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186-182
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 L3-24 Install new tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-182 50-029-21670-00-00 12139 Conductor Surface Intermediate Liner Liner 9442 80 4341 11379 941 104 11416 20" 13-3/8" 9-5/8" 7" 2-7/8" 8823 40 - 120 39 - 4360 37 - 11416 11186 - 12139 11107 - 11211 40 - 120 39 - 3981 37 - 8822 8643 - 9440 8569 - 8654 none 470 2670 4760 7020 11160 none 1490 4930 6870 8160 10570 11275 - 11798 4-1/2" 12.6# 13CR-85 35 - 11211 8706 - 6811 Structural 4-1/2" Bluepack Max RH, 10981 , 8467 No SSSV 10981 , 11125 8467 , 8584 Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY / LISBURNE 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 0028323 , 0028322 35 - 8654 0 344 0 10619 0 4661 0 1266 0 779 323-067 13b. Pools active after work:LISBURNE OIL 2-7/8" BROWN HB , 11125 , 8584 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sr Pet Eng: Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations By Grace Christianson at 11:39 am, Aug 29, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.08.28 16:34:18 -08'00' WCB 4-9-2024 RBDMS JSB 083123 DSR-8/29/23 ACTIVITYDATE SUMMARY 5/23/2023 ***WELL S/I UPON ARRIVAL*** (rwo expense) R/U HES 759 SLICKLINE UNIT ***CONT WSR ON 5/24/23*** 5/24/2023 ***CONT WSR FROM 5/23/23*** (rwo expense) SET 2 7/8" KEYLESS X-CATCHER AS JUNK CATCHER ON CA-2 PLUG @ 11,188' SLM (2.29" max od, 43" oal) ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** 5/24/2023 *** WELL SI ON ARRIVAL *** INITIAL T/I/O = 200/0/0 OBJECTIVE: CUT TUBING W/ BAKER CUTTING TOOL AT 11080 FT. CORRELATED TO TUBING TALLY 3-21-87. CUT TIME WAS 4.5 HOURS, BAKER REPORTS SUCCESSFUL CUT. READY FOR NEXT STEP. FINAL T/I/O = 100/0/0 *** WELL SI ON DEPARTURE, DSO NOTIFIED *** 6/23/2023 T/I/O = 128/36/0. ***Circ Out*** Pumped 5bbls 60/40, 104bbls surfactant water, 885bbls 1%KCl, down tubing, up IA, to L3-22's flowline. Pumped 178bbls diesel down IA for U-tube freeze protect. Pressured TxIA to 1500 psi for 5 min, lost 16/15 psi. bleed back to starting pressures. final WHP's 674/670/11 Pad op notified on departure. 6/25/2023 T/I/O = VAC/VAC/0+. Temp = SI. Bleed WHPs (pre RWO). No AL. Flowline dissconnected, wellhouse removed, rig scaffolding installed. Bled OAP to bucket from 3 psi to 0 psi in 1 min. Bled balance line to bucket from 20 psi to 0 psi in 1 min. Bled control line from to BT 860 psi to 0 psi in 2 mins. Monitored for 30 mins, no change in pressure. Final WHPs = VAC/VAC/0. SV, WV, SSV = C. MV = O. IA, OA = OTG. 09:50 6/26/2023 Check tubing for pressure (0), set 2-1/2" CIW H TWC, bleed control & balance lines @ THA, hardly any psi. or volume, bleed tubing hanger void, hardly any psi. or volume, nipple down THA, plug (2) ¼" NPT gallery type control line ports in hanger neck, function upper lock down screws one at a time, 3-5/8" clear bowl, all functioned properly, all LDS OD were gooey/sticky. Clean/wire brush & Kroil LDS ODs, re-torque to 500 ft./lbs., make up 2-7/8" EUE lift sub to hanger lift threads 8 RH, back out & lay down sub, clean top flange ring groove, install new R-54, help well support crew make up 11" x 13-5/8" DSA, RDMO. 6/27/2023 T/I/O=0/0/0> Pre TB #01. Set 2 9/16' CIW "H" TWC. N/D production tree, N/U 13" BOP's w/ 13" x 11" DSA. Torqued both flanges to specs. PT'd.with lift gas to 500 psi. Passed. FWP's TWC/0/0 7/8/2023 Finish torquing up BOP body. PT BOP's with gas from L3-22 1400 psi (PASSED). 7/20/2023 MIRU TB-1, Send AOGCC BOP test notification, witness wavied by G. Cook on 7/20/2023 @ 15:20. 7/21/2023 T-Bird 1 RWO. Job Scope: Tbg swap. IC pack-off and Tbg Head change. Continue MIRU. Service choke and kill manifold. Shell Test BOPE. Conduct initial BOP test to 250/3000 psi. Witness waived by Guy Cook 7/20/23 15:20 hrs. One failure. CMV#3. Replace and retest. Pull TWC. Attempt to rock out diesel. TRSV is closed. RU slickline and run hold open sleeve Daily Report of Well Operations PBU L3-24 OBJECTIVE: CUT TUBING W / BAKER CUTTING TOOL AT 11080 FT. CORRELATED TO TUBING TALLY 3-21-87. CUT TIME WAS Daily Report of Well Operations PBU L3-24 7/21/2023 ***HES 759 THUNDERBIRD RIG ASSIST*** (rig assist) SET 2.31" C-LOCK, HOLD OPEN SLEEVE (97" oal, 2.34" max od, 1.12" id) IN TRSSSV @ 2,192' MD ***THUNDERBIRD IN CONTROL OF WELL UPON DEPARTURE*** 7/22/2023 Pull tubing hanger & three joints of tubing, rig set storm packer, nipple down BOP & tubing head, remove IC packoff, file & grind damage to casing head ID, set new packoff, run in lock down screws, torque to 500 ft/lbs, tighten glandnuts, nipple up new tubing head, inject IC packoff w/ J stick 40000 psi, test packoff 500 psi/5 min, 0 psi loss, test 3500 psi 30 min, lost 100 psi first 15 min., lost 0 psi second 15 min., good tests, bleed off test psi, set test plug in tubing head, stand by for BOP shell test, pull test plug, RDMO 7/22/2023 T-Bird 1 RWO. Job Scope: Tbg swap. IC pack-off and Tbg Head change. Continue circulating bottoms up, MU landing jt, BOLDS and unseat hanger @ 65K, PU to 85K and breakover to hanging weight @ 65K. LD hanger, Swap out elevators and LD 3 jts 2-7/8". Set YJ storm packer @ 18'. Test to 500 psi.. Clear and raise rig floor. ND and remove BOP and THA. Wellhead Tech removed IC pack-off. Dress sealing area of bowl (damaged/scarred). NU BOP and replacement THA w/ test plug installed. Lower floor and set windwalls. Test void to 3000 psi mins. Test breaks 3000 psi 5 mins charted. Pull test plug, spot wrangler, Pull & LD stormpacker. TOH w/ 2-7/8" completionwhile spooling control and chemical injection lines 7/23/2023 ***WELL S/I ON ARRIVAL (assisting Thunderbird rig)*** RAN JUNK BASKET W/ 8.50" GAUGE RING, SD ON LOWER HALF OF PBR @11,133' SLM (recovered about 1/4 cup of metal shavings) RAN KJ, 3' x 1-3/4", 2.25" CENT, 1-3/4" SAMPLE BLR W/ MSBB, SD IN JUNK CATCHER @11,229' SLM (blr empty, no issues entering remaining PBR) ***WELL S/I ON DEPARTURE*** 7/23/2023 T-Bird 1 RWO. Job Scope: Tbg swap. IC pack-off and Tbg Head change. Continue TOH w/ 2-7/8" while spooling conrtol and chemical lines. OOH w/ full cut joint, 8' pup below cut joint and seal extension that pulled from PBR. Slickline drift to PBR @ 11,133' SLM. Drifted thru sccop on PBR to ensure clear passage. Tag Tbg plug @ 11,229' SLM. RD slickline. Start running 4-1/2 13cr VamTop completion. 7/24/2023 RWO, T/I/O = BPV/0/0, Completion PU 13-1/2" McEvoy SSH tubing hanger with 4-1/2" TDS pin x VT pin to string of 4- 1/2" VT tubing, open IA and drain stack, RIH with hanger and land at 14.40' RKB to LDS, verify landed through IA, RILDS to tag evenly at 5-7/8" IN, LDS all visible on top of hanger from rig floor, torque GNs to 500 ft/lbs, torque LDS in alternating criss cross to 500 ft/lbs, standby for rig to spot corrosion inhibitor and set packer. 7/24/2023 ***ASSIST THUNDERBIRD RIG*** DRIFT W/ 3.50" G. RING TO 11,000' SLM PULLED BALL & ROD FROM 11,015' MD PULLED 4-1/2" RHC PLUG AT 11,015' MD ***CONTINUE ON 7/25/23 WSR*** Daily Report of Well Operations PBU L3-24 7/24/2023 T-Bird 1 RWO: Job Scope - Tubing swap, IC packoff and tubing head change Continue PU and TIH w/ new 4-1/2" gas lift tubing completion. Up/Dn Wts 118/84K. PU extra Jt and slack-off to 5' below final WLEG depth to 11077'. lD Jt Mu and land hanger and completion @ 11,072'. RILDS. Pump 220 bbls 1% EPT-3744 corrosion inhibitor and displace w/ 372 bbls 1% KCL. Corr Inhib spotted from 6935' to packer plus 4 bbls excess. Drop ball and rod. Attempt to set packer, unable to catch pressure, MIRU slickline and retrieve Ball & Rod. 7/25/2023 ***CONTINUED FROM 7/24/23 WSR*** (RWO expense) SET 4-1/2" PX PLUG AT 11,015' MD T-BIRD ATTEMPTED PT (unable to catch pressure) LEAK DETECT W/ 4.5'' D&D HOLEFINDER (confirm sov intact and leak around hanger) PULLED 4.5'' PX PLUG @ 11,015' MD SET 3.81'' RHC @ 11,015' MD ***WELL HANDED OVER TO THUNDERBIRD RIG*** 7/25/2023 RWO, T/I/O = BPV/0/0, Completion Troubleshoot leak in completion, drain stack through IA, fluid level in stack dropped below hanger neck indicating tubing hanger leak, standby for slickline, make up 4- 1/2" TDS landing joint 11-1/2 turns, mark RKB, verify 0 psi on IA, loosen gland nuts, BOLDS to 6-3/4", pull tubing hanger to rig floor, CCL ports in tubing hanger are not plugged, install 1/4" NPT plugs x2 in top of hanger and 1/2" NPT plugs x2 in bottom hanger, replace tubing hanger body seal, open IA valve, reland tubing hanger at 14.40' RKB to LDS, verify through IA, close IA valve, RILDS to tag, torque gland nuts to 500 ft/lbs, torque LDS to 500 ft/lbs, LDS IN at 5-3/4", all LDS visible on top of hanger from rig floor, fill stack, close annular and PT to 500 psi through kill line for 5 minutes with no loss, bleed off psi, open annular, BO LJ, standby for rig to pump corrosion inhibitor and set packer, set 4" H TWCV 7/25/2023 T Bird 1 RWO: Job Scope - Tubings swap, IC packoff and tubing head swap RIH & retrieve RHC body, PU & RIH w/ PX plug, set on X nipple @ 11,015', attempt to set packer, take returns from IA. RU DND hole finder & Dutch Riser to troubleshoot Tbg x IA communication. Gradually increase pump rate to 4 bpm while slickline RIH to upper GLM w/ shear valve. No change in weight. Set D&D hole finder below upper GLM, above upper GLM, above upper X nipple and @150'. Immediate returns from IA on each test. Leak is above 150'. Drain stack by draining fluid from IA valve. Note fluid level drop behind hanger neck indicating leak is theTbg Hanger. Slickline pulled PX plug and ran RHC. Pulled hanger @ 118K. Control line ports not plugged. Install plugs and replace seal. Land hanger, RILDS, and test hanger from the top to 500 psi. Pump 220 bbls 1% EPT 3744 Corr. Inhibitor 6 bpm @ 800 psi. Displace w/ 372 bbls 1% KCL to spot C.I from 6935' to below packer. Drop ball & rod, set packer @ 3,000 psi, MIT-T to 3,500 psi- pass, MIT-IA 3,000 psi - pass, shear OV, Set TWC, RDMO ***Job Complete*** 7/26/2023 Assist WWS N/D BOP. Remove TBG HGR neck protector, clean void. Inspect lift threads and neck. Install DX seal N/U THA. fill w/ test oil. R/U test equipment, test void to 500/5000 5/30 min. passed. bleed off pressure. @ SET 3.81'' RHC @ 11,015' MD RIH & retrieve RHC body, PU & RIH w/ PX plug, set on X nipple @ 11,015', attempty to set packer, take returns from IA. Drop ball and rod. Attempt to set packer, unable to catch pressure, MIRU slickline and retrieve Ball & Rod @ Drop ball & rod, set packer @ 3,000@ psi, MIT-T to 3,500 psi- pass, MIT-IA 3,000 psi - pass, shear OV, Set TW C, RDMO Troubleshoot leak in completion Continue PU and TIH w/ new 4-1/2" gas lift tubing completion. Up/Dn Wts 118/84K.gg PU extra Jt and slack-off to 5' below final WLEG depth to 11077'. lD Jt Mu and land hanger and completion @ 11,072'. RILDS. Daily Report of Well Operations PBU L3-24 7/26/2023 RWO, T/I/O = BPV/0/0, Completion, PPPOT-T (PASS) Work with WS to ND BOPs, remove protector and clean hanger neck, DX seal area, test void, ring gasket groove. Install new DX seal in hanger neck, fill test void with hydraulic oil, install new BX-160, NU 13-5/8" x 4" THA, pressure test to 500 psi low, pass, test to 5000 psi high for 30 mins, lost 100 psi first 15 mins, lost 0 psi second 15 minutes (PASS). WS tested tree. 7/27/2023 T/I/O=TWC/0/0. Post TB #01. Evacuated fluids from BOP, Removed 13" CIW BOP and Install 13" CIW THA and 4" CIW Tree w/ Baker C. Wellhead tech perform PPPOT-T. Passed. PT'd tree through tree cap against TWC, 500/low..5000/high.. Pass. Pulled 4" CIW "H" TWC #427 through tree. Connect production and AL piping and set wellhouse FWP's 0/0/0. job complete. 7/27/2023 ***WELL S/I ON ARRIVAL***(post rig) PULLED BALL & ROD @11,003'SLM PULLED ST#4 BK-SHEAR VLV @4,073'MD PULLED ST#3 BK-DMY VALVE @7,163'MD SET ST#4 BK- LGLV @4,073'MD ***CONTINUE ON 7/28/23*** 7/28/2023 ***CONTINUE ON FROM 7/27/23*** PULLED 4-1/2" RHC BODY FROM 11,006'SLM BAILED FROM 11,167'SLM TO 11,170'SLM RETRIEVED 1 CUP OF SLUDGE, PULLED 2-7/8" CATCHER FROM 11,170 TROUBLE ENTERING FEMALE SECTION OF PBR(scoop) RAN 5'x2.0'' P-BAILER(salmonMFB), WORK THROUGH PBR, S/D @ 11174'SLM (1 cup of plastic and thick fluid) RAN 2-1/2" RB TROUBLE ENTERING SBR & LATCHING (sheared RB) ***CONTINUE ON 7/29/23*** 7/29/2023 ***CONTINUE FROM 7/28/23*** PULLED PRONG FROM 2-7/8" CA-2 PLUG @ 11198'MD PULLED 2-7/8'' CA-2 PLUG FROM D-NIP @ 11198'MD ***WELL LEFT S/I ON DEPARTURE*** 8/1/2023 SVS Passed State Test 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU L3-24 Install new tubing Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 186-182 50-029-21670-00-00 ADL 0028323 , 0028322 12141 Conductor Surface Intermediate Production Liner 9442 80 4341 11379 941 11198 20" 13-3/8" 9-5/8" 7" 8643 40 - 120 39 - 4360 37 - 11416 11198 - 12139 2420 40 - 120 39 - 3981 37 - 8822 8643 - 9440 none 470 2670 4760 7020 11198 1490 4930 6870 8160 11275 - 11799 2-7/8" 6.5# L-80 35 - 112118706 - 6811 Structural 2-7/8" BROWN HB 2-7/8" Camco TRDP-1A 11125 / 8584 2192 / 2191 Date: Bo York Operations Manager David Bjork David.Bjork@hilcorp.com 907.564.4672 PRUDHOE BAY 5-1-2023 Current Pools: PRUDHOE OIL , LISBURNE OIL Proposed Pools: PRUDHOE OIL , LISBURNE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov By Meredith Guhl at 9:14 am, Feb 02, 2023 323-067 Digitally signed by Bo York (1248) DN: cn=Bo York (1248), ou=Users Date: 2023.02.01 16:05:13 -09'00' BOPE test to 3000 psi. Annular to 2500 psi. DSR-2/2/23 10-404 MGR07FEB23 2420 SFD 2/6/2023GCW 02/09/23JLC 2/9/2023 2/9/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.09 14:45:23 -09'00' RBDMS JSB 021423 RWO L3-24 PTD:1861820 Well Name:L3-24 API Number:50-029-21670-00 Current Status:Shut-In – Non-Operable Rig:Thunderbird Estimated Start Date:5/2023 Estimated Duration:5days Reg.Approval Req’std?10-403, 404 Date Reg. Approval Rec’vd:TBD Regulatory Contact:Carrie Janowski Permit to Drill Number:1861820 First Call Engineer:David Bjork Contact:907-440-0331 Current Bottom Hole Pressure:3,300 psi @ 8,900’ TVD 7.22 PPGE | offset well recent SBHP Max. Anticipated Surface Pressure:2,420 psi (Based on 0.1 psi/ft. gas gradient) Last SI WHP:2000 psi (SL RU on 10/15/22 after 5 day SI) Min ID:2.312” @ 2192’ MD 2-7/8” CAMCO TRDP-1A Max Angle:52 Deg @ 5,700’ MD Brief Well Summary: L3-24 is a Lisburne/Ivishak commingled well that produces all the oil from the Ivishak formation. The well recently failed integrity testing indicating L3-24 has TxIA communication. A LDL confirmed there are tubing leaks at collars at 10580’ MD, 10490’ MD, 10360’ MD, and 10100’ MD. The well passed a CMIT-TxIA to 2,905-psi on 10/18/22 proving the well has competent casing. Objective: Pull the existing 2-7/8” tubing. Run new 13-Cr 2-7/8” completion to repair tubing leaks. Achieve a passing MIT- IA & MIT-T. Pre RWO work: Wellhead: 1. PPPOT-T to 5000 psi. Function all LDS. PPPOT-IC to 3500 psi. Function all LDS. E-line/Fullbore: 1. Cut tubing ~11,080’ MD. 2. Circulate well with 8.4 ppg KCL + freeze protect DHD: 1. Bleed WHP to 0 psi Valve Shop: 2. Set and test TWC 3. Nipple down tree and tubing head adaptor. Inspect threads. 