIGIN :FS1A 'APE NAME : :ONTINUATION # :01 'REVIOUS TAPE : :OMMENTS :LIS TAPE, $.A.P.C. H-21, API# 50-029-215'75 FILE HEADER ~-~ :ILE NAME :EDIT .001 iERVICE NAME : ~ERSION .~ : tATE : IAXIMUM LENGTH : 1024 :ILE TYPE : 'REVIOUS FILE : :~ INFORMATION RECORDS [NEM CONTENTS iN : STANOARD ALASKA PRODUCTION CO. IN : H-21 (42-21-11-1]) :N : PRUDHOE IANG: 'OWN: lin ;ECT: 21 10UN: NORTH SLOPE ;TAT: ALASKA COMMENTS UNIT TYPE CATE SIZE CODE 000 000 030 065 000 000 020 065 000 000 012 065 000 000 004 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 .VP 010.H02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER ;OMP~NY = STANOARO ALASKA PRODUCTION COMPANY IELL = H-2! (42-2~-11-~3) :IELD = PRUDHOE BAY 'OUNTY = NORTH SLOPE BOROUGH ;TATE = ALASKA IDB NUMBER AT AKCC: 72832 ~UN ~1, DATE LOGGED: 26-JUN-B8 .DP: J. KOHRING ]ATE COMPUTED: 2g-JUN-88 ;ASINGC4T#) ;ASING(2g#) 'UBING(17#) 'YPE FLUID IATRIX SANDSTONE = 9.625# Bg147'(DRILLER) - BIT SIZE = 12.25" = 7.00# @9961'(DRILLER) - BIT SIZE = 8.5" : 5.50" @S946'(DRILLER) : PRODUCED FLUIDS 'OOL STRING(2.5" TOOL): CNC-O~ 146 ATC 508 NSR-LA 3039 ATM 374 :IELD REMARKS: .VP 010.H02 VERI~ICATION LISTING PAGE 3 TIED INTO BHCS DATED 12-~AY-86. WELL SHUT IN 21:00 25-JUN-B8. WELLHEAD ;HUT-IN PRESSURE = 1120 PSIG. THE SEVERE INCREASE IN GR CURVE JUST gELOW THE 'ERFS INOICATES ~ WATER PRODUCTION(SCALING) PROBLEM. THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS ~-~ SCHLUMBERGER LOGS INCLUDED WITH THIS FILE <EOIT.O01>: <SEE FILE EDIT.O02 FOR COLLAR LOCATOR DATA> COMPENSATED NEUTRON LOG - PASS ~1 (.PS1) FIRST TO LAST READING: 9998' TO 9095" COMPENSATED NEUTRON LOG - mASS ~2 (.PSI) FIRST TO LAST READING: 9998' TO 9097' COMPENSATED NEUTRON LOG - PASS #3 (.PS3) FIRST TO LAST READING:' 9998' 'TO 9097' COMPENSATEO NEUTRON LOG - PASS #4 (.PS4) FIRST TO LAST READING: 9998' TO 9098' .VP OlO.H02 VERIFICATION LISTING PAGE 4 NPN! - HODGES-LEHM~N AVERAGED (.HLA) FIRST TO L~ST RE,DINts: 9998' TO 9098' DATA mORMAT RECORD ~ !NTRY BLOCKS TYPE SIZE REPR CODE ENTRY 2 I 66 0 4 I 66 1 8 4 73 60 9 4 65 .lIN 16 I 66 1 0 I 66 0 )ATUM SPECIFICATION 5LOCKS INEM SERVICE SERVICE UNiT API API ~PI API FILE SIZE SPL REPR ID ORDER # LOG TYPE CLASS )EPT FT O0 000 O0 'ENS PSI LB O0 635 21 IPHI PSi PU O0 890 O0 IRAT PSi O0 420 01 INRA PS1 O0 000 ICNL PS1 CPS O0 330 :CN'L PSI CPS O0 ~30 ~0 ;R PSI GAPI O0 310 O! 