4. NU BOPE configuration top down: Annular, 2-7/8”x5” VBRs, blinds and integral flow cross Proposed RWO Procedure: 1. MIRU Thunderbird #1 Rig. 2. 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. that produces all the oil from the Ivishak formation. Lisburne/Ivishak commingled well t RWO L3-24 PTD:1861820 C. Confirm test pressures per the Sundry Conditions of approval. D. Test the 2-7/8”x5” VBRs with 2-7/8” test joint E. Test the annular with 2-7/8” test joint. F. Submit to AOGCC completed 10-424 form within 5 days of BOPE test. 3. RU and pull TWC (RU lubricator is pressure is expected). 4. MU landing joint or spear, BOLDS and pull hanger to the floor. PU weights are expected to be ~63K. 5. Pull 2-7/8” tubing to floor, circulate bottoms up. POOH LD tubing string. 6. Run 2-7/8” 13Cr tubing with stacker packer completion as detailed on proposed schematic. 7. Land Hanger and reverse in corrosion inhibited 8.4 ppg KCL with freeze protect. 8. Drop ball and rod and set packer. 9. Perform MIT-T to 3,000 psi and MIT-IA to 3,000 psi for 30 charted minutes. 10. Set TWC 11. 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 Post rig Slickline Work 1. Set LGLVs 2. Pull Ball and rod and RHC profile 3. Pull plug from 11198’ MD. 4. RDMO & POP well RWO L3-24 PTD:1861820 Attachments: 1. Wellbore Schematic 2. Proposed Wellbore Schematic 3. BOP Drawing 4. Sundry Revision Change Form RWO L3-24 PTD:1861820 Wellbore Schematic RWO L3-24 PTD:1861820 Proposed Wellbore Schematic RWO L3-24 PTD:1861820 RWO BOPs RWO L3-24 PTD:1861820 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 HAK Prepared By (Initials) HAK Approve d By (Initials) AOGCC Written Approval Received (Person and Date) Approval: Operations Manager Date Prepared: Operations Engineer Date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aFXSVRI*UHHQVWLFNSDFNLQJLQWR,&YRLG:RXOGQRWKROGSUHVVXUH 1$ 67$7(2)$/$6.$ $/$6.$2,/$1'*$6&216(59$7,21&200,66,21 5(32572)681'5<:(//23(5$7,216 6U3HW(QJ 6U3HW*HR )RUP5HYLVHG6XEPLW:LWKLQGD\VRU2SHUDWLRQV 6U5HV(QJ By Anne Prysunka at 1:21 pm, Sep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perator Name:2. Development Exploratory Service 5 Permit to Drill Number:186-182 6.50-029-21670-00-00 PRUDHOE BAY, PRUDHOE OIL/PRUDHOE BAY, LISBURNE 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 12141 11406 8814 11125 none none 8584 Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 40 - 120 40 - 120 1490 470 Surface 4341 13-3/8" 39 - 4360 Intermediate 11379 9-5/8" 37 - 11416 37 - 8822 6870 4760 Production Perforation Depth: Measured depth: 11275 - 11799 feet True vertical depth:8706 - 6811 feet Tubing (size, grade, measured and true vertical depth)2-7/8" 6.5# L-80 35 - 11211 35 - 8654 11125 8584Packers and SSSV (type, measured and true vertical depth) 2-7/8" BOT HB Packer Liner 941 7" 11198 - 12139 8643 - 9440 8160 7020 12. Stimulation or cement squeeze summary: Intervals treated (measured): Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 572233718810 22841 710 1055 0 534 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: Kirsty Schultz Kirsten.Schultz@hilcorp.com Authorized Name:Bo York Authorized Title: Authorized Signature with Date:Contact Phone:(907) 350-4310 Treatment descriptions including volumes used and final pressure: 13. Operations Manager Operations Performed1. Abandon Plug Perforations Fracture Stimulate Pull Tubing GSTOR WINJ WAG GINJ SUSP SPLUG 16. Well Status after work:Oil 5 Gas Exploratory Development 5 Stratigraphic 15. Well Class after work: Service WDSPL 14. Attachments: (required per 20 AAC 25.070.25.071, & 25.283) Daily Report of Well Operations Copies of Logs and Surveys Run true vertical measured9442 Sundry Number or N/A if C.O. Exempt: 319-072 2-7/8" Camco TRDP-1A SSV 2192 2191 Junk Packer Printed and Electronic Fracture Stimulation Data 5 Commingle Operations shutdown Change Approved Program 5 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 5Perforate New Pool Repair Well Re-enter Susp Well 3.Address: 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 7.Property Designation (Lease Number):ADL 028323, 028322 LISB L3-24 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 By Samantha Carlisle at 8:20 am, May 19, 2021 Digitally signed by Bo York DN: cn=Bo York, c=US, o=HIlcorp Alaska LLC, ou=Alaska North Slope, email=byork@hilcorp.com Date: 2021.05.19 06:53:23 -08'00' Bo York RBDMS HEW 5/20/2021 SFD 5/21/2021DSR-5/19/21MGR26JUL2021 ACTIVITYDATE SUMMARY 2/26/2019 T/I/O=570/25/15 SI Load IA pre CTU (PROFILE MODIFICATION) Pumped 5 bbls 60/40 followed by 123 bbls crude down IA to load pre CTU. See log for details WSL/DSO notified Tag hung on IA/AFE sign hung on MV ***FLUID PACKED ANNULUS*** Valve positions=SV WV SSV closed MV open CVs OTG FWHP=640/vac/25 3/1/2019 CTU #9 - 1.75" Coil Job Objective: Sand Plug MIRU CTU. Make up drift BHA with 2.0" JSN. ...Continued on WSR 3-2-19... 3/2/2019 CTU #9 -1.75" Coil ***Cont. from WSR 3-1-19*** Job Objectve: Sand Plug RIH w/2.0" JSN for drift. Tag TD at 12069' CTMD. Paint white/red TD flag at 11069' POOH, RIH w/ HES 24 arm caliper. Stop at flag and log up @ 50 fpm into tubing tail and catch first GLM above PKR. POOH and confirm good data, +8' correction. Make up Sand Dump BHA with 1.75" BDJSN and RIH. Load well with KCL and then diesel to underbalance. Tie in at flag and tag PBTD at 12084' . Pump 25 bbls of 8 ppa sand slurry and lay in from PBTD ...Continued on WSR 3-3-19... 3/3/2019 CTU #9 - 1.75" Coil ***Cont. from WSR 3-2-19*** Job Objective: Sand Plug Lay in 1st sand stage and confirm settled sand top of 11804'. Swap wellbore fluids due to excessive coil weight/drag. Lay in 2nd sand stage and confirm settled sand top of 11470'. Lay in 3rd stage, pooh to inspect lubricator while sand settles, Paint yellow tie-in flag. Replace O-ring and make up same Sand Dump BHA with 1.75" BDJSN. RIH and tie-in at flag. Tag sand top deeper at 11478'. Bridge must have broken down and sand fallen deeper. Prepare for stage #4. ...Continued on WSR 3-4-19... 3/4/2019 CTU #9 - 1.75" Coil ***Cont. from WSR 3-3-19*** Job Objective: Sand Plug Lay in sand stage #4. Consistent tag at 11365'. Reverse out to a sand top of 11406' MD. POOH. Well Secured and DSO notified. RDMO. ***Job Complete*** 3/4/2019 (LRS Unit 72 Assist Coiled Tubing: Coil Lost Pump) Arrive on location, Standby. Released from job without pumping 3/7/2019 ***WELL S/I ON ARRIVAL*** (Profile Modification) HES RELAY UNIT#46. DRIFT W/ 2.0" CENT, TEL, 1-3/4" SAMPLE BAILER. LOCATE WLEG AT 11,182' SLM / 11,211' MD (+29' correction). TAG TOP OF SAND AT 11,437' MD. ***JOB CONTINUED ON 08-MAR-2019*** 3/8/2019 ***JOB CONTINUED FROM 07-MAR-2019*** (Profile Modification) HES RELAY UNIT# 46 RAN PDS 24 ARM CALIPER FROM 11,229' MD TO SURFACE (good data). ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** 3/14/2019 T/I/O=0/VAC/0. IA companion install. Installed new 2 1/6" CIW Companion IA, tag #2 and PT'd 300 psi low and 3500 psi high.(PASSED). Pull 2" McEvoy VR plug PT'd IA blind flange to 2500 psi.(PASSED). ***JOB CMPLETE***. See log for details. Final WHP's 0/0/0. Daily Report of Well Operations PBU L3-24 Daily Report of Well Operations PBU L3-24 4/26/2019 ***WELL S/I ON ARRIVAL*** (Profile Modification) HES ELINE UNIT #4863 BEGIN S/B FOR SNOW REMOVAL. ***JOB CONTINUED ON 27-APR-2019*** 4/27/2019 ***JOB CONTINUED FROM 26-APR-2019*** (Profile Modification) HES ELINE UNIT# 4863 TAG TOP OF SAND AT 11,427' ELM W/ 2" X 40' DUMP BAILER. DUMP 4.5 GALLONS OF 17 PPG CLASS "H" CEMENT. ***JOB CONTINUED ON 28-APR-2019*** 4/28/2019 ***JOB CONTINUED FROM 27-APR-2019*** (Profile Modification) HES ELINE UNIT #4863 RUN 2: DUMP 4.5 GAL OF 17 PPG CEMENT (TOC ~ 11,421`) RUN 3: DUMP 4.5 GAL OF 17 PPG CEMENT (TOC ~ 11,418') RUN 4: DUMP 4.5 GAL OF 17 PPG CEMENT (TOC ~ 11415.5') ALL LOGS CORRELATED TO COIL JEWELRY LOG DATED 02-MAR-2019. ***WELL LEFT S/I ON DEPARTURE*** 4/29/2019 T/I/O = VAC/0/0 Temp=S/I Performed LTT On MV Passed. Job Completed. MV Opend, SSV, SV, WV= are Closed 5/2/2019 T/I/O = 0/0/0. Temp = SI. MIT-T FAILED to 1500 psi. (Profile Mod). No AL. TBG FL @ 880' (5 bbls). IA FL @ 880' (58 bbls). Pumped a total of 8.75 bbls of diesel into tubing on 4 attempts to pressure TBG up to 1500 psi. Each test lost an average of 750 psi in the 1st 15 minutes. Bled TP down to 3 psi, bled back 1 bbl of fluid. Hung tags. Final WHPs 3/3/3. SV, SSV = C. WV = LOTO and blinded. MV = O. IA, OA = OTG. 16:30 1/4/2020 T/I/O= 0/0/0 C/O WV COMP. R/D Old 2 9/16 HWO Comp WV. Installed tapped blind. Torqued Blind x FC to API Spec. 286 ft lbs. PT'd Upper most tree against SSV gate, Low 300psi, High 5000psi.(Passed). RDMO ***JOb Complete*** FWHP=0/0/0 2/17/2020 T/I/O = 0+/10/0+. Temp = SI. WHPs (LTSI). No AL. WV LOTO and blinded. SV, WV, SSV = C. MV = O. IA, OA = OTG. 01:00 5/16/2020 T/I/O = SSV/10/0+. Temp = SI. T & IA FL (proactive barrier testing). No AL. WV blinded. T FL @ 720' (5 bbls). IA FL @ 990' (66 bbls). SV, WV, SSV = C. MV = O. IA, OA = OTG. 04:30 8/23/2020 T/I/O = 7/12/4. Temp = SI. Increase TP (eval TxIA). No AL. IA FL @ 970'. LRS increased TP using 6 bbls of diesel with no communication in the IA. Monitored for hr. During monitor TP decreased 440 psi, IAP & IA FL unchanged. Closed downhole valve. Final WHPs = 1020/12/4. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:45 8/23/2020 T/I/O= 7/12/4. LRS Unit 72 Assist DHD. Pumped 6 bbls of 60/40 Meoh into the TBG to open SSSV. Final T/I/O= 1500/12/4. 3/7/2021 T/I/O = 152/11/-7. Assist DSO with bring well on line. Job cancelled by DSO. Final T/I/O = 152/8/-7 4/1/2021 ***WELL S/I ON ARRIVAL*** (HES E-Line Perforating) PERFORATE 11,275' - 11,296' w/ 2-1/8", 5.8 SPF, PENTA PHASE GUN (deep start strip gun w/ millenium charges). LOG CORRELATED TO ATLAS CBL DATED 24-DEC-86. ***JOB CONTINUED ON 04/02/21*** 4/2/2021 ***JOB CONTINUED FROM 01-APR-2021*** (HES E-Line Perforating) ATTEMPT TO PERFORATE 11254' - 11275' TWO TIMES (see log for details). **PLAN TO POP TO EVAL FOR ADDITIONAL ADDPERFS** 4/29/2021 Well has been tested and reviewed. WTR. SO = 74% WC Meter =75% WC, test = 81%, THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Mark Sauve GPMA/Lisbume Lead PE BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Alaska Oil and Gas Conservation Commission Re: Prudhoe Bay Field, Lisburne and Prudhoe Oil Pools, PBU L3-24 Permit to Drill Number: 186-182 Sundry Number: 319-072 Dear Mr. Sauve: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 ww W. o ogc c.a laska.g ov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this z�day of February, 2019. RBDMS Ik AF 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 71E r- 1. Type of Request. Abandon ❑ Plug Perforations 0 • Frecture Stimulate ❑ Repair Well ❑ Operations shIlown ❑ Suspend Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool 0 ' Re-enter Susp Well ❑ Alter Casing ❑ Other: Change Pool to Pmdhoe Oil 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ®. 5. Permit to Drill Number: 186-162 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic 13 Service ❑ 6. API Number: 50-029-21670-00-00 7. If perforating: CO. 471.1/A B. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU L3.24 9. Property Designation (Lease Number): 10. Fieltl/P1ools: / �rtlj/"C� ADL 026323 6 ADL 028322 • PRUDHOE BAY, LISBURNE OIL'- 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD01): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD). Junk (MD). 12141 9442 12094 9401 None None Casing Length Size MD TVD Buret Collapse Stmcturel Conductor 80 20" 40-120 40-120 1490 470 Surface 4341 13-3/8" 39-4380 39-4380 3450/4930 1950/2670 Intermediate 11379 9-5/8" 37-11416 37-8822 1 6870 4760 Production Liner 941 7" 11198 - 12139 8643-9440 1 8160 1 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 1 11538 - 11798 8924 - 9144 2-7/8" 6.5# L-80 35-11211 Packets and SSSV Type: 2-7/8• BOT HB Packer Packers and SSSV MD (ft) and TVD (ft): 11125, 8584 2-7/8" Carew TRDPAA SSV 2192, 2191 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations. 2/21/2019 15. Well Status after proposed work: Oil 0 WNJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval /,1%,� Date GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Re resentati P GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true A the procedure approved herein will not Contact Name: Sauve, Mark A be deviated from without prior written approval - Contact Email: Mark.Sauvealop.com Authorized Name: Sauve, Mark A Contact Phone: +1 907 564 4660 Authorized Title: GPMA/Lisbume Lead PE Authorized Signature: �� /J� Date: 211-111-1 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: + Plug Integrity, ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No OPI" Subsequent Form Requirt - 31Q APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date l l ` irm 403 Revised D4/2017 ORIGINAL RBDMS�4*/MAR052019 Il19 Submit Form and Approved application is valid for 12 months from the date of approval. /�'7/�//� Attachments in Duplicate �1 30-403 Sundry Application for Well PBU L3-24 PTD #186-182 Expected Start Date: February 21, 2019 Current condition of well: Well objective(s): Producer, Operable, Shut In Convert from Lisburne to Ivishak pool. LTSI well, no plans at the moment for Lisburne offtake. Good Ivishak Z1 target to either produce long term to LPC, or identify a DS -04 sidetrack in the future. Proposed program: 1. Drift to TD 2. Sand back. Top of sand -11400' MD 3. Drift to top sand, dump -1 Oft of cement. 4. Perforate Ivishak Z1 (-11255'- 11297'). BP BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 .51 ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD, EAZ, BPG 10112/15) General Information Well Name: 13-24 Well Type: Gas Lift Producer API Number: Well Activity Conventional 4 50-029-21670-00 Classification: Plug Lisbourne, Perf Ivishak Activity Description: Cost Code/ AFE: APBNRWOS Field/ Reservoir: 12 Month Avg IOR, 50 LISBURNE bopd: Add Perf+ Prof Mod Job Type: Estimated Cost, $150 $K: PROFILE MODIFICATION AWGRS Job Scope: Other regulatory Convert from Lisburne to Ivishak 000l requirements? Yes Sundry Form 10-403 Required? Yes Sundry Form 10-404 Primary Secondary Required? Bernhard Stechauner Engineer: Contact numbers: (907) 564-4594 (907) 360-7485 Ryan Thompson Well Intervention Engineer: Contact numbers: (907) 564-4535 (907) 301-1240 Mark Sauve Lead Engineer: Contact numbers: (907) 564-4660 (907) 748-2865 November 14, 2017 Date Created: Revisions (date, who, what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Date Oil Rate Inj Rate Gas Injection GOR Choke Setting Gas Lift Rate Pressure bo d ( p) bw Water ( pd) Rate (scf/stbo) (Mscf/Day) (psi) Cut (%) (Mscf/Day) 11/28/2016 0 bwpd, 1WC 1,055 0 104 4,134 572 10b°I°881 Current Status: Operable Shut In Inclination > 700 at Depth (ft) NA Recent H2S (date, ppm) 5/12/1997 1 60 ppm Maximum Deviation (Angle and 52° 5,100' MD Depth) Datum depth, ft TVDss 8,900' TVDss Dogleg Severity (Angle and Depth) 5° 3,250' MD Reservoir pressure (date, 1/16/2016 1 3,412 psi Minimum ID and Depth 2.250" 11,198' MD prig) Reservoir Temp, F 182° F Shut-in Wellhead Pressure 800 psi Known mesh. integrity pppOT-IC failed, IAxOA fixed with SealTite 2007; Warm DART BUR 110psi/d, Cold BUR 202psi/d problems (specifics) Last downhole operation (date, operation) 1/16/2016 Drift with S. bailer and SBHPS Most recent TO tag (date, depth, toolstring OD) 1/16/2016 12,076' MD 2.00" cent, 1-1/2" s -bailer Surface Kit Fit -for -Service? YES If No, Why? If well has been shut in for > 1 year or job cost> 500M, fill out Non Rig Surface E ui ment Checklist. Comments, well history, LTSI well, no plans at the moment for Lisburne offtake. background information, Good Ivishak Z1 target to either produce long term to LPC, or identify a DS -04 sidetrack in the future. etc: Well Intervention Details Please contact the SOR author if. 1. There is a change in work scope to the approved SOR 2. For well work I $100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20% 3. Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice. GP 100220 (AKA 10-50). by either being documented as Legacy Equipment or having the required design assurance work completed? https://gwo.bpglobal comisites/gwo2/Globall-ibraryll 00220.pdf Suspected Well Problem: LTSI Lisburne well, high WC,Ivishak add perf target. Specific Intervention or Well Objectives: 1 Isolate Lisburne and perforate Ivishak 2 Prove up a future Ivishak sidetrack in the area, depending on Ivishak production results 3 Key risks, critical issues: Mitigation plan: 1 Perforating through two strings, small tubing Will use 2 118" enerjet strip guns Sand back with coil and dump cement on EL will give 2 Isolate Lisburne in a way that's easily reversible us minimal amounts of cement to underream should we elect to re-access Lisburne. Pulling 2 1/8" strip guns back through 2 718" tubing (2.25" Will run jars with the E-Line perforating string to 3 mitigate issues pulling 2 1/8" strip guns back through min ID) 2.25" min restriction. Guns will be shot in 7" liner. Flowback through portable test unit and down L3-24 does not have an active AL line or flowline (both neighboring well flowline (L3-22). If oil rate looks good 4 isolated as part of the "sleeper" project) then justification for returning L3-24 flowline to service will be made. Plan to use red hose for gas lift (sourced from L3-18 or L3-22) Summary Service Line Activity Step # 1 S Drift to TD for 2 1/8" strip guns. Sand back. Top of sand —11,400' MD. See separate word document for sandback procedure. Use Acoustic 2 C Cement Bond Log (12/24/86) for tie in. Note the tubing was not in the well when this log was run so there is no tubing CCL signatures. - 1. Drift and tag top of sand to verify sand top within window (-11,400 - 11,450) 2. Dump bail —1 Oft of cement on top of sand 3 E 3. Caliper from Tubing Tail to surface with PDS 24 arm caliper. Please email data to Ryan Thompson post caliper for review prior to MIT-T. Wait 72 hours for cement to harden.MIT�,(C- talent) per pumping schedule. If fails contact Interventions 4 D Engineer. `7 S44 S Perforate Ivishak Z1 per perforating form. Use Jewelry log fro the coil rig up as tie in log. A. Run jars with perforating assembly to mitigate any issues pulling strip guns back through 2 7/8" 5 E Tubing and the 2.25" minimum restriction. B. Review perforating RP section 5.3, line H for further recommendations shooting strip guns in well with tight tolerance. Flowback well through portable testing unit and down neighboring flowline (recommend 13-22 flowline). L3- 4 T 24's flowline has been isolated as part of the sleeper project. Detailed work scope (If no RP/SOP exists for the intervention type, a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations (may be NA if no change anticipated due to the intervention) BOPD: 100 MMSCFD: 6 BWPD:50 Expected Production Rates: FTP (psi): 200 Choke setting: PI (bfpd/ psi dp) Post job POP instructions: IPOP to LP with AL and test. include in separate excel worksheets attachments: Current wellbore schematic needed: Pert form, logging form, well test chart, annotated mini log, annotated log section, tubing/casing tallies, Wellhead i, etc TRF£= MG VVMIRD= kcft+ ACTWTOR= AXELSD' XB. aL = 80 BF.E = . KOP= 2400 1. .Anpi 52@5700 Wium lvD= 1146 t' Wtum TV D= 83015 Minimum ID = 2.250" @ 11198' 2-718" CAMCO D NPPLE ITDPDFTINR" lllm 1 D=2441 - 9-"—o vu Stmc L3-24 I SAI€l NOTMa: 16 6I1t�n MW 36ICA AHDI EO fiJYI BK -2I 84 DOTE ii QJ BY f I DOTE I REVBV QMAABQiS 12/28188 R 41 ORIUY CptPLEi]ON 0&0&11 1 PJC 1DRAWNG CDPRH:IgNS LOG : 211 Q ON 12/1686 AM,rt DEiEIE WAWM SAFETY N34 031MID7 ANGLEATTTOPPERP 33' ® 11538 1OJD2J03 Nate: K�fat to Ratl�clnn DB far Itebtcal>X41 tlats SRE S l� AL OpNSgz DA 2-V8' -11558 O l 'S -Ti 53 -sl Mi tt18] 2-1!8` 5 11562- 11628 D 81.r11!8] 2118' S 11670-11MB D MOV87 2 -VB' S 1172211729 D 0i111187 2.118' 'S 11738-11742 D Mil V8] 2-1iA' 'S 11702-IIMB D 06111!87 9-"—o vu Stmc L3-24 I SAI€l NOTMa: 16 6I1t�n MW 36ICA AHDI EO fiJYI BK -2I 84 DOTE ii QJ BY f I DOTE I REVBV QMAABQiS 12/28188 R 41 ORIUY CptPLEi]ON 0&0&11 1 PJC 1DRAWNG CDPRH:IgNS 021M/M AM,rt DEiEIE WAWM SAFETY N34 031MID7 RL DATDN MJ 1OJD2J03 D&Bi15V CDBtH,TIDNS 1D,021fb SV D]Ri>gT10N5 5T 03,05I11 RLWRJC GLV D]RRELTLIiS RAIDNOE BAY lM WAL: 13-N PEfA1(Na: 1B61A2B APi ka: 5 D -02621610 -DD SED 22T 1N R15E 870 ML & 565 FWL BP E�braEon(A1 "$ Well L3-24 Work Desc MIT -T Target Pressure 1350 Date 11114/17 Engineer Bernhard Stechauner Phone 9075644594 1-12S Value 1 60 1-12S Date 1 5/12/1 997 Job Objective M|T'Ttubing post cement cap. Attempt Npressure up|Ato1500psi prior toM|T-Th/limit differential pressure across tubing. Pump Schedule F- Stage Fluid Type Pump Into Volume (bbis) Rate (bpm) Max Pressure MIT #1 Test Type MIT -T Target Pressure 1350 Max Applied Pressure 1500 Test Fluid Methanol (Neat) Integri Limits Confirmed L'i MIT #2 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confirmed El MIT #3 Test Type Target Pressure Max Applied Pressure Test Fluid Integrity Limits Confirmed Ll 1% PENDING PERFORATING PROCEDURE sm W.11 1-3-24 APl# 50-029-21670-00 2126— 2.125 Pel ------ - ------------ Do. 11114=17 Prod Error Bernhard Sbochaurer Offloo Ph: 19011564-4594 907 5" -4594 Won L324 Mo.. Ph: 190)16]]-0860 linde API Y: 50-029 21670 00 Prod Eng r: C0111pager; (907) 360-7485 CC or AEE APBNRWOS P.D. Center PBTD WBL Erni.. General IOR T,,o Work D.,,rr,1— Balance Referenced to BHCS Go. DW Count. SPF Phasing So. Pocod.,o AdrrM.,d W.11 Ob WBW See Pr—do,, Machmend; Tiemin bg wdh proposed Pais annotated QlBlu Hn ljurrpl: a pern Powx Spiral Khrm Requested Go. V.: 21/8' Cham.: Emul.t. HMX Is Drawdown hieconnon,ulnurtunifflon.cuoutry During Portman., Preferred Amount of DrunclownSuggestions to Achiaw Dnwdmoo L.at Witt. 12,076 it MD on 11I6/2016 . Est Res. Pres.., Min Wellbore 10: 225_ U .. netuary---- . ..... . .___,-,,,,,-34u_ Mart Swell In Lfquhrl: M. Sava in G.., — -- — ------- 2126— 2.125 Pel ------ - ------------ Perforation Summary S....Cod Won L324 h linde API Y: 50-029 21670 00 Prod Eng r: n.h Prod! Er,, P.D. Center PBTD General Balance Referenced to BHCS Go. DW Count. SPF Phasing Zona AdrrM.,d WBW QlBlu 01B/U . .. . ..... ... OIB/U D/B/U Wald OUSTIC CEMENT BOND LOG -/SIGNATURE/GAMMA RRY fflm BLf WA QlCOfiPIRRTEO ___ - ---- --_L3-24 L 3 - 24 PRGIDE BRY ( LISBOAME P00. I NORTH SLOPE sr ATE H-W 815' ENL U.M. _ TUPII:_ _ RGE scBNRv cvva ft". 8.8' ElE01TEp5 8B 60.8' 0i 59.8' 60.0' I1. Pam P.O. I � 4' MTB. 2' 1' E RECOfUEB 442 N. 9RE DIOE}'NER-PATI R tv BanNaL RECOW 0 TO 1-11116 in 00 1-11116 in 346° 2-118 in 00 2-1/8 in 1450 Gun type Enerjet Enerjet Enerjet Enerjet Shot density (SPFj 4 and 6 4 and 6 4 and 6 4 and 6 Minimum restriction 45.2 (1 78) 45.2 11.78) 57 12251 57 (2.25) mm (in) Bore- hole fluid All Ail Ali All Max shooting Interval 14.3 147) 12.1 1401 12.8 1421 12.1 1401 m [n] Min. casing ID mm (in) 101.6 141 1016 141 114.3 14.51 114.3(45) Max. pressure (K) 20 20 20 1 20 HMX temp 1 hour (F3 365 365 365 365 HNS temp 1 hour [F3 WA N/A 450 WA 19 lb (4 SPF) 21 Ib (4 SPF) 29 lb (4 SPF) 31 Ib (4 SPF) Gun wt. (10 R fully loaded) 25 lb (6 SAF) 27 Ib (6 SPF) 39 Ib (6 SPF) 41 Ib (6 SPF) by 0 Portable Test Separator Work Request Date 11/14/2017 AFE: APBNRWOS Name Bernhard Stechauner Contact Number 1 (907) 564-4594 Contact Number 2 (907) 360-7485 Well L3-24 Current Status: Latest H2S Value: Welitest (or expected rates): Base Case High rate case (if applicable) Return Well Return well PBGL PBGL cot Oil Water Fgas GL FTP I FGOR IWC (bopd) lbwpd) (MMCF D) (MMCFD) (psi) I (scf/stb) I (%) 100 50 1 6.0 ? 600 60,000 33% 500 100 10.0 ? 600 20,000 17% L3-22 I Well is LTSI IOR HPIP #2 well [OR Well Rig up red hose from whatever source is most coovientent. Background unique to this operation (Only if required, beyond 5oR background) L3-24 has been converted from a LTSI high WC producert to a ZI Ivishak producer. Productivity of the Ivishak Z1 interval is highly uncertain and the 0-24 flowline has been isolated as part of the "sleeper project". Before initiating the return of L5 -24's flowline to active status it will be necessary to verify that the oil rate form the new Ivishak perfs is high enough to 'ustifiy the work. Portable Test Separator Objectives 1 Determine the stabilzed IOR from the new Ivishak perfs. 2 3 4 Pad Separator ack? Yes Obtain at least one well test per day for three days after POP and stabilization. Clean-up period should be short. Plan tO have AL supplied from red hose for POP. Notes: Well will be POP'd Via "RP: Generic Unloading Procedure using GL" unless otherwise specified Target solids will be < 0.1% upon RDMO, unless otherwise specified Target PH will be 6.5 - 7 per RP upon RDMO unless otherwise specified Well: L3-24 TVJ=ETI (F(FEET) Mo 1:240 'J� a' GRJ •� �nnafnoc++ :^:-eli scntmaSir £3575 22P 120 21N X600 122 21P 8025 1250 14P 1127 -8650- .13P 1130 -8675 11325 ION -8700 135 �-225__ - --- - ---- - - - - --- -- - - WeL Entries IOR Type Work Description Sand Preaedufe Log: 2 M DA Date: 12/19/1938 Company: Depths(Nom4o) Demr.(Nem4o) Fee SPF 11255' 11,297' Requested Gun She: Charge: Ia Drawdown fed.ssarylDeerl...cesaary During Perfeseng Pnfarrsd Amount a DrawdownlSuggastione to Achieve Drawdown Last Drift. 12,073 ft MO on 1/162016 Eat Res. Pres. Q4 Perforation summary Well: LJ 24 Date', API a: 58029 3167000 Cenral comment,: Depth. to this it... lag to M on da th with the Mannas lug. Grant. Pool, Min Wa .lD: 225 Max Swell in Liquid: Mas Swell in Gas: Zona AdlRnllp d Z1 Add 6,900NDss MD is 2413 Psi Balance Referenced to SHGS Gun DM. OranL SPP Phasklp OIB10 WSW OIs/U WSW D,eID 0113,13 Dle,u 019713 01611.1 Prod Engr Pero Zone Ail,"lliaparf PENDING PERFORATING PROCEDURE MR: 1.3-24 API a: 50-029-21670410 Own: 1111412017 Prod Engr Bemhand Stechnunar Oma. Ph: (907) 6844594 j H2S Lew[: Home Ph: W'. OeIllPager. (907)360-0489 CO or ARE: APBNMOS WeL Entries IOR Type Work Description Sand Preaedufe Log: 2 M DA Date: 12/19/1938 Company: Depths(Nom4o) Demr.(Nem4o) Fee SPF 11255' 11,297' Requested Gun She: Charge: Ia Drawdown fed.ssarylDeerl...cesaary During Perfeseng Pnfarrsd Amount a DrawdownlSuggastione to Achieve Drawdown Last Drift. 