'ENS PS2 LB O0 635 IPHI PS2 PU O0 890 O0 IRAT PS2 O0 ,420 01 INRA PS2 O0 000 O0 ICNL PS2 CPS O0 330 31 :CNL PSZ CPS O0 330 30 ;R PS2 GAPI O0 310 O1 'ENS PS3 LB O0 635 21 IPHI PS3 PU O0 890 O0 IRAT PS3 0:0 420 01 :NRA PS3 O0 000 O0 ICNL PS3 CPS O0 330 31 :CNL PS3 CpS O0 330 30 ;R PS3 GAPI O0 310 O1 'ENS PS4 LB O0 635 21 IPHI PS4 PU O0 890 O0 IRAT PS4 O0 420 01 PROCESS CODE (OCTAL) 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 6B 00000000000000 6B O000000000000O 68 000000000010000 68'100000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O000000OO00000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 O00000000OO000 68 00000000000000 68 OOO00000000000 .VP 010.H02 VERIFICATION LISTING PAGE 5 ~NRA PS4 O0 ICNL PS4 CPS O0 :CNL PS4 CPS O0 ;R PS4 G~PI O0 {PHI HL~ PU O0 000 330 330 310 390 )EPT 9918.5000 TENS ~NRA -999.2500 NCNL tENS -999.2500 NPH! tCNL -999. 2500 FCNL {PHI -999.2500 NRAT :CNL -999.2500 GR IRAT 4.5781 RNR~ ;R 45.1250 NPHI -999. --999. -999. -999. -999. -999. 4. -999. )EPT 9900.0000 TENS {NRA 4.8477 NCNL FENS 10.0000 NPH! dCNL 3334.0000 FCNL {PHI 27.0508 NRAT :CNL '732.5000 GR IRAT 4.8047 RNRA ;R 46.8750 NPH! 15. 3436. 2'7. 769. 4. 45. 4. 27. )EPT 9800.0000 TENS {NRA 3-9531 NCNL tENS 10.0000 NPHI dCNL 3234.0000 FCNL 4PHI 23.5352 NRAT :CNL 783.0000 GR ~RAT 4.3242 RN~A ;R 37.2187 NPHI 10. 3156. 22. 832. 4. 42. 3. 23. )EPT 9700.0000 TENS {NRA 4.9961 NCNL rENS 10.0000 NPHI ~CNL 2986. 0000 FCNL 4PHI 28- 5I 56 NR~T :CNL 529.0000 GR ~RAT 5.3789 RNRA ;R 571.5000 NPHI 2892. 30. 628. 4. 812. 4. 31. ]EPT 9600.0000 TENS ~NRA 3.7598 NCNL FENS 10.0000 NPHI ~CNL 4'680.0000 FCNL ~PHI 22.4609 NRAT :CNL 1250.0000 GR ~RAT 4.10:9,4 RNRA ~R 1144.0000 NPHI 10. 4464. 21~ 125 '7. 4. 1128. 3. 22. O0 31 3O O1 O0 2500 2500 2500 2500 2500 2500 2031 2500 0000 0000 7832 5000 7852 2187 5078 6367 0000 0000 9980 5000 3281 2813 9590 5352 0000 0000 7129 500:0 9609 0000 7852 0059 0000 0000 6309 0000 1875 0000 7813 2656 NPHI FCNL NRAT GR RNRA TENS NCNL NPHI FCNL NRAT GR RNRA TENS NCNL NPHI FCNL NRAT GR RNRA 'TENS NCNL NPHI FCNL NRAT RNRA TENS NCNL NPHI FCNL NR~T GR RNRA 'TENS NCNL -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 10.0000 325¢.0000 29.8340 708.5000 4.8711 40.3750 4.2266 10.0000 3232.0000 25.0000 798.0000 4.2578 39.3438 4.1680 10.0000 3100.0000 32.0801 578.5000 5.2305 714.5000 4.6484 10.0000 2974.0000 23.0469 1187.0000 4.0703 1115.0000 3.7852 10.0000 4664.0000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 I 68 00000000000000 NRAT 5.1250 GR 41.6875 RNR~ 4.3320 TENS 15.0000 NCNL 3096.0000 NPHI 27.2461 FCNL 716.5000 NRAT 4.5195 GR 36.4375 RNRA 3.8828 TENS 10.0'000 NCNL 3265.0000 NPHI 23.5352 FCNL 783.0000 NR.AT 5.3945 GR 646.0000 RNRA 4.7500 TENS I0.0000 NCNL 2924.0000 NPHI 31.98Z4 FCNL 621o0000 NRAT 4.2656 GR 1107.0000 RNRA 3.7227 TENS 15.0000 NCNL 4732.0000 NPHI 21.~750 FCNL 1,233.0000 NRAT -999.2500 GR -999.2500 RNRA -999.2500 TENS -999.2500 NCNL -999.2500 NPHI 25.4395 FCNL 774.0000 .VP 010.H02 VERIFICATION LISTING PAGE 6 )EPT 9500.0000 TENS 15. ~NRA 4. 8320 NCNL 4030. 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