12,073 ft MO on 1/162016 Eat Res. Pres. Q4 Perforation summary Well: LJ 24 Date', API a: 58029 3167000 Cenral comment,: Depth. to this it... lag to M on da th with the Mannas lug. Grant. Pool, Min Wa .lD: 225 Max Swell in Liquid: Mas Swell in Gas: Zona AdlRnllp d Z1 Add 6,900NDss MD is 2413 Psi Balance Referenced to SHGS Gun DM. OranL SPP Phasklp OIB10 WSW OIs/U WSW D,eID 0113,13 Dle,u 019713 01611.1 Prod Engr Pero Zone Ail,"lliaparf TRE FMC WELLHEAD= MCEVOY ACTUATOR= AXELSON KB. ELEV = 60' BF. ELEV = 2-1/8" KOP= 2400' Max Angle = 52 @ 5700' Datum MD= 11461' Datum TVD = 8900' SS 13-3/8" CSG, 68#, K-55 BTC, ID = 12.451" 114' 13-3/8" CSG, 72#, L-80 BTC, ID = 12.347" 4380" 9-5/8" CSG, 47#, L-80 NSCC XO TO L-80 BTC 1--F 5163 - Minimum ID =2.250" @ 11198' 2-7/8" CAMCO D NIPPLE I TOP OF 7" LNR I 2-7/8" TBG -IPC, 6.5#, L-80 EUE 8RD, .0058 bof, ID = 2.441" 47#, L-80,.0733 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: ZDL DA ON 12/16/86 ANGLE AT TOP PERF: 33" @ 11538' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/8" 'S 11538-11558 O 04/11/87 2-1/8" 'S 11562 - 11628 O 04/11/87 2-1/8" 'S 11670-11698 O 04/11/87 2-1/8" 'S 11722 - 11728 O 04/11/87 2-1/8" 'S 11738-11742 O 04/11/87 2-1/8" 'S 11792 - 11798 O 04/11/87 Selective Shots PBTD - 12093' LNR 29#, L-80 BTC, .0371 bpf, ID = 6.184" 1-F 12-13W L3-24 SAFETY NOTES: 2-7/8" CAMCO TRDP-1A SSA SSSV, ID = 2.312" CHEMICAL MANDRELS !DEVI TYPE 1 VLV 1LATCHIPORT DF 8 1 KBMG-L I DMY I BK -2 1 0 03/e GAS LIFT MANDRELS ST MD TVDIDEVI 12/20/86 TYPE I VLV ILATCHIPORT ATD/TP DATE 2 2776 2759 20 MC-FMHO DMY BK -2 0 03/22/87 3 5040 4412 51 MC-FMHO DOME BK -2 16 10107/91 4 6739 5506 47 MC-FMHO DMY BK -2 0 03/22/87 5 7933 6302 50 TE-FMHO SO BK -2 24 11/30/91 6 11018 8497 36 CA-FMHO EO DMY BK -2 0 11/01/91 19-5/8"X2-7/8" BROWN HB PKR, ID = 4.00" 12-7/8" CAMCO D NIP. ID = 2.25" 1 11211' -12-7/8" WLEG, ID=2.441" i 11196' ELMD TT LOGGED 04/11/87 DATE REV BY COMMENTS DATE REV BY COMMENTS 12/20/86 RWN 41 ORIGINAL COMPLETION 03/06/11 PJC DRAWING CORRECTIONS 02/09/03 ATD/TP DELETE WAIVER SAFETY NOTE 03/04/07 RL DATUM MD 10/02/09 DMS/SV CORRECTIONS 10/02109 SV MD CORRECTIONS 03/05111 RLW/PJC GLV CORRECTIONS 7" MARKERJOINT PRUDHOE BAY UNIT WELL: 13-24 PERMIT No: 1861820 AIR No: 50-029-21670-00 SEC 22 ,T11 N, R15E, 870' FNL & 845' FWL BP Exploration (Alaska) TREE= FMC VIELLHEAD= MCEVOY ACTUATOR= AXE.SON KB. ELEV = 60' BF. E -EV = Opn1Sgz KOP= 2400' Max Angle = 52 @ 5700' Datum MD= 11461' Datum TVD= 8900'SS PROPOSED L3-24 318" CSG, 68#, K-55 BTC, D= 12.451" -318" CSG, 72#, L-80 BTC,— 12.347" 4380' r CSG, 47#, L-00 NSCC XO TO L-80 BTC 51$3' Minimum ID =2.250" @ 11198' 2-7/8" CAMCO D NIPPLE TOP OF 7" LNR 11166' 2-7/8" TBG -13C, 6.5#, L-80 EEBRD, .0058 bof. D=2.441" =8.681' H 11416' PERFORATION SUMhMRY REF LOG ZDL DA ON 12/16/86 ANGLE AT TOP PERF: 33'@1153V Note: Refer to production DB for historical pert data SIZE SPF INTERVAL Opn1Sgz DATE 2-118" 'S 11538-11558 O 04/11187 2-118" 'S 11562-11628 O 04/11187 2-118" 'S 11670-11698 O 04/11187 2-118" "S 11722-11728 O 04/11187 2-118" "S 11738-11742 O 04/11/87 2-118" *S 11792 - 11798 O 04/11/87 ' Selective Snots 6.184" H 12139' SAFETY NOTES: ' CAMCO TROF-IA SSA SSSV, D = 2.312' CHEMICAL MANDRELS TYPE 1 VLVGLATTPORI� KBML DMY BK -2 0 1 0312: GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 2776 2759 20 MGFM-D DMY BK -2 0 03/22/87 3 5040 4412 51 MGFMHO DOME BK -2 16 10/07/91 4 6739 5506 47 MGFM tO DMY BK -2 0 03/22/87 5 7933 6302 50 TEFMiO SO BK -2 24 11/30/91 6 11018 8497 36 CA-FMHO EQ DMY BK -2 0 11/01/91 11125' H 9-518" X 2-7/8" BROM HB PKR D = 4.00' 11196' H2-7/8"CAMCOONRD=2.25" D=2.441" 11390' CMT CAP 11400' TOP OF SAND DATE RET/ BY CONVENTS DATE REV BY COMMENTS 12120/86 RM 41 ORIGINAL COMPLETION 03/06/11 PJC DRAWING CORRECTIONS 02/09/03 ATD'TP DELETE WAIVER SAFETY NOTE 03/04/07 RL DATUM MD 10/02/09 DMS/SV CORRECTIONS 10/02/09 SV MD CORRECTIONS 03/05/11 RLVNPJC GLV CORRECTIONS 17" MARKER JOINT I PRUDHOE BAY UNIT WELL: 1-3-24 PERMIT No: 1861820 AR No 50-029-21670-00 ,Ti t N, R1 5E, 879 FNL & 845' FWL BP Exploration )Alaska) Rixse, Melvin G (DOA) From: Rixse, Melvin G (DOA) Sent: Monday, February 25, 2019 4:05 PM To: 'Thompson, Ryan' Cc: Lastufka, Joseph N; Douglas, David (Wipro Technologies); Sauve, Mark A; Stephen F Davies (DOA) (steve.davies@alaska.gov); David S Roby (DOA) (dave.roby@alaska.gov); Guy L Schwartz (DOA) (guy.schwartz@alaska.gov) Subject: RE: PTD 186-182 PBU L3-24 Sundry 319-072 Plug and Perf Ryan, You have verbal approval to proceed with well work per Sundry 319-072 to change production from the Lisburne pool to the Ivishak pool. Please note that the Ivishak and Lisburne Pools are not permanently isolated. When this well is no longer economical or if it is sidetracked, compliance to AOGCC 20 AAC 25.112 will be required. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-223-3605 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231) or (Melvin.RixsePalaska.KovI. From: Thompson, Ryan <RYAN.THOMPSON@bp.com> Sent: Monday, February 25, 2019 3:16 PM To: Rixse, Melvin G (DOA) <melvin.rixse@alaska.gov> Cc: Lastufka, Joseph N <Joseph.Lastufka @bp.com>; Douglas, David (Wipro Technologies) <David.Douglas@bp.com>; Sauve, Mark A <Mark.Sauve@bp.com> Subject: RE: PTD 186-182 PBU 1.3-24 Sundry 319-022 Plug and Perf Mel, Attached is the revised program for L3-24. This program is for a short term test of the Ivishak on this well. To answer your questions below: 1. When was your last MIT on tubing and inner casing? MIT -T to 2500 psi & MIT -IA to 1500 psi on 3/22/87 (following completion of the well) 2. What pressure do you plan to test your cement plug to? 1500 psi surface pressure Please let me know if you have any questions. Thanks, BP EXPLORATION (ALASKA) INC., PRUDHOE BAY UN LIS 1-3-24 (186-182) PRUDHOE BAY, LISBURNE OIL Monthly Production Rates av,vvv,vvv 1,000,000 s Y C C0 L C 100,000 LL V O N 10,000 M L) w O 0 Y M d LL 1,000 u O a A 100 N 3 O L 10 Cum. Prod Oil (bbis): 1,025,820 Cum. Prod Water (bbls): 3,292,526 Cum. Prod Gas (mcf): 2,551,221 _. 10,000,000 a, 1,000,000 M 0 100,000 0 3 O 3 =r 10,000 O Z m 1 1,000 O C� G a M ro 100 N 3 0 3 r 10 s Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 Produced Gas (MCFM) . GOR Produced Water (BOPM) — Produced 011(BOPM) SPREADSHEET–Prod-Inject CuNes_Well_V117_18561820_PBU_L3-24_20190220.xlsx 2/20/2019 SOF 7 • • _ I y/, s THE STATE Alaska Oil and Gas „w —s�� `TA °i\ LAsKA Conservation Commission te, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY' Fax: 907.276.7542 www.aogcc.alaska.gov Bernhard Stechauner FS2 Lead PE BP Exploration(Alaska), Inc. A N 1 8 1 i,16 PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU L3-24 Permit to Drill Number: 186-182 Sundry Number: 317-600 Dear Mr. Stechauner: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this . day of January, 2018. • RECEIVED STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMM• N I.1 ; 2 ?017 APPLICATION FOR SUNDRY APPROVALS �J 20 MC 25.280 / (om,, 1. Type of Request: Abandon 0 Plug Perforations (0. Fracture Stimulate 0 Repair Well 0 ,AC 5 tutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool H- Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 186-182 - 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development B • 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-21670-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No m PBU L3-24 - 9. Property Designation(Lease Number): 10. Field/Pools: ! 'r_ii:4,44^`��r" /.!3<� 'hS ADL 0028323 • /1' 11 t_U6,ze)5Z. -- ,z,2.i,.,/•� PRUDHOE BAY,LISBURNE OIL : , t`� -Z'2 U�� /j 11. / PRESENT WELL CONDITION SUMMARY i.el,/cb Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12141 • 9442 • 12094 9401 Casing Length Size MD TVD Burst Collapse Conductor 80 20" 39-119 39-119 1490 470 Surface 79 13-3/8" 38-117 38-117 3450 1950 Surface 4267 13-3/8" 117-4383 117-3996 4930 2670 Intermediate 11379 9-5/8" 37-11416 37-8822 6870 4760 Production Liner 941 7" 11198-12139 8643-9440 8160 7020 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11538-11797 8924-9144 2-7/8" L-80 35-11212 Packers and SSSV Type: 9-5/8"x 2-7/8"BOT HB Packer Packers and SSSV MD(ft)and TVD(ft): 11125, 8584 2-7/8"Camco TRDP-1 A SSSV 2192,2191 12.Attachments: Proposal Summary 0 Wellbore Schematic IR( 13.Well Class after proposed work: Detailed Operations Program H BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development 171 • Service 0 14.Estimated Date for Commencing Operations: 1/15/18 • 15. Well Status after proposed work: Oil RI • WINJ 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Stechauner,Bernhard be deviated from without prior written approval. Contact Email: Bernhard.Stechauner@bp.com Authorized Name: Stechauner,Bernhard Contact Phone: +1 907 564 4594 Authorized Title: FS2 Le d PE Authorized Signature: Date: 1 Z./Z VI ?— COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 511 —(O O Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: f Post Initial Injection MIT Req'd? Yes 0 No L5 Spacing Exception Required? Yes 0 No 52/ Subsequent Form Required: /Q -- .4 APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: I 141 I :v-ORU3INAL Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachmen in Duplicate • S Alaska Oil and Gas Conservation Commission 3333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Application for Sundry Approval (10-403) December 21, 2017 To Whom it May Concern: Attached please find the Sundry Application for Sand Back with Cement Cap to Plug the Perforations in the Lisburne Formation and Addition of Perforations in the New Pool of • the Ivishak Formation for Well L3-24, PTD # 186-182. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-403 • • ALASKA WELL ACTIVITY STATEMENT OF REQUIREMENTS (V2.0, DBR, LHD, EAZ, BPG 10/12/15) General Information Well Name: L3-24 Well Type: Gas Lift Producer API Number: 50-029-21670-00 Well Activity Conventional 4 Classification: Activity Description: Plug Lisbourne, Perf Ivishak Cost Code/AFE: APBNRWOS Field/Reservoir: LISBURNE 12 Month Avg IOR, 50 bopd: Job Type: Add Perf+Prof Mod Estimated Cost, $K: AWGRS Job Scope: PROFILE MODIFICATION Other regulatory Convert from Lisburne to Ivishak pool requirements? Sundry Form 10-403 Yes Required? Sundry Form 10-404 Required? Yes Primary Secondary Engineer: Bernhard Stechauner Contact numbers: (907)564-4594 (907)360-7485 Well Intervention Engineer: Ryan Thompson Contact numbers: (907)564-4535 (907)301-1240 Lead Engineer: Mark Sauve Contact numbers: (907)564-4660 (907)748-2865 Date Created: November 14, 2017 Revisions(date, who,what changed): Current Well Status Information Water Rate or Gas Rate or FTP or Injection Oil Rate Inj Rate Gas Injection GOR Gas Lift Rate Date Choke Setting y) Pressure (bopd) (bwpd)Water Rate (scf/stbo) (Mscf/Day) (%) (Mscf/Day) (psi) 11/28/2016 0 1881 bwpd, 1,055 0 104 4,134 572 WC 100% Current Status: Operable Shut In Inclination >70°at Depth(ft) NA Maximum Deviation (Angle and Recent H2S (date, ppm) 5/12/199760 ppm Depth) 52° 5,100' MD Datum depth,ft TVDss 8,900'TVDss Dogleg Severity(Angle and Depth) 5' 3,250' MD Reservoir pressure(date, 1/16/2016 3,412 psi Minimum ID and Depth 2.250" 11,198' MD psig) Reservoir Temp, F 182° F Shut-in Wellhead Pressure 800 psi Known mech. integrity PPPOT-IC failed. IAxOA fixed with SealTite 2007: Warm OART BUR 110psi/d, Cold BUR 202psi/d problems(specifics) Last downhole operation (date, operation) 1/16/2016 Drift with S. bailer and SBHPS Most recent TD tag (date, depth, toolstring OD) 1/16/2016 12.076' MD 2.00"cent, 1-1/2"s-bailer Surface Kit Fit-for-Service? YES If No,Why? If well has been shut in for> 1 year or job cost>$500M, fill out Non Rig Surface Equipment Checklist. Comments,well history, LTSI well, no plans at the moment for Lisburne offtake. background information, Good Ivishak Z1 target to either produce long term to LPC, or identify a DS-04 sidetrack in the future. etc: 1 ccmcvr. .49 fvb e ' weld cotitie o1 qr ; 3,004 6oj2 Zvi fo,co k,44 wW`e/:%'` Out. 1Nor4") ,S yams Peo 4/m44 dropper /t/ow 50 BOP, q,Ad 'i' e' cc? wc1 OtorP Q;�, w ell 441 o fen 5'b IT /r hr eVI w�'11, Ofl j r qds• q-r'M '8 ro /Psit" r � ,yw ries t/1� wlcC vAyvz S P( yy.*41 r4g ( ' sO /r Ca* k (QcO ar P v v� rim f olf f3erK AIww far i'Mf.K✓ !e covcrp �'foA ire !�" ' %2/1 7 • 4111 Well Intervention Details Please contact the SOR author if: 1.There is a change in work scope to the approved SOR 2.For well work>$100M estimated total cost, as soon as it is reasonably anticipated that the actual cost will exceed the estimated cost by 20%. 3.Does the planned equipment to be installed in the well meet the requirements of the GWO Well Equipment Group Practice,GP 100220(AKA 10-50),by either being documented as Legacy Equipment or having the required design assurance work completed?https://gwo.bpglobal.com/sites/gwo2/GlobalLibrary/100220.pdf Suspected Well Problem: LTSI Lisburne well, high WC,Ivishak add perf target. Specific Intervention or Well Objectives: 1 Isolate Lisburne and perforate Ivishak 2 Prove up a future Ivishak sidetrack in the area, depending on Ivishak production results 3 Key risks,critical issues: Mitigation plan: 1 Perforating through two strings, small tubing Perform SPAN analysis to identify best gun Sand back with coil and dump cement on EL will give 2 Isolate Lisburne in a way that's easily reversible us minimal amounts of cement to underream should we elect to re-access Lisburne. - 3 Summary Service Line Activity Step# 1 S Drift to TD 2 C Sand back. Top of sand 11,400' MD 3 E Drift to top sand, dump-10ft of cement perforate Ivishak Z1 Detailed work scope(If no RP/SOP exists for the intervention type,a well-specific procedure is required in addition to the SOR): 1 2 3 Performance Expectations(may be NA if no change anticipated due to the intervention) BOPD: 100 MMSCFD: 6 BWPD: 50 Expected Production Rates: FTP(psi): 200 Choke setting: PI(bfpd/psi dp) Post job POP instructions: POP to LP with AL and test. Attachments -include in separate excel worksheets Required attachments: Current wellbore schematic As needed: Perf form, logging form,well test chart,annotated mini log, annotated log section,tubing/casing tallies,Wellhead info,etc 0 • Well: L3-24 (FEET) EE)'� _gP " A nnote4on Well sche attic 1:240 1:240 9 0 4P1 <^: _8575 -1120 i I" € 60 ..r p Awl,225-;;,,•1...•i• ..,,,,,,,,,,,,:,•,-, , [ - $ 4 i.1254T x 11275 x 8650 -- f . 13P 11111 : -111300~ il , -8675 1- w -1.1325' -8700 -°1135G • • • .14Hit PENDING PERFORATING PROCEDURE Well: L3-24 API 8:50-029-21870-00 9 (907)564-4594 Date: 11l14I2017 Prod Engr Bernhard Stechauner Office Ph: ; H2S Level: ' Home Ph: Ij 60 ppm Cell/Pager: (907)360-7455 CC or AFE: APBNRWOS _...... _.. WBL Entries IOR Type Work Description See Procedure Well Objectives and Perforating Notes: See Procedure. Attachment: Tie-in log with proposed perfs annotated Reference Log Tie in Log Add 0 feet Log: Z DL DA to the tie-in log to be on Date: 12/16/1986depth with the reference log. Company: _ _....... _...... Depths(from-to) Depths(from-to) Feet SPF Orient. Phasing Zone Ad/Re/Iperf 11,255' 11,297' Z1 Add Requested Gun Size: Charge: Min Wellbore ID: 2.25 Max Swell in Liquid: _.... _............ Max Swell in Gas: ........ Is Drawdown Necessary/Desired/Unnecessary During Perforating Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Drift: 12,076 ft MD on 1/16/2016 Est Res.Pres.00 8,900'TVDss MD is 3412 psi Perforation Summary Summary Dist Well: L3-24 Town: Date: API 8: 50-029-21670-00 Prod Engr: Anch Prod Engr P.D.Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient. SPF Phasing Zone AdperftReperf 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U 0/B/U • S S TREE= FVC WEI I HEA C= MCEV DY L3-24 S AFETY NO TES: ACTLJA TOR= AXELSON KB BEV= 57 i I BF REV= ,. KO P= 2.102 1 2.192' H2-7/81 CA MC'0 TITER 14 SSA SS 511,ID=2.31Z ,...,... ..._... „„.„ . , ..,.,_,.. Max Ang.e= 5 2 5 700 LILI Datum IAD= 11 46 1' CI-EIACA L MANDRELS °atom Tv D= 8900 SS Ell ST MD ND...DEV TY FE V LV LA TO-I PC ITU DATE 1 2280 22 78 9 1.03 MG-L DMY BK-2 0 03r '87 113-3131 CSG,984 K-55 BTC,ID=1 2.45 1' H 114' GAS LIFT MANDRELS ST PAD ND DEV TYPE V LV LA ICH PC RT DATE 11111 1 1 I I 13-3 'CSG,72*,L-80 BTC,ID=12.347' H 4389' Ed _ 2 27713 2759 20 kC-Fk440 GM' BK-2 0 03i22i8 7 3 5040 44 12 51 MC-F WO DOME BK-2 16 10/07791 4 5736 5505 47 kC-F WO DEE B K-2 0 03/22i8 7 I 5-518'CSG 47*,L-80 NSCC XO TO L-80 BTC H 5163' 5 7'233 8322 50 TE-8M0 SO BK-2 24 11/30(9 1 6 1 10 18 8497 35 CA-F54-10 OD DMY BK-2 0 11,01,91 Minimum ID=2.250"@ 11198' 2-7/8" CANICO D NIPPLE : ------1 11125' H,,,_5 9-X 2-718-BROWN NB PKR 0=-1.00' I 'TOP OF r LNR H 11186' Hu I i I 11198' V12-7,8'CA!ACO 0 NIP,0=225' I 2-77.9'TB 0-PC,6 i*,L-80 B_IE SRC —I 11211' f—' ', I 11211' H2-7/8',4AEG,It=2'i-4 1' .0,Z 8 bp f, IC=2.4 41' I i'11918' Ha Nu yr LOGGED 34 11:87 19-518"CSG,47it, L-30,.3733 opt', IC=9381' H 11416' HAI PEEP:RATION 3IJI14.4ARY 0 1 11501' 1-17• MARKER JOCIT I REF LOG:ZCL DA ON 1218G A.NCLE AT TOP _.RF- 33'.a! 11533 Note: Refer to Prod_.-.:.ttai DB for'es torical parr data SIZE SPF INTERVAL OpniSqz DATE I ' 2-118' 'S 1153 8-1 5581 0 04/11/87 2-1/8' 'S 11%2-1 1629 0 04.1 1:87 2-1;9' 'S 11 37 0-1 1%8 0 94:11;87 I ' 2-1,8' S 11 72 2-1 172 9 0 34,11/87 2-1,6' S 11 73 8-1 174 2 0 34111.87 2-1/8- '0 11 79 2-1 1799 0 34/11/87 I 'Select.Ne Shots PBTD 12093' I 4+:4:if: 17'LNR,294,L-30 BTC,.0371 oof,ID=5.194- H 12139' DATE REV BY COMMENTS DATE R2i BY COMMENTS FD-OE BAY LILT 1 2/2O196 RWN 41 °Rail NAL.COMPLETION '3 3i06/11 PJC C41,4 WINO CORR TiONS AELL L3-24 02639/03 A 1D/TP DELETE WAIVER SAFETY NOTE, PEWIT Na 1361823 93104/07 RL DATUM MD API No. 5C320-21/3l0-3) 10/02109 DIAS,^SV CORRTEDItE SEC 22,TI 1N,18158.970 FM_8 345 FWL 1302r09 SV PAD CORRECTIONS 03/05/11 RLWPJC CIV OD RRECTCNS EIP Exp lo ration(Alas ka) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 20, 2012 Mr. Jim Regg 5i.,A4NED AUG 0 1 2012 Alaska Oil and Gas Conservation Commission 3-12- 333 West 7 Avenue 1 Anchorage, Alaska 99501 ! a- Subject: Corrosion Inhibitor Treatments of GPMA Lisbume 3 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA L3 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 altemate, 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 (10404) GPMA Lisbume 3 I Date: 03/08/2012 Corrosion Initial fop of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date 13-01 1890750 50029219590000 0.0 N/A 0.0 N/A 10.20 11/29/2011 13-02 1861540 50029216440000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-05 1851950 50029214210000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-08 1831430 50029210190000 3.0 N/A 3.0 N/A 27.20 11/29/2011 L3-11 1852310 50029214520000 0.0 WA 0.0 WA 7.65 11/29/2011 1.3-12 1861610 50029216510000 Dust Cover N/A 0.0 WA N/A 3/8/2012 L3-15 1852660 50029214760000 0.0 N/A 0.0 WA 8.50 11/29/2011 13-18 1861670 50029216570000 0.0 N/A 0.0 N/A 11.90 11/20/2011 L3-19 1852860 50029214940000 0.0 N/A 0.0 N/A 7.65 11/29/2011 L3-22 1861750 50029216630000 0.0 N/A 0.0 N/A 10.20 11/20/2011 L3-23 1853060 50029215130000 0.0 N/A 0.0 N/A 10.20 11/20/2011 •--- L3-24 1861820 50029216700000 0.0 N/A 0.0 N/A 8.50 11/29/2011 L3-28 1890660 50029219550000 P&A 12/93 NA NA NA NA NA L3-30 1861850 50029216730000 0.0 N/A 0.0 N/A 10.20 11/29/2011 L3-31 1860340 50029215440000 0.0 N/A 0.0 N/A 8.50 11/29/2011 ~t~C STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COMMISSION JAN 1 8 ~ 0~~ REPORT OF SUNDRY WELL OPERATIOI~ska Oil & Gas Cons. Cornmissionl 1. Operations Abandon ~ Repair Well Q Plug Perforations ~ Stimulate ~ Other~h~ TITS Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension 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 186-1820 ' 3. Address: P.O. Box 196612 Stratigraphic Service ' 6. API Number: ~ Anchorage, AK 99519-6612 50-029-21670-00-00 7. KB Elevation (ft): 9. Well Name and Number: 60 KB ' L3-24 ' 8. Property Designation: 10. Field/Pool(s): - ADLO-028323 PRUDHOE BAY Field/ LISBURNE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12141 ~ feet Plugs (measured) None true vertical 9441.68 - feet Junk (measured) None Effective Depth measured 12094 feet true vertical 9400 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 SURFACE - 120' SURFACE - 120' 1490 470 Surface 4380' 13-3/8" 72" L-80 SURFACE - 4380' SURFACE - 3994' 5380 2670 Production 11416' 9-5/8" 47# L-80 SURFACE - 11416' SURFACE - 8823' 6870 4760 Liner 941' 7" 29# L-80 11198' - 12139' 8643' - 9440' 8160 7020 DFYEu~3' JAN ~ ~ 2000 ~~'u!'t9> rf i d M E Pe orat on epth: easured depth: SEE ATTACHMENT True Vertical depth: Tubing: (size, grade, and measured depth) 2-7/8" 6.5# L-80 SURFACE - 11198' 0 0 - Packers and SSSV (type and measured depth) 9-5/8"X2-7/8" BRWN HB PKR 11111' 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: 0 Subsequent to operation: 24 135 1226 526 14. Attachments: 15. Well Class after proposed work' copies of Logs and surveys Run Exploratory ~~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~~ WAG ~' GINJ WINJ ~' WDSPL ~'' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature- Phone 564-4944 Date 1/17/2008 Form 10-404 Revised 04/2006 ~~~~ ~~ ~ `~~~ ~ ~o~~ ~ (, (a7 Submit Original Only • L3-24 186-1820 PERF ATTACHMENT MD OPN/SQZ TVD 11537.5 11538.5= O 8923.61 8924.44'. 11539.5 11540.5 O 8925.27 8926.11 `' 11541.5 11542.5 O 8926.94 8927.78! 11543.5 .. 11544.5 O 8928.61 8929.45 ~ , 11545.5: 11546.5 O 8930.28 8931.11= 11547.5' 11548.5 O 8931.95 8932.7& 11549.5: W _.. 11550.5 O 8933.62 8934.45: 11551.5 11552.5 O 8935.29 8936.12' 11553.5 11554.5 O 8936.96 8937.79 11555.5- 11556.5 O 8938.63 8939.46' 11557.5 11558.5 O 8940.3 8941.13= 11561.5 11562.5' O 8943.64 8944.48 11563.5: 11564.5= O 8945.31 8946.15 11565.5 11566.5 O 8946.98 8947.82:: 11567.5 11568.5 O 8948.65 8949.49 11569.5 11570.5 O 8950.33 _,. 8951 16 11571.5 11572.5 O ~ ___-_-- _ n ... ~ 8952 .. _.-._-~ 8952 83~ 11573.5 11574.5 O 8953.67 8954.51 11575.5 11576.5 O 8955.34 8956.18 11577.5 11578.5 O 8957.02 8957.85 11579.5 11580.5 O 8958.69 8959.53 11581.5 11582.5 O 8960.36 8961.2.. 11583.5 11584.5 O 8962.04 8962.87 11585.5 11586.5 O 8963.71 8964.55 11587.5 11588.5 O 8965.39 8966.22 11589.5 11590.5 O 8967.06 8967.9 11591.5 11592.5 O 8968.74 8969.57 11593.5' 11594.5 O 8970.41 8971.25 11595.5 11596.5 O 8972.09 8972.92 11597.5: 11598.5 O 8973.76 8974.6 11599.5 11.600 5' O 8975.44 8976.28 11601.5 11602 5 O 8977.12 8977.96 11619.5 11620.5 0..~.. 8992.22 8993.06 11621.5 11622.5 O 8993.9; 8994.74 11623.5 11624.5 O 8995.58 8996.43 11625.5' 11626.5 O 8997.27 8998.11 11627.5' _.._... 11628.5 O 8998.95 8999.79 1.1649.5. 11650.5 O 9017.48 9018.32 11651.5 i 1652.5 O 9019.17 9020.01 11653.5 11654.5 O 9020.85. 9021.7 11669.5 11670.5 O 9034.37 9035.22 11671.5 11672.5 O 9036.06 9036.91 11673.5 11674.5 O 9037.76 9038.6 11675.5 11676.5 O 9039.45 9040.3 11677.5; ~~ rM~.. 11678.5 ~.:... , O 9041.14 9041.99 11679.5' 11680.5 O 9042.84 9043.68 11681.5; 11682.5 O 9044.53 9045.38 11683.5 11684.5 O 9046.23 9047.07 • • L3-24 186-1820 PERF ATTACHMENT 11685.5. 11.686.5 O 9047.92 9048.77 11687.5, 11688.5 O 9049.62 9050.46;:.. 11689.5: 11690.5 O 9051.31 9052.16' 11691.5.: _... 11692.5 O 9053.01 9053.86- 11693.5 11694.5 W O 9054.7 9055.55'. 11695.5: 11696.5 0... 9056.4 9057.25' 11697.5. 11698.5' O 9058.1 9058 95! . , ..,_ 11721.5' _ . 11722.5;_ O 9078.5 9079.35' 11723.5 11724.5; M . O ..... 9080.2 . 9081.05 11725.5 ..~... ,~ ..... ..... 11726 5 . O 9081.91 9082.76 11727.5 11728.5 O 9083.61 9084.46''. 11737.5 ~ 11738.5 O 9092.13 9092 99' ~ 1~ 1739.5= 11740.5 O ~ ~ 9093.84 9094.69: 11741.5` 11742.5 O 9095.55 9096.4:'•.. 11791.5= 11792.5 O 9138.34 9139.2 11793.5 11794.5 O 9140.06': 9140.91 1 1795 5 11796.5 O 9141 77 9142 63 , 11797.5 11798.5 O 9143.49 _._.__.. 9144.35' - • • L3-24 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVtT'YDgTE ~ : - SUMMARY 11/8/2007 T/I/O=SSV/50/0+, Temp=S1. Assist Seal Tite seal IC void. , Rigged up pump equipment. Pressure test pump equipment to 4000 psi/ 10 min, test good. Pumped Hyd fluid through void to achieve .8 gpm leak rate C«3 500 psi. Pumped in 1 liter of Seal Tite flex plug in stages in 1 hr's time. The IC void was holding 3500 psi with minimal leak-off. Let sealant cure over night. 11/9/2007T/I/O=SSV/50/0+, Temp=S1. Assist Seal Tite seal IC void. Rigged up pump equipment. Pressure test equipment to 4000 psi/ 10 min, test good. Pressure test IC void to 3500 psi 30 min, lost 500 psi. Pumped 300 mililiters of Gly flo. Let cure for 5 hrs. Pressure test to 3500 psi for 30 min, test good, no loss of pressure.. 11/13/2007;***"WELL S/I ON ARRIVAL*** (static) RAN 2.34 NO-GO CENT TO 2161' SLM. `RAN 2.34 NO-GO CENT & SAMPLE BAILER TO 2166' SLM (HYDRATES IN S- :BAILER) '`----FOUND HYDRATES IN TBG, UNABLE TO FINISH JOB---- "*"LEFTWELL S/I, NOTIFIED DSO OF STATUS""* 11/14/2007` T/I/0= 500/40/40 Hot Oil Treatment (Suspected Hydrates) Pumped 8 bbls neat ':;meth and 47 bbls of 180''F crude down Tbg. Tbg showed no signs of obstruction. .Pumped 6 bbls neat meth up flowline. Final WHP= 0/40/120. 11/20/2007"""CONT. JOB FROM 11/19/07 WSR*"" (d&t/ sbhps) RAN 2.34" NO-GO CENT & FLAPPER CKR ASSY TO 2159' SLM, APPEARS r FLAPPER IS PARTIALLY CLOSED. '':RAN 2.34" NO-GO CENT. W/ BRUSH TO 2159' SLM, BRUSHED FLAPPER AREA... APPEARS FLAPPER IS NOW FULLY OPEN. RE-RAN FLAPPER CKR, HAD A GOOD FUNCTION TEST...CONFIRMED ;FLAPPER IS FULLY OPEN. 33TAGGED TD W/2.14" CENT & S-BAILER C~ 12,034' SLM. (12,080' ELMD...btm ?,pert (~ 11,798', 282' of rathole)...RECOVERED SOME PC-TBG. RAN 2.14" CENT/TEV & PETREDAT GAUGES AS PER PROGRAM...RECEIVED GOOD DATA. _ **"LEFT WELL S/I O_N DEPARTURE, TURNED WELL OVER TO DSO""" 12/15/2007<TIO = 2240/2300/760. Temp = 40 deg. OART, post-seal-tite (eval IAxOA comm. AL on. POP , . r---. ~ . . ¡f"r\' t:~.>;,:¿ /r.-\ ::;-;:1 I~'r:' \..1 -: l' !! ,i ~) U (r\\ lllt ."No.. '--'OJ r r' \ f- \. . ¡ ". ,-~. lQJ J-" '-:', n ¡--" ,. ;~-ì n n ("~\ 'f"I Ii !¡.\[Iu!t'if¡'t.\ 1'\\\1 fi\\".~,.,IU-\!'\\ ffÙ Lb Li\J @ \i LfÙ ¡ ! ! FRANK H. MURKOWSKI, GOVERNOR / ./ ALAS KA 0 IL AND GAS CONSERVATI ON COMMISSION ./ 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 12, 2004 Mr. Bruce J. Williams GPB Operations Integrity Manager BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 I ?ih-It(¡;).- Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU Ll PBU L2 PBU L3 Date of SVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16.7% 50.0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part ofthe SVS. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13,2003, supported retention of the 10% failure threshold. Effective the date of SVS test, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to 'M't th SVS test. ~~onn~'ChaIT~ C~missioner Sincerely, ÇJ~ Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) "........, r----.. Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Ron White AOGCC Rep: Waived Submitted By: Ron Marquez Date: 04/2712004 Unit/Fie1d/Pad: Greater Pt McIntyre/Lisbume/L3 Separator psi: LPS 450 HPS 450 Illli~l.l1- _illá~ -. WII1lI~IrJm~1~f18lIð. -- Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L3-01 1890750 12/4/1993 S1 L3-02 1861540 450 350 350 P 6 P OIL L3-05 1851950 1/14/2003 SI L3-08 1831430 7/2/1994 SI L3-11 1852310 9/9/2003 81 L3-12 1861610 4/19/1997 81 13-15 1852660 12/22/1996 S1 L3-18 1861670 2/16/1997 S1 L3-19 1852860 11/17/2001 S1 L3-22 1861750 6/4/2003 81 L3-23 1853060 6/26/1995 S1 L3-24 1861820 5/12/1997 81 L3-28 1890660 9/7 /1993 81 L3-30 1861850 11/25/1996 S1 L3-31 1860340 7/28/2003 SI Wells: 1 Components: 2 Failures: 1 Failure Rate: Remarks: L3-02 4/27/2004: Grease crew notified to service SSV Page 1 of 1 SVS PBU LIS L3 04-27 -O4.xls MICROFILMED 9/28/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG / 1. Status of Well Classification of Service Well OIL ~. GAS [-] SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-182 3. Address 8. APl Number P.0. Box 100360, Anchorage, AK 99510-0360 50- 029-21670 4. Location of well at surface 9. Unit or Lease Name 870' FNL, 845' FWL, 5ec.22, T11N, R15E, UN Prudhoe Bay Unil;/Lisburne At Top Producing Interval 10. Well Number 2210' FSL, 1424' FWL, Sec.23, T11N, R15E, UN At Total Depth 11. Field and Pool 2065' FSL~ 1709' FWL, Sec.23, T11Nt R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ] 6. Lease D~ignation and Serial No. Li sburne 0i 1 Pool RKB 60'/ ADL 28323 Al K ?~21 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore ~ 16. No. of Completions 11/26/86 12/15/86 ~/19/R7- N/A feet MSL] 1 12141 'MD/9441~VD 120~4'MD/9400'TVD YES ~ NO ~ 7192' feet MD ~qnn, (approx.) 22. Type El~tric or Other Logs Run 23. - '- ................ ' ........... ' -~l'~,-['l~ ~ ~ ~ b~ ~'~fi h~-~c~ SETTING DEPTH MD CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED ~ ~n,, a~ ., .~.. .~ ,,u-"n ~ ~,e"-~, I~ ....... ~v 1700~ Pol ~.L ............................. Ill & sx :lass G a_~/~,, ~,~ n~ ,_on Surf I~"~6' 1~ ~/4 ..... ..... sx Cla~s G & 300 ~ AS ~", ~.~,,~ L-80 111~°'~ 121~ .... ~ I/2 ............. 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) Perforated w/12 spf, 0° phasing SIZE DEPTH SET (MD) PACKER SET (MD) 11538 ~ -11558 'ND/8923 ~ -89~0 ~ TVD 2-7/8" 11211 , 11125, .. 11562 ~ - 11602 ' ND/89~3 ' - 8977 ~ TVD -- ETc. 11620 ~ -11628 'ND/8992 ' -8999 'TVD 26. ACID, FRACTURE, CEMENT SGUE EzE, 11650'-1165~'ND/9017'-9020'TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 11670'-11698'ND/903~'-9057'TVD See a~ached we]i work iog (da~ed ~/i9/87) for 11722 ' -11728 'ND/9078 ' -9083 'TVD ~ d bre~kdown. 11738 ~ -117~2 ~ND/9092 ~ -9095 'TVD 11792 ' -11798 ' ND/9138 ' -91~3 'TVD , ,, 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) N/A DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS'OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl ('corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Non~ ~ ~ [~ - NOTE: Drilled RR 12/20/86. Tubing run 3/21/87. Perf'd well 6/9/87. Acid breakdown performed 4/19/87. Gas ,. ', gr~oh0rage /-y/ Form 10-407 Submit in duplicate ~ Rev. 7-1-80 107/WC5 CONTINUED ON REVERSE SIDE I . 29. . 30. " GEOLOGIC MARKERS. FORMATION TESTS : . , , ,, . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Zone 7 11518 ' 8906 ' N/A Top Zone 6 11585 ' 8962 ' Top Zone 5 11760' 9110' Top Zone 4 11878' 9212' Top Zone 3 12104' 9408' 31. LIST OF ATTACHMENTS Well work log (dated 4/19/87), Addendums (dated 3/20/87 and 3/25/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 (D.F, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any mUltiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. item 28' If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. ,~ Well Work Log Date' / . / I JoU cocle DS/Well ~cri~¢on of work SSSV n,,ple Mi.imum restrlctionlde,t~2.~ ~ "~ ~//¢a ' , 5,8" PSI,~ 113 3'8" PSI IDiese' rec°very v°lumeJFTPllTP+ ~O ISITP TBG~.T. ~es . SSSV Remarks Cost E~imate MC~: MC~: MC~: ' MC~: MC~: ~ MC~: DC~: DC~: DC~: DC~: DC~: DC~: Time Log entW ///~ ~~~ //~ ~ ~r~ /~. ~~ ' 7/~ P~/4 "' "'" / '.: ,, ~ ;'.,:..' 181o 00~ :~,..~ . Well Work Log i Time Log entry o~-~ ~o O~S~ ~ ~ro~ I~ 0133-o~ ~ T~ ~ o~ o.o.~. Signed: ~~/~~ Page ] of~ Reservoir Fluid Study ARCO OIL AND GAS COMPANY L3-24 Wel 1 Lisburne Field North Slope, Alaska RFL 870203 Litton Core Lab 1300 East Rochelle Boulevard P.O. Box 152053 Irving, Texas 75015-2053 (214) 570-5055 June 19, 1987 ARCO Oil and Gas Company 2300 W. Pl ano Parkway PRC E-407 Plano, TX 75075 Attention' Mr. Jerry Haley Subject' Reservoir Fluid Study L3-24 Wel 1 Li sburne Field North Slope, Alaska RFL 870203 Gentlemen' A subsurface sample was collected from the subject well and submitted to our laboratory in Irving, Texas for use in a reservoir fluid study. The results of this study are presented on the following pages. Thank you for the opportunity to perform this study for ARCO Oil and Gas Company. Should any questions arise or if we may be of further service in any way, please do not hesitate to contact us. Si ncerely, James R. Fortner Area Manager Reservoir Fluid Analysis JRF'KK'dr 17 cc' Addressee Litton Core Lab LABORATORY PROCEDURES ARCO Oil and Gas Company Reservoir Fluid Study L3-24 Wel 1 Li sburne Field North Slope, Alaska RFL 870203 Upon arrival in the laboratory, the reservoir fluid sample was transferred from the storage cylinder to a high pressure windowed cell where it was maintained at 5000 psig and 120°F throughout the following analyses. The hydrocarbon composition of the reservoir fluid was determined through hexanes with a heptanes plus residual fraction by low temperature fractional distillation, along with gas chromatography. The results of the distillation, in terms of both mol percent and weight percent, are presented on page three. A small quantity of the reservoir fluid was charged to a high pressure windowed cell and thermally expanded to the reservoir temperature of 182°F. During a constant composition expansion at this temperature, the fluid was found to have a bubble point pressure at 4075 psig. When subjected to differential pressure depletion at the reservoir temperature, the fluid evolved a total of 671 cubic feet of gas at 14.696 psia and 60°F per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.315 barrels of saturated fluid per barrel of residual oil at 60°F. The viscosity of the reservoir fluid was measured over a wide range of pressures at 182°F in a rolling ball viscosimeter. The viscosity of the fluid was found to vary from a minimum of 1.20 centipoises at the saturation pressure to a maximum of 5.04 centipoises at atmospheric pressure. Four separator tests, (one on the original reservoir fluid and three on DV prepared oils) were performed at specified conditions. The results of these separator tests are tabulated on pages six through nine. -1- -Litton Core Lab Company Wel 1 ARCO Oil and Gas L3-24 Company Fi el d Lisburne FORMATION Formation Name Date First Well Completed Original Reservoir Pressure Original Produced Gas/Oil Ratio Production Rate Separator Pressure and Temperature Oil Gravity at 60°F Datum Original Gas Cap E1 evati on Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoir Temperature Status of Well Pressure Gauge Normal Production Rate Gas/Oil Ratio Separator Pressure and Base Pressure Well Making Water WELL Date Sampled Sampl ed at Status of Well Gas/Oil Ratio Separator Pressure Tubing Pressure Casing Pressure Sampl ed by Type Sampler County State Page File 1 RFL North S1 ope Alaska , , , , CHARACTERISTICS PSIG @ of 870203 2O PSIG CHARACTERISTICS In. to Bbl/D/PSI @ 4233 PS I G @ 182 °F @ Ft. SCF/Bbl Bbl/Day oF °API Ft. Subsea Temperature PSIG, Ft. Ft. Ft. Ft. SAMPLING CONDITIONS Bbl/Day 11582 Ft. and Temperature PSIG, Ft. Bbl/Day SCF/Bbl oF PSIA % Cut Ft. SCF/Bbl oF PSIG ARCO PSIG REMARKS: The analyses, opinions or interpretations contained in this report are based upon observations and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. Core Laboratories, Inc. assumes no responsibility and makes no warranty or representa- tions, express or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other mineral, propelty, well or san(] in connection with which such report ~s used or relied upon for any reason whatsoever. ,Litton Core Lab Page 2 of File RFL 870203 Wel 1 L3-24 2O Summary of PVT Data - Properties of Bubble Point Fluid Bottom Hole Sample Bubble Point Pressure 4075 psi g Reservoir Temperature 182°F Thermal Expansion of Fluid at 5000 psig Volume @ 182°F Volume @ 120°F 1.03189 Density at 4075 psig and 182°F (Experimental) Viscosity at 4075 psig and 182°F 48.63 Lbs/CF 0.338 PSI/Ft 1.20 Centipoises Primary Separator Gas/Oil Ratio Stock Tank Gas/Oil Ratio F1 ash Gas Solubility Differential Gas Solubility 616 SCF/STB 62 SCF/STB 678 SCF/STB 671 SCF/STB Flash Formation Volume Factor Differential Formation Volume Factor 1.316 RVB/STB 1.315 RVB/RDB Separator Conditions for Flash Data: Primary Separator: 250 psig and 150°F Stock Tank: 0 psig and 180°F Terms used in report SCF = Cubic feet of gas at 60°F and 14.696 psi a STB = Barrel of stock tank oil at 60°F and 14.7 psi a RDB = Barrel of residual oil at 60°F and 14.7 psia from differential liberation RVB = Barrel of fluid (gas or saturated oil) at reservoir temperature and pressure Litton Core Lab Page File Wel 1 3 RFL of 870203 2O L3-24 HYDROCARBON ANALYSIS , OF RESERVOIR FLUID SAMPLE · ,. Mol Component Percent Hydrogen Sulfide 0.00 Carbon Dioxide 8.83 Nitrogen 0.29 Methane 43.51 Ethane 3.95 Propane 2.13 i so-Butane 0.37 n-Butane 0.90 iso-Pentane 0.34 n-Pentane 0.45 Hexanes 1.40 Heptanes plus 37.83 100.00 Weight Percent 0.00 3.22 0.07 5.78 0.98 0.78 0.18 0.43 0.20 0.27 0.97 87.12 100.00 Dens i ty, Gm/Cc @ 60°F* 0.8006 0.8172 0.8086 0.2997 0.3558 0.5065 0.5623 0.5834 0.6241 0.6305 0.6850 Molecular Weight* 34.08 44.01 28.01 16.04 30 .O7 44.10 58.12 58.12 72.15 72.15 84.00 Measured Physical Properties'** Heptanes plus Average molecular weight = 120.73 *Assumed values. **Adjusted for light components found chromatography. Density, Gm/Cc £a 60°F 0.9118 in podbielniak °API @ 60°F 23.5 resi due as Molecular Weight 278 analyzed by capillary Litton Core Lab Page 4 of File RFL 870203 Well L3-24 2O Pressure, PSIG 50OO 4500 4400 4300 4200 4100 4075 3000 2000 1000 Formation Volume Factor, RVB/STB TABLE II FLASH PVT DATA Total Gas in Solution, SCF/STB Solution Gas in Sep. Liquid SCF/STB Stock Tank Oil Gravity, °API@ 60°F 1.305 678 62 24.7 1.311 678 62 24.7 1.312 678 62 24.7 1.313 678 62 24.7 1.315 678 62 24.7 1.316 678 62 24.7 1.316 678 62 24.7 1.251 505 66 24.7 1.196 350 68 24.7 1.139 189 74 24.7 Separator Conditions for Flash Data: Primary Stage: 250 psig at 150°F Tank Stage: 0 psi g at 180°F ,Litton Core Lab Page 5 of File RFL 870203 Wel 1 L3-24 SEPARATOR TEST OF RESERVOIR FLUID SAMPLE 2O Separator Gas/Oi 1 Pressure, Temp., Ratio PSIG °F (1) 250 150 578 to 0 180 59 Gas/Oil Tank Oil Formation Separator Ratio Gravity, Vol ume Vol ume (2) °API@ 60°F Factor(3) Factor(4), Gas Gravi,..ty 616 1.065 0.772 62 24.7 1.316 1.051 67~' 1.155 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 4075 psig and 182°F per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. Litton Core Lab Page 6 of File RFL 870203 Wel 1 L3-24 2O SEPARATOR TEST OF 3000 PSIG DV OIL SAMPLE Separator Gas/Oi 1 Pressure, Temp., Ratio PSIG °F (1) 250 150 411 to 0 180 63 Gas/Oil Tank Oi 1 Formation Separator Ratio Gravity, Vol ume Vol ume (2) °API Ia 60OF Factor(3) Factor(4) Gas Gravity 439 1.067 0.798 66 24.7 1.251 1.051 5O5 1.195 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 3000 psig and 182°F per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. .Litton Core Lab Page 7 of File RFL 870203 Well L3-24 SEPARATOR TEST OF 2000 PSIG DV OIL SAMPLE ~ ...... · ,, , ~ ,, 2O Separator Gas/Oi 1 Pressure, Temp., Ratio PSIG °F (1) 250 150 264 to 0 180 65 Gas/Oil Tank Oil Formation Separator Ratio Gravity, Vol ume Vol ume (2) °API@ 60°F Factor(3) Factor(4) Gas Gravity. 282 1.068 0.824 68 24.7 1.196 1.051 350' 1.212 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 2000 psig and 182°F per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. ,Litton Core Lab Page 8 of File RFL 870203 Well L3-24 SEPARATOR TEST OF 1000 PSIG DV OIL SAMPLE __ __ 20 Separator Gas/Oi 1 Pressure, Temp., Ratio PSIG °F (1) 250 150 107 to 0 180 70 Gas/Oil Tank Oil Formation Separator Ratio Gravity, Vol ume Vol ume (2) °API@ 60°F Factor(3) Factor(4) Gas Gravity 115 1.071 0.862 74 24.7 1.139 1.051 189" 1.272 (1) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of oil at indicated pressure and temperature. (2) Gas/Oil Ratio in cubic feet of gas at 14.696 psia and 60°F per barrel of stock tank oil at 60°F. (3) Formation Volume Factor is barrels of saturated oil at 1000 psig and 182°F per barrel of stock tank oil at 60°F. (4) Separator Volume Factor is barrels of oil at indicated pressure and temperature per barrel of stock tank oil at 60°F. ,Litton Core Lab Page 9 of File RFL 870203 Well L3-24 2O Relative Pressure, Volume PSIG V/Vsat.(1) TABLE III DIFFERENTIAL AND TOTAL VOLUME PVT DATA Differential Liberation at 182°F Gas Formation Gas in Conversion Liberated Volume Factor, Solution, Factor Gas Gravity, RVB/RDB SCF/RDB SCF/RVB (Ai r=l.000) 5000 0.9916 1.304 671 4500 0.9960 1.310 671 .... 4400 0.9969 1.311 671 4300 0.9979 1.312 671 4200 0.9989 1.314 671 4100 0.9998 1.315 671 .... 4075 1.0000 1.315 671 3600 1.0244 1.285 594 3200 1.0538 1.261 531 -, 2800 1.0957 1.238 468 2400 1.1574 1.214 405 2000 1.2528 1.192 345 1600 1.4089 1.169 282 1200 1.6929 1.147 220 800 2.3017 1.124 157 400 4.2166 1.099 89 ...... 138 11.1307' 1.077 41 0 1.052 0 Calculated Gas Vi scosity, Centi poi ses(2) 1246 0.755 0.0235 1106 0.753 0.0219 968 0.750 0.0203 829 0.748 0.0187 690 0.749 0.0172 552 0.750 0.0157 412 0.764 0.0143 273 0.791 0.0129 135 0.856 0.0119 46 0.989 0.0112 1.162 .... Gravity of Residual Oil = 24.6°API @ 60°F · *Extrapolated (1) (2) Relative volume, V/Vsat. is total volume data for constant composition (no gas removal) expansion of bubble point fluid at 182~F Gas viscosity data calculated from gas gravity and using method of Carr, Kobayashi and Burrows: AIME, 1954, Vol. 201, p. 265. Litton Core Lab VIscOSITY DATA AT 182°F : .~ ~, . ~ ~, ,, , ~, ....... Page File Wel 1 10 RFL L3-24 of 870203 2O Pressure, Oil Vi PSIG Cent Calculated Oi 1/Gas scosity, Gas Viscosity, Viscosity ipoise Centi poi se (1) Ratio 5000 1.30 480O 1.28 4600 1.26 4400 1.24 4200 1.22 4O75 1.20 1.31 3200 1.41 2800 1.54 2400 1.70 2000 1.89 1600 2.13 1200 2.45 800 2.86 400 3.59 138 4.21 0 5.04 0.0235 55.7 0.0219 64.4 0.0203 75.9 0.0187 9O.9 0.0172 109.9 0.0157 135.7 0.0143 171.3 0.0129 221.7 0.0119 301.7 0.0112 375.9 (1) Gas viscosity data calculated from gas gravity and using method of Carr, Kobayashi and Burrows: AIME, 1954, Vol. 201, p. 265. Litton Core Lab Page 11 of File RFL 870203 Wel 1 L3-24 20 Pressu PSIG Formation Gas in Gas Conversion* Saturated Free re, Volume Factor Solution Factor Oil Compressibility* Gas Compressibility* RVB/RDB SCF/RDB SCF/RVB Bb 1/MMBb 1 s/PS I Bbl/MMBb 1 s/PS I 4075 1.315 671 3875 1.302 637 1345 52.3 275.5 3675 1.289 606 1270 54.9 283.9 3475 1.277 574 1200 57.6 291.6 3275 1.265 542 1134 62.5 303.8 3075 1.254 511 1062 70.8 324.3 2875 1.242 479 995 81.2 349.2 2675 1.230 447 925 93.1 377.0 2475 1.218 416 854 106.0 407.7 2275 1.207 386 785 119.9 441.2 2075 1.196 354 716 136.4 481.6 1875 1.185 323 647 156.4 533.8 1675 1.173 292 580 183.9 603.1 1475 1.162 261 506 221.6 690.3 1275 1.151 231 438 270.6 801.8 1075 1.139 201 368 332.6 951.5 875 1.128' 180 297 419.5 1173.8 675 1.116 137 228 552.1 1533.6 475 1.104 102 158 803.0 2208.1 *Data calculated by Mr. Jerry Haley based on differential vaporization data supplied by Core Laboratories, Inc. Page 12 of 20 File 870203 Well L.3-24 TOTAL VOLUME BY CONSTANT COMPOSITION 2.4 2.2 2.0 i.8 i 6 i,4 i,2 l,O 0.8 0 EXPANSION OF BUBBLE POINT FLUID ' I-i : , ! I / : --~--r % ' . ' aL- -?~--?. ,.-~.. -~ . _~ .... ~- !~]-~--.I ~ '"~~r'~ ~.-~-4-!-]-~]--~-'?-~'-' ' llil,!, ; ' ': '' '' I ''~ .... ~ ~.e~--~-.~~_ -~"--*- :'; .... r%~d~ ~,~, ..... ~_~+_...,_~._~...~r,.~..,~_.~% I',, i~ i ~[ ' ' ' i i~i I ; ~ '""J-'-~1%' ' ~' '~ ' ; ~ ++., ........ .,~ ~..~.t.._~_,.~.~_~.~ :T~i i. !~ .~.L..-4~'~q~e~-'-e~'~-~'w'i~-k-I '' .... ' ' ~' -x-4~--+-.~ ?!~~:~:~--i t~.Th :':~: -~-~* +-'¥';'-? .... ~'-: .... ;"~"~- ~.~: ?--,.-.,--~--?.~-?~-.~-.~.-,---~-,,-,~ , . .,,., · iM ¢_LJ_~.i '¥~ ~- ~ I ~ ~ , ~ ~ , I ~ ~ .... , . ...,..~. ._.~. ,~_;_~.~$I: : ~._.,.~.~..,- ~ ~,-~ +-*.~ ~.+-,--~.4 ..... -~.+,-~-~ 4--~+--+-.~.-1-?.~--~-~-r , , :~~, ,~,. _.~ _~_+__~ .... ~ ..... t-~-:~t '- · . . _.~ ~_ L~__H..~_. illl .... --r--~-,?-~ iT'r-,- i-d,-~-i-i-'~'~--+~'~'~'*'" t I i, .i.i III ~ ~ i ~ I, I ~ (!. ; :I-~-~:~~~: +~ ..... ~_.,~ _ _ ~ ~5~:~---~-~-~-~--~~_'-~-~-~.~--~-~ .... ~~7~d"i"i i ~ ~ i ~ L ~j~ ~'-~-~~~~ I 1 i i ~ i ~ ~ ~ i~ ' ~ ~ t~ ],t~ ~.%~_L4 J~ I t t t J.i,.] [, [ I ! I i I I I ~ I~ ~..~,~..~ ~ ,~ lO00 2000 3000 4000 5000 6000 PRESSURE, PSZ6 Page 13 of 20 File 870203 Hel) L3-24 OIL AND GAS COMPRESSIBILITY ~0000 t000 lO0 lO 1000 2000 3000 4000 5000 8000 PRESSURE, PSIG Page 14 of File 870203 Hel~ L3-24 2O FORMATION VOLUME FACTORS 1.40 l .35 .30 .25 1.20 1.15 1.10 l. O0 ~t i ,. ~ i. ,., .j~ :' ,, ,/ ~ .... ~ .... } ~ LEGEND ~ ~g~fferen~a~ MB~B: RVB/RDB ~" --~--F~ash da~a: RVB/STB .SEPARATOR CONDITIONS: 250 ps~g ~ ~50°F "' 0 ps~g ~ ~80°F 0 lO00 2000 3000 4000 5000 6000 PRESSURE, PSIG Page ]5 of 20 File 870203 Well L3-24 RATIO OF FLASH TO DIFFERENTIAL FORMATION VOLUME FACTOR, RDB/STB & O3 ~ IIIII IIIII Ilil IIIII III IIIII IIIII IIIII It111 IIIII 11111 IIIII II111 I1111 II111 I I I I I I.I Ii I "l~i iii~~ ~ IIIII IIIII ~! IIIII IIIII IIiil Illll III!1 Illll II1|1 II111 IIIII IIii IIIII IIIII III!1 III!1 IIII1 IIII1 IIIII I1111 IIIII IIIII III!1 IIIII IIIII IIiil IIIll IIlll Illll IIIII Illll Ilill Illll Illll III!1 IIIII Ilili Illll IIIII IIIII Illll IIIII IIIII IIIII IIIII IIIII IIIII IIIII III!1 IIiil IIiil IIIII IIIII IIIII It111 IIIII IIIII IIIII IIIII IIIII IIIII IIIII IIIII IIIII IIIII IIIII IIiil IIiil IIIII IIIII IIIII Ill|l 1 O2 rr I O0 f~ "" 0 99 u._ 0 98 0 §fi O. fl5 0 lO00 2000 3000 4000 5000 6000 PRESSURE, PSI6 Page File Well 16 of 87O2O3 L3-24 20 lO00 900 8OO TOTAL SOLUTION GAS SOLUBILITIES AND GAS SOLUBILITY IN SEPARATOR LIQUID LEGEND -~---Differential Data: SCF/RDB ---~---Flash Data; SCF/STB .... ~.... Gas in Separator Liquid: SCF/STB SEPARATOR CONDITIONS: 250 pslg @ i50eF 0 psig @ ~BO°F 700 _.1 z .J 600 500 400 300 200 iO0 0 lO00 2000 3000 4000 5000 6000 PRESSURE, PSIG Page 17 of 20 File B70203 Well L3-24 iO "DIFFERENCE" BETWEEN DIFFERENTIAL AND FLASH GAS SOLUBILITY, SCF/STB m ._! -5 -iO 0 lO00 2000 3000 4000 5000 8000 PRESSURE, PSIG Page ]8 of 20 File 870203 Hell L3-24 GAS CONVERSION FACTOR 1600 1400 i200 ,, lO00 0 ~_) b_ Z o Z II11 IIIII IIII III!1 IIII IIII ! IIII1 III IIII IIII Jllll 1111 , , , II11 I I t111 IIIII III11 IIII IIII IIIit IIII k IIIII IIII · ~ II 11 I II Il IIIII IIII III!1 IIIII Iltl IIIII IIII III! IIIII II11 ! I' 11111 IIII IIIII IIII 1111t IIII IIII I II Ii llllj IIii tl II II II IIIII II11 IIIII IIII IIIII IIII IIIII IIII ! I I II I I I II ~' I III I II III IIII1 . II II J I/I II II IIJ J'l II II II I /1111 I I I I I ,iii I I ! I I I I I /' I I II IIIII ~ IIII I IIII1 r III1 L III!1 ! 1111 IIIII ~' i ' L II II II Il II I I I I I/' I I I ! I I h/! I IIII I I,~'i I I I I! II~ll I IIii L i/'1 II I I I Ii ~IIIII IIii rllllJ I IIi! I IIii , IIII I ,~ III!1 III! .! I I I I.I I I I I li~' I I II I I I Ii ~" IIII IIII Ii IIII1 IIII _ IIIII IIii 800 600 400 200 0 0 lO00 2000 3000 4000 5000 6000 PRESSURE, PSIG Page 19 of File 870203 Well L3-24 20 FREE GAS GRAVITY AND VISCOSITY LU Z O.g 0.8 0.7 0 lO00 2000 3000 4000 5000 6000 0.03 0.02 O.Oi 0.00 0 PRESSURE, PSIS lO00 2000 3000 4000 5000 6000 PRESSURE, PSIG Page 20 of File 870203 Well L3-24 20 OIL VISCOSITY AND VISCOSITY RATIO UJ u cO 6.0 , 4.0 3.0 2.0 i.O 0.0 0 lO00 2000 3000 4000 5000 6000 400 PRESSURE, PSIG 3OO 2O0 lO0 0 0 lO00 2000 3000 4000 5000 6000 PRESSURE, PSIG January 8, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 360 Anchorage, Ak. 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60097 Well: L3-24(SEC22 TllN R15E) Lisburne Field North Slope, Alaska Survey Date: December 24, 1986 Operator: Mcguire Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard Western Area Manager Enclosures NL Sperry.SunlNL Industries, Inc. P.O. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 L I SBLIRNE ALASKA · . ~, ~,,.. · ~ VERTIUAL ~,EC SF'ERRY-SUN WELL.. SLIRV, EYING L. LMFANY PAGI DECEMBER 29~ 1'-'-' .-.~,_-,6 JOB NUMBER AK-BO-6t . KELLY BUSHING ELE~ OPERATOR-MCGU I RE MEA.:.i_ RED VERT I CAL ~ I NCL I NAI" I ON D I REF:T I ON SEVER I TY REL. 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L I .=,B _IRNE ALASKA SPERRY-SLIN WELL..=,_IRVEYING COMPANY DECEMBER · ...'*, 1986 dOB NUMBER AK-BO-6 KELLY BU.=,H I NG L F ERAT JR-Mt.:.t.:~U I RE 'I'RUE ME~:.'-:;LI REL] VERT I CAL I']EF'TH E E.F 1 H SEA TOTAL I CAL REL-:TANGULAR COORD I NATES; MD-TVD VERT I CAL DEPTH NORTH / SOUTH EAST / WEST D I FFERENCE CORREC:T I ON · ~!L~*~ ' :: ,~, " . ~ ··. . ,.. >::.: 4177 ~ ,~,60. C}0 ~,~00::, Q~.::..... 4:328 3'? 60.00 :3900 ....... 00 481 9 ::: S 974:=,-' ~:- E '-'=, 6,=,.'-' '? 1 :._, 1.61 46:38 4160, O0.. .......~"i ~50 . O'"~O .......................... :"'~ ;:~., .-, ~ ........ *',":~ ....... .",:=: .......... 1' ..... 1 ;~'~ 7 ...., .~;';,,~ ...... E: 2~ ...... 7,',.~:" ................................................................................................................................................................................................... 1A 56.06 ~ -- . 4797 4':,AC}. 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E . ...:'.:::..:: .6~:8:~:'.~:~...: :'... ::' ::.':: :.:::...:: ..:~0 ,: ~,~.:::: :::.: ..::.. :..:::::..:.:' .: ::.. ::::::::::::::::::::::::::::::: : ': 79 4560 ('~ O 4._, (.~ O 00 7:3 ....... ~:,6._, 06 E 71..26 60.84 ' ::.:~.:~ 47~::(:"~"¢~'C:_ _ .................... 4'?'b"b': .~,7 .,0 4:, :.0. oo $~ . . .::::::: :~.., ....:: ~ ... ............. ::.:.. ............................................................ >.......< ............. ~....<~ ..................... ....,. .............. 6224 5160.00 5100.00 969.24 S 2:357.62 ~ 1064.56 51.43 6376 :2 ............. ~::'~'~-:'"<~'<~: ............. :'~'~'~;E"~:~ .................................... / ~'-' ¢ 5360 00 ~ ::: 0 (') 00 1027 ¢''-' :,.-,~: ......... =,~ S 2575.61 E 1166.16 49.91 ~7};<:. :.:.' :.. :.:.'. ;~:: :~ ~.~ (~:,~(~0 :::: ?.': :::.?~: ::~:;::;;~)~:~;::::(~A::.:::~:::~::; ::::::::::::::::::::: .. SF'ERRY-;::UN WELL SURVEYING COMF'ANY L L. I SBURNE AL. ASKA DECEMBER '?':/, 1'-'--' ... yo6 ._lOB NUMBER AK-BO-60 KELLY BLI._-,HING OPERATOR-MCi I RE TRUE TOTAL MEASLIRED VERT I CAL VERT I CAL RECTANGLIL_AR COORD I NATES MD-TVD VERT I CAL ]-'~' "' ' F DEPTF! DEPI"H L E.F TH NORTH / SOLITH EAST/WEST D I F F EREN_.E CORRECT I ON · :<' ':'.: ' :':.? :. ::=i~:~:!:~ -..: -: ,' ::.:,:.::?:!?'/!": .......... ~"::::::!i:~!.:!:!'! · '::: :!:!: .]~:~ :. ':~::?::!:'. ......... i~.:::.:-: ::' ':~. ',: c.:' ....... ~::<::: ~-:i ~)~': =' =:'i' :':-~':~!::~:~::::~'::!:~!!:iF~:~[<:~:~:~i:~:: · : · ..... : : . . : ~.. ... . :.: .::. :, ,:: : ::.......,: ~ . · · · .~: : .::..:. :~. ~" :~:::-" .~ ...... ~t' ::: ..... *~* · *'~- ~ ':: .... :,:~<: :: :, .: :. · :.:::::: ;:;:, :~.,. '::.~:::..' ........ . ::~::::~' ':~.,':::L;.~:=:::::..:::~: :' :~.: :~ ,,.~:~i: ~:' `:~::~:~::F:~:~)~;:>:~b)~t~:;~i~E4:~:~<~:~:~`~A~li~:;~:ss~¢~ ,' ..' 6973 5660,00 ........ ' ..... ' ~ ....... 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"'"".:::':':~'::i: !"<:~"'::?:i:~: ~ ~ _") ). ) : :: :~':.~ : :.~ '~::,~: ~:.~. :.,~..: :?: ': ~ ' : ::..,: ~ ~ ~:..~ ~:.::.~ '~:::::.::. :~:::::::::::::::::::::::::::::: ~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 'iii::ii:i?'? ::f:::~ii~N~i~i~.':':ii~iiiiiii::!~i~!i~]~i~$' .~i"'"~:~i.:~$~ ':7930 7660, O0 ' : ' ' :: .... ' : : .... :" .... :" ...... .~ (~) (:) ~:i '7 7760. O0 7700. O0 1 I978. 14 S 50:34. 18 E 2:307.70 37.63 10:3:37 7960. OC) '7'?C)C). O0 19:35.26 S 5'205.5:3 E 2:377.24 :3:3.54 · .., ~ .. .,.....:.. ,:::,.:.,,>;,,:,,..: ............ ,.-.,-,, · ~ · ::,.,.-:..,.:-:....-:..:.:::.:......-m:: ========================================================== ~-; m - , ~ - . . ~ ~ ~ ~, ~ ~ ~ ............................... 10467 o0~O 00 o000.00 1963. I0 S; ~'~ c~ ~"-- ~407,:.~i ')- '-"-' ':'"" ' 201 ~. 80 S '=' :' 1C 7~.z, A2AO O0 00 . ,~,=.: ;~,'~ ~::" .... ~,ZOO, .. ~ ~, 2~'..E . .... ~om~, ~ ~:~, .~,~ ....::. :..: ::: .:. =========================================================== 10:349 8360.00 ::: .... ::: 00 . C)0 20 ~ :3 . i 2 S: ~ .... ~,,.'') ~.~ 09 E 24:39 . i 1 ~'~ :~,. ~'-'...."::' ~,, ............... ~. t::.:: E ~._ 1 68 2 ~ ~ 7 110'?-7 ::: P]/-. (') 00 :E: 500. F) 0 2104 1 ':~ ':' ._,o.:, ;= ' '-":~ 7.5 E "5'-' . ~ .... :,7 20 t . ~ . ,~i i 11219 8660.00" · 8600.00 '~": ........ .... ~":' "~:~:" :' "'::':¥ ~ :'"":~:"~: ':: "':':: :"::~::' Z ! ~ 1. :~::::~ !:: ~,'.: '.::': ...... :,7( 4.,:?.~:: ========================= :. :...: :::::::::::::::::::::::::::::::::::::: :::'::::: :::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .':. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ '~.'::. ::' ~- ~ · ~' :: :-,.- ..::.>:::: =========================================== :.~: .:::.::::: ,::, :. ::.:r:::.:: · ::::::::::::::::::::::::::::::::: :: .:-..::::.: ::::::::::::::::::::::::::::: ~ . :..:.: .::~j , ~ ....... ::::::::::::::::::::: ====================================================================== .:...:..,.,::::::~.:-,. :>::. .-, oo ,..,,,,,. ...... 11P iA2 :3'F'60. C)O :R 'T, (') (') ..... OC) 2215 A't S ~'-":~'o ~ 0 ;,'-'=.J E '"~'~"-' .... ' · - '- ' ~ -'~ ' I 17C)1 ':/OAF). OF) ~/(}AO. OF) 224~. F)1 S 5947. 18 E 2641.00 i 1 :~ 17 9160.0o :-~ 100.00 2:71.80 ~ 6001.64 E 2657. ::~:::::~:: .: :.::::::::~.?~:~:.','::~. · ':::~::,.::~:... ~.. ~::. ..................... ~::.~. ::.:.:,:~::~:.:::.=.,~::::.::.~f~:~::~:~:...,¢~.-.-.: ~..~.... ~:~:~ ~:...~,~:~'.~:, , ~...,.~ ......... ~~'-' ........... ~ ............. ,.::.::.:::.~ ..................... ~::~.:~ . ~ .... ~ ........ ~:~ .... ::.:':, ,., , .~ ..: ,.::::::: , : .: '::":~:::~: .:::::::::.::: :: ::: :~:::~ :::::::::::::::::::::: :::::::::: ::::::::~::::::::::: ::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::: ::: ::::::::::::::~::: :: ::::::::::: ::: .. :::::::::::::::::::::::::::::::::::::::::: ::..:..: . .,~.. ' ::?':' :::.. :' : :i ::::::: :: ::: ::::: :::::::: ::::::::::::::::::::::::::: ~::::: :::: ::::'ii::: ::::::::::::::::::::::::::::i:i i :::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ============================= ....... ====================================================================================================================================================================================================================================================================================================== == ============================================================================ ..... :~,: · .// SF'ERRY-SLIN WELL. SLIRVE~ L I .:,B JRNE ALA:::;KA DECEMBER 29, 1986 dOB NUMBER KELLY BU~_-.HING OF'ERATOR-MCGU TRUE TOTA MEASLIRED VERT I CAL VERTICAL RECTANGLILAR COORD I NATES: MD-TVD VERT I CAL DEF'TH DEF'TH DEPTH NORTH/S:OUTH EAST/WEST D I FFERENCE CORRECT I ON '' ~'::' :::.~.]:: · :. THE NEAREST 2C) .F.O.!?.?.. MD .............. , . . ::..:,::::.: ::..: ............................. ........ ================================================================================= ============================== .............. ::::::::::::::::::::::::::::::::::::::::::::::::::: ............. ....::~:.:.::~:::::::::.:::::~:::..~:~.:.:.~:.:<.>:x:~:::~:~::~:<~.v>:~.:~:.:.:.:~::~::~:~::.:::>~..~>J::::.::s:.:~.:.::~¢r<:~:~.~:~.~::~:~[*~:~:~n~:~:~~~¢~:~g~g~*:~g~:~¢~¢~:¢¢::~:::~¢~:~¢¢~::~::~:~:~:~:.:~.~:~.~:~s~:~:~:¢)~::~}~5~:~¢:~[s}~i~:~: _ SPERRY--F:;LIN WELL SURVEYING COMF'ANY L. I SBURNE DECEMBER 2~ 1~86 JOB NUMBER KEI_LY BUSHING ELEV ~F ERATu MEASLIRED DEF'TH ]"RUE SEA TO TAL -', i I CAL. VERT I CAL RECTANGLILAR C:F~ORD I NATES I- ' i"' ' '-'- '-' '/ DEPTFI r EF TH N..IRTH/.=,uI..ITH EA.:,'[. WEST MARKER I ]1. ~"':"~ ,r,9~,,-, .":,,"~ =,~¢,)~,. ..~.~.'.i~ i~... ..:.' ~.~ t~. :. ~ ' ~', :. :: .'~, ~'. : :: ~:~ ' ,':':' ' ~:' :~".:. '.:'::~':::';:.'-:: ". ................ · .... :"~ ....... ~.:;¢~-~ ~.~ .... · ....... ~ ....... ~* ............. i 176o_ 91. 10_. 19 ..... 90~0. 19. ~=.._o.'-":'~'-' ?7 S ._.~974.87 E TOP ZONE ._~ ]. ].c, /'-' ~ '""c, ';":~:'.. ~1 ................................. 1.71 ~2)"""~1.. 1._ ............................................................ 1.71 ~;ff~:i;~5~""'"";~;',. ~:7 ........... .=,;~: ............................... 6Ozc,.*"':~'~=~'"'"';~/~; ._, .......................................... E TuF='"~ ............... ZuNE= .................................................................................................................................................................................................................... 4 ...... ~ t ? o'o .?? 36. '73 ............... ,;;'~"? [:~":' '?'~ ......................... ~'2:~*'i)"~"'~:':~-~" "i~ .................... ?J;'~E~ii~: ': ':~ 6 ""E .............. SiJ Rg'~'Y"'"'~i'EPT'[:i ................................................................................................................................................................. ..... :, · .,..:~._ ~, ~,~, 2~':;I ~'D:~ '~;::'~¥:':'; "?':~'¢:~ : :'~' :'"' : : ....~ ':"il'"i ' ' 's /;:":'"::::":'i:?''; :'":": '¥";;':':"' ::??:~:";:'~'":':"': :~: :::::::::::::::::::::::::::::::::::::: '::]?::':"" ':::.'¥"::::'::::?'"?':'"/.;'::"~??.'?:~:;;~:~:??~:~:!:~(;:]~¢i~]~;~ .%~.%~ ~ - ~.: & ~.. .,~ :. :.. , .:: ~ .... ~ ~ .: , . .... ;:...: ~: .:::, ~: ,:.:: ,:: .... : :~ .~?/:::.:;:;~::;.:::~x::;~::~¢::;(~¢:"- ~I~' ':'~ 12104 ':¢ '* P'=' '='"' '" ' . .,.,~, ~,45. z4 z, ,. 614¢:..7,~: E .:::;:::: :. ....... I:IER]:VE£1 U.':-;INi:~ OIL ]:lEI:TH.-, AND :_-';PERRY ol..Ixl .",URVEY riATA TOP ZONE '7 11518 ...... :':: T 0 P Z A N E: 6, 11 ~ "-' '-= ::~'P 6, 2.2:3 ':":~ ~") ":' ':"' '-" .......... 23 ~. 16 ~('):~; 58'.:/1 64~. TOP 7..~NE o I176'0' T O F' Z 0 N E .:, 12104 '.::'~ 408. :'::(') '- '-' '-' - · ,-'..:,._'~ 6. '-' ~. :.~._',4o. :2:(.') '"'"'-' ._ . TOTAL DEPTH DRILLEK 1~:141 .~44(.).._,o : .. -:... · . ' ~ . . .. :::: ~..:~.:..:.:.: ~::..:.'r' .:::.:..:: :.:...::::~::x: . ~.~ · :..:...... ~ :.. · :.' ':- . .~' .:...:::-.:..:.;.:.: ................... . .:......:.'..:~::::::'..':.:':.;.~ ..:; :::.: ......... '.: :'...: ::'.x'.:~?: .,.:~.'.~.-.-'~".':'~:~ · ~.~ . ..- :~:.p..,~... ...... x:;:-'~'~ ........ ~-~:~ ......... ~ .... ~ ~:. ~:~ · ,:~;!~ .... .~. . ~.;~;t&?~:.,~.~:~;~:...:~¢~4~ ..... ~.:?.;'.c:c::..~:::::~:~::~;~?:::;:.::~;~::::~. ::: :.~::: :::: :~::~.~:~: ~"~4~;~:~:~:~'~~ ':~:~:~;:~4~:''~¢~$~:::~:~ :~:::~':¢¢':.. ... .. ~.:: __ ~ ~ ..:.::,..::.~:~ ".~'"":~:~:~:.~:.¢'¢<'~'a~:~.'"'","~:'-:~;~;~;~:~h~ ':~t~:¢~¥~~:~::::~:''': '~: ":~:~::'":~:'"':~(:~ .... :~::~.~ :~.~j::;:~::.::.~:::~:~::::~:~- :~¥:~:::;.~:~;:~s'~ .... ' '::. .............................................................................................................................................................................................................................. ,;~ .-~_4~ ......... : ................................................................................................................................................... .......... . "RUE NOPI'Iti $C~L.E ~-- ~ INCH TO 1000.00 / ~000.0 I.]S8dBNE qRCO ~L~SK~, [3--24~5EC22 'IIiN RISE) OECEMBE8 24, ~K-80--60097 INC. 1986 I ~-3000.00 PROJECTT SPERRY -SUN $CRLE ;- INCH TO 2000.00 / 2000.0 LISBUBNE ARCO RLRSKR. OECEHBE8 24. L3-24(SEC22 71iN 8!5E; QK-80-80097 2000.00 4000. OO 6000.00 8OOO, OO IOO00. O0 L. 12141 't i 2000, CO 4000. O0 6000. O0 80~30. O0 INC. [986 ADDENDUM WELL: 12/25/86 L3-24 RU DA, rn Boss gyro f/12,000' - surf. Rn CBL f/12,084'-9800' w/0 psi & 2nd rn w/1000 psi. Drilling Supervisor Date ADDENDUM WELL: 3/12/87 L3-24 RU pmp to tbg head vlv, press up to 3000 psi (8 bbls diesel). Tst good. Drill'ing Supervisor ARCO ALASKA LISBURNE ENGINEERING DATE: 5-31-89 FROM: TINA KINCAID ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: FINAL FOR L2-24 COLLAR LOG DIFF TEMPERATURE LOG GAMMA RAY PERFORATING RECORD RUN I 4/30/89 RUN I 4/30/89 RUN I 5/10/89 'RUN I 5/12/89 DRESSER ATLAS DRESSER ATLAS DRESSER ATLAS SCHLUMBERGER FINAL FOR L3-24 PROD PROFILE LOG RUN I 4/20/89 CAMCO FINAL FOR L4-18 PROD PROFILE LOG RUN I 5/12/89 CAMCO FINAL FOR L5-36 PHYSICAL FORMATION LOG 4/25/89 GAMMA RAY RESISTIVITY LOG 4/26/89 SCHLUMBERGER SCHLUMBERGER SIGN AND RETURN TO: TINA KINCAID ARCO ALASKA, INC. 700 G STREET; ATO 409 ,~ ..ANC~AGE, ~SKA 99510 RECEIVE~.,~ ..... . ~ ~ Ancno,~ge P~NO STANDARD D&M STATE OF ALASKA CENTRAL FILES TRANSMITTAL # 615 AIRCO AILAS A IIINC. DATE: 11-24-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Finals L2-14 GCT Directional Survey 11-8-87 Run I 5" Sch L2-14 CET 11-8-87 Run 2 5" Sch L3-24 Production Profile 10-12-87 Run i 5" Camco L5-29 Temperature Log 10-25-87 Run i 5" Camco L5-29 Temperature Log 10-21-87 Run I 5" Camco RECEIVED BY:. '.AlaS~,a 01! & Gas,..~,r~ngCans' Oom~issio~ PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 ..~..~,.~~')~' CENTRAL FILES. ~ /] D&M XXON TRANSMITTIAL Cf 346 PLANO STANDARD STATE'OFALASKA~,, DATE: 10-21-87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH.Final Prints ~-~L2-16 CET 10-.13-87 Run I 5" Sch '~ L2-16 OCT Directional Survey 10-13-87 Rur, I 5" Sch ~ L5-5 Casin§ Ccllar Log & Perf Reccrd 10-.12-87 Run I 5" Sch ~-L5-21 Perforation Record 10-.11-87 Run I 5" Sch ~L5-21 After Perforation GR Log 10-.11-87 Run i 5" Sch RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATO 477 ANCHORAGE, AK. 99510 CENTRAL FILES D&M EXXON PILANO STANDARD,: TRANSMITTIAL # 328 ARCO ALASKA INC. LISBURNE ENGINEERING Date: July 16, 1987 From: Para Lambert >~7c~ Enclosed are the following: CH Finals for Lisburne Wells L2-6 Base Line Temp Log 6-17-87 Run ! 5" Camco ~ L3-18 Temp GR Log 6-17-87 Run 1 5" Camco L3-24 Flopetrol Production Logging 5~2-87 Run 1,2,3,4 5" Sch Anchorage Received by: Please sign and return tolPam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE FILE ROOM EXXON STANDARD CENTRAL FILES TRANSMITTAL # 263 A~¢O ALASKA INC. LISBURNE ENGINEERING Date: 7-2-87 From: Pam Lambert Enclosed are the following: Final Report for L3-24 Reservoir Fluid Study 6-19-87 CoreLab Please sign and r~tto~ P~ L=bert ~ / ~ ~co ~ ~Nc. ~ ~ 700 G Street ATO 477 ~ / Anchorage, ~. 99510 ~~& M E~ON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 260 - LISBUP. NE L'~G~I~ING Date: 5-19-87 From: Pam Lambert nclosed are the following: CH Finals for Lisburne Wells L2-33 Temp Fluid Density Flowmeter Log 5-8-87 Run 1 5" Camco L3-8 Waterhold Up Temp Flowmeter Log 5-4-87 Run 1 5" Camco L3-24 Flopetrol Prod Logging 4-30-87 Run 1 5" Sch L3-30 Post Temp GR Log 5-2-87 RUn 1 5" Camco L3-30 Collar Log & Perforating Record 5-7-87 Run 1 5" Sch L3-30 Major Acid Treatment Temp GR 5-11-87 Run 1 5" Camco L3-30 Mini Breakdown Treatment Temp GR 5-11-87 Run 1 5" Camco Received Please sign and return t~Pam Lambert ARCO AK INC. 700 G Street ATO 477 -Anchorage, AK. 99510 Gas Cons. Commission' Anchorage D&M EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITT~ # ~ 3 7 LISBURN~ EN(~IN~ERINC Date: 5-7-87 From: Para Lamber t Enclosed are the following:~% C~or Lisburne Wells L2-21 Post Acid GR Temperature Log 4-10-87 Run 1 Camco L2-21 GR Temperature Log 4-18-87 Run 1 Camco ~ L3-24 Diff Temp/GR (Post Major Stim) 4-19-87 Run 1 GO L3-24 Diff Temp/GR (Post Minor Stim) 4-19-87 Run 1 GO L3-24 Collar/Perf Log 4-11-87 Run 1 GO L3-24 Diff Temp/GR Static Base Log 4-17-87 Run 1 GO L3-30 Diff Temp/GR Post Stim 4-18-87 Run 1 GO Recei 0 , Pleasl~sig;Fand return to~Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M ~.. FILE ROOM EXXON STANDARD CENTRAL FILES TRANSMITTAL # 232 .. STATE OF ALASKA ALA~. , OIL AND GAS CONSERVATION COM .;SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Alter Casing [] Other 2. Name of Operator ARCO Alaska. inc. 3. Address P.0. Box 100360 Anchorage~ AK 99510-0360 4. Location of well at surface 870' FNL, 845' FWL, Sec.22, T11N, R15E, UN At top of productive interval 2210' FSL, 1424' FWL, Sec.23, T11N, R15E, UM At effective depth 2075' FSL, 1688' FWL, Sec.23, TllN, R15E, UM At total depth 2065' FSL~ 1709' FWL~ Sec.23~ TllN~ R15E~ UN 11. Present well condition summary Total depth: measured 12,141 'MD true vertical 9441 'TVD Stimulate [] Plugging [] Perforate [] Pull tubing COHPLETE Datum elevation (DF or KB) RKR F,c) ' 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L3-24 8. Approval number 7-~7 9. APl number 50-- fY)q-'21 10. Pool Lisburne 0il PQQ] feet Plugs (measured) None feet Feet~ Effective depth: measured 12,094 'MD true vertical 9400 ' TVD feet Junk (measured) None feet Casing Length Size Conductor 80' 20" Surface 4345 ' 13-3/8" Producti on 11,379 ' 9-5/8" Liner 941 ' 7" Cemented Measured depth 1700# Pol eset 120 'MD 2650 sx' AS III & 4380'MD 600 sx Class G 800 sx Class G & 11,416'MD 300 sx AS I 369 sx Class G 11,198'-1'2,139'MD True Vertical depth 120'TVD 3994 'TVD 8821 'TVD 8842 '-9439 'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 11,211' Packers and SSSV (type and measured depth) HB pkr ~ 11,125' & TROP-1A SSSV @ 2192' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well Hi sto.ry) Daily Report of Well Operations Copies of Logs and Surveys Run ~ 6vro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-)~/~q/L.~/ ~'"'~_;¢_L/,~-{_/Title Associate Engineer Form 10-404 Rev. 12-1-85 ~ (Dani) SW02/20 Date Submit in Duplicate ARCO Oil and Gas Company Daily Wel, History-Final Report Instructions: Preoare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel3ort" should be submitted also when ooerations are susOended for an indefimte Or appreciable tength of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire Dilatation if sOace ~s available. I Accounting cost center code District ICounty or Parish I State Alaska i North Slope Borough I Alaska Field ILease or Unit lWetl no. Prudhoe Bay ~ ADL #28328 I L3-24 Auth. or W.O. no. ITitle AFE ALO150 I Completion WWS #1 API 50-029-21670 Operator IA'R'CO' w'I' IcostF°tal number °f wells (active °r inactive) °n thisIcenter prior to plugging and ARCO Alaska, Inc. 50% labandonment of this well Complete 3/20/87 ! 0400 Hrs. Spudded or W.O. begun Date and depth as of 8:00 a.m. 3/20/87 3/21/87 thru 3/22/87 3/24/87 3/25/87 Complete record for each day reported 7" @ ,139' 12,094' PBTD, NU BOPE Accept rig @ 0400 hrs, 3/20/87. ND tree, NU BOPE. 7" @ '~2,139' 12,094' PBTD, RR Diesel Tst BOPE. RU DA, make GR/JB rn to PBTD. RU & rn 347 2-7/8", 6.5#, L-80 EUE 8~ Cbg w/SSSV ~ 2192', HB Pkr 11,125', TT ~ 11,211'. Tst cbg co 2500 psi, cst ann to 1500 psi. ~ BOPE, NU & tst tree to 5000 psi. Displ well w/diesel. ~ ~ 2400 hfs, 3/21/87. Long term tbg tst. Bled press - Tbg w/O psi, csg w/ll00 psi, contrl in w/llO0 psi. Notified State. Release well to Production. Old TO Released rig 2400 Hrs. INew TD PB Depth 12,094' Date K nd of r g 3/21/87 Rotary Classifications (oil, gas, etc.) Oll Producing method Flowing Type completion (single, dual, etc.) Single Official reservoir name(s) Lisburne Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas ~er day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Drilling Supervisor For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date: 2-5-87 From: Para Lamber Enclosed are the following: CH Finals for Lisburne Wells L3-2 Collar Log (to set packer) 12-16-86 Run 1 5" DA ~"'"L3-2 Collar Log (for perforating) 12-16-86 Run 1 5" DA ~'L3-19 CET 3-11-86 Run 1 5" Sch L3-19 CBL 3-10-86 Run 1 5" Sch (CBT) '"'~L3-22 Acoustic CBL 11-25-86 Run 1 5" DA '~L3-24 Acoustic CBL 12-24-86 Run 1 5" DA ~LGI-6 7-9-86 Run 1 5" Sch (CBT) '~LGI-6 Completion Record 10-28-86 Run 1 5" Sch LGI-~ GCT Directional Survey 7-9-86 Run 1 5" Sch (recomputed) Please sign and return to~ Pam~ambert~/ ARCO D&M STATE FILE ROOM 700 G Street ATO 477 Anchorage, AK. 99510 EXXON STANDARD CENTRAL FILES TRANSMITTAL # 162 ARCO ALASKA INC. LISBURNE ENGINEERING Date: 1-19-87 From: Pam Lambert Enclosed are the following: Magnetic Tape for L3-24 OH LIS Shifted 12-16-86 Run 1 DA Please sign and return tolPam L 0 ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 141 .... STATE OF ALASKA ALASKA .)IL AND GAS CONSERVATION COMM~,,,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging ~ Stimulate ~ Pull tubing ~ Amend order-' Perforate- Other- 2. Name of Operator ARCO Alaska, ]Inc. 5. Datum elevation (DF or KB) 3. Adc~e. SSo. BOX 100360 Anchorage, AK 99510-0360 4. Location of well at surface 870' FNL, 845' FWL, Sec. 22, T11N, R15E, UM At top of ,productive interval 2100 FSL, 1320' FWL, Sec. 23, T11N, R15E, UM(Approx) At e~egti~/e~LPt~h 1710' FWL, Sec. 23, T11N, R15E, UM(Approx) At t~fPP~sL, 1733' FWL, Sec. 23, T11N, R15E, UM(Approx) 60'RKB 6~Un~.orPr~pertvname ~rudnoe uay ~nit/Lisburne 7. Wellnumber L3-24 8. Permit number 86-182 9. APl number 50-- 029-21670 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 4345' Production 11379' Liner 941' 12141 'MD feet Plugs (measured) None 9436'TVD feet 12094 'MD feet Junk (measured) None 9391 'TVD feet Size Cemented Measured depth 20" 1700# Poleset 120 'MD 13-3/8" 2650 sx AS III & 4380'MD 600 sx Class G 9-5/8" 800 sx Class G 11416'MD 7" 360 sx Class G 11198-12139'MD Rue Vertical depth 120'TVB 3998'TVB 8838'TVD 8660-9434'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None RECEIVEB JAN 2 1987 Alaska Oil & Gas Cons. Commission Anchorage 12.Attachments Description summary of proposal ~ Detailed operations program - BOP sketch -' WELL HISTORY 13. Estimated date for commencing operation January, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~~z/ ~~ Title Associate Engineer Commission Use Only (DAM) SA/193 Conditions of approval Notify commission so representative may witness I Approval No. F-; Plug integrity ~ BOP Test ~ Location clearance I Date Approved by Subsequent Work Reported / ~.~ ~,. oc ~ on Form No.,/~' ~) ~' Dated _.~/~ . by order of Commissioner the commission Date / -~¢/ ¢~c'.-.] Form 10-403 Rev 12-1-85 Submit in triplicat, e ~:,-~':'~ ': ~ - ~ .... '- · ~ :-~ t .c~:~:~'~-':~' ,. ~.~'~ . : . ' pany ~> . Well History - Initial Repo~ - Dally - I~1~:- P~pare and submit the "Initial Repoff' on the fi~t Wednesday after a ell is spudded or workover operations are sta~ed. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty, parish orborough I State Alaska North Slope Borough Alaska Field ILease or Unit iWell no. Prudhoe Lisburne I ADL ~28328 I L3-24 ITitle Drill Auth, or W.O. no. AFE AL0150 Rowan 41 AP1 50-029-21670 Operator ARCO w.I. ARCO Alaska, Inc. Spudded or W.O. begun IDate Hour Pr or status if a W.O, Spudded I 11/26/86 0200 hrs. Date and depth as of 8:00 a.m. 11/26/86 11/27/86 thru 12/01/86 12/02/86 12/03/86 Complete record for each day reported 20" @ 120' 470', (350'), Drlg surf hole Wt. 8.7, PV 4, YP 53, PH 9.7, ~L 15, Sol 2.5 Accept rig @ 1930 hfs, 11/25/86. ND diverter sys. 11/26/86. Spud well @ 0200 hfs, . 13-3/8" @ 4380' 4380', (3910'), ND diverter Wt. 9.6+, PV 6, YP 26, PH 8.4, ~rL 28, Sol 10 Drl & surv 17½" hole to 3045', POOH & left 1 cone in hole. CbS BRA, RIH, wsh & rmhole f/2983'-3045', drl to 3122, pipe torqued & split box leaving TOP @ 962', POOH. RIH w/skirted screw-in sub & retrv'd fsh, POOH. TIH, drl & surv 4380', POOH. RU & rn 2 its, 13-3/8", 68#, K-55 BTC csg & 107 Jts, 13-3/8", 72#, L-80 BTC csg w/PC @ 4298', FS @ 4380'. Cmt w/2650 sx AS III & 600 sx C1 "G" w/2% CaC1 & .2% D-46. Displ using rig pmps, did not bump plug. 1672', 1.1°, 2258', 7.4°, 2910', 23.5°, 3531', 39.1°, 4053', 48.6°, 4310', 49.7°, ND diverter. N77.3W, 1671.99 TVD, - 1.68 VS, 0.37N, 1.66W S65.7E, 2256.99 TVD, 13.72 VS, 4.08S, 13.14E S74.8E, 2883.95 TVD, 184.58 VS, 66.275, 172.29E S63.2E, 3423 TVD, 487.85 VS, 187.47S, 450.43E S65.3E, 3784.88 T'v'D, 861.28 VS, 355.97S, 785.19E S72.7E, 3952.97 TVD, 1055.52 VS, 425.59S, 966.55E 13-3/8" @ 4380' 4460', (80'), Drlg Wt. 8.4, PV 1, -YP 1, PH 12, ~FL 100+, Sol .5 NU & tst BOPS. RIH, DO cmt stringers @ 4030', wsh dn to 4276', drl cmt to 4296', tst csg to 2500 psi. DO flt equip & cmt + 10' new formation. Conduct formation Cst to 14.1 ppg EM~. Drl to 4460'. 13-3/8" @ 4380' 6350', (1890'), Drlg Wt. 9.1, PV 3, YP 5, PH 10.5, ~TL 25+, Sol 5.5 Drl & surv to 5508', DD to 6350'. 4574', 50.1°, S70.2S, 4123.02 TVD, 1257.10 VS, 489.82S, 1157.98S 5314', 51.9°, S68.1E, 4585.69 TVD, 1834.53 VS, 700.305, 1695.70S 5776', 51.4°, $73.8S, 4874.13 TVD, 2195.02 VS, 823.47S, 2034.71S The~ is correct see Proceduri~s~,l~lanual, Section 10, Drilling, Pager86 and 87. IDate 1/16/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History--Interim ~nstrdctione: This form is used during drilling or workover operations, If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Date and deptl~ as of 8:00 a.m. County or Parish Alaska North Slope Borough Ikease or Un t Prudhoe Lisburne ADL #28328 Complete record for each day while drilling or workover in progress 12/04/86 12/05/86 12/06/86 thru 12/08/86 12/09/86 12/10/86 12/11/86 JState Alaska JWell no, L3-24 13-3/8" @ 4380' 7540', (1190'), Drlg Wt. 9.1, PV 4, YP 6, PH 10.0, WL 19.4, Sol 5.5 Drl & surv to 7540'. 6484', 47.9°, S75.2E, 5337 TVD, 2727.65 VS, 971.93S, 2549.05E 7099', 46.2°, S68.5E, 5758 TVD, 3174.61VS, 1110.76S, 2974.95 7411', 47.3°, S68.8E, 5972 TVD, 3401.85 VS, 1193.49S, 3186.61E 13-3/8" @ 4380' 8330', (790'), Drlg Wt. 9.3, PV 4, YP 10, PH 9.0, WL 10.8, Sol 7 Drl & surv to 8330'. 7808', 49.7°, S68.8E, 6235 TVD, 3699.14 VS, 1301.00S, 3463.80E 8179', 49.5°, S68.8E, 6476 TVD, 3981.64 VS, 1403.16S, 3727.20E 13-3/8" @ 4380' 10,320', (1990'), Wt up mud to 9.9 ppg Wt. 9.7+, PV 8, YP 10, PH 12.2, WL 6.8, Sol 9 Drl & surv 12¼" hole to 10,320'. 8,280', 48.8°, S69.2E, 6542 TVD, 4058.03 VS, 1430.54S, 3798.53E 8,905', 47.3°, S69.9E, 6961TVD, 4521.44 VS, 1591.39S, 4233.31E 9,623', 45.0°, S71.OE, 7457.62 TVD, 5039.26 VS, 1764.15S, 4721.94E 10,239', 41.8°, S71.3E, 7903.71TVD, 5463.23 VS, 1899.33S, 5124.53E 13-3/8" @ 4380' 10,540' (220') Drlg. Wt. 10.1, PV 11, YP 12, PH 12.0, WL 6.8, Sol 11 Circ, wt up, drill, TOH, ch$ bit, TIH-cracked box on jars. TIH, rm 854' to btm, drl. 10,402', 40.0, S69~5E, 8026.91TVD, 5569.86VS, 1935.13S, 5225.06E 13-3/8" @ 4380' 10,835' (295') TIH Wt. 10.0, PV 17, YP 10, PH 11.9, WL 5.6, Sol 11 Drl & surv to 10,835'. 10,764', 37.3°, S66.4E, 8309.60 TVD, 5795.90 VS, 2019.99S, 5434.57E 13-3/8" @ 4380' Drl & surv 12¼" hole to 11,157'. 11,066', 35.8°, S65.0E, 8552,20 TVD, 5975.58 VS, 2093.99S, 5598.4~E M~s~ 0\\ & ~s Cons. go,,,..._ss~~ Th~b~ is correct Si natur For form prepar~*n~ ~nd d~ribution JDate 1/16/87 Jq'i,,e Drilling Supervisor ARCO Oil and Gas Company 4~, Daily Well History--Interim 'Instructions: This form i's used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska' North Slope Borough Field ILease or Unit Prudhoe Bay I ADL #28328 Date and depth as of 8:00 a.m. 12/12/86 12113/86 thru 12/15/86 12/16/86 12/17/86 12/18/86 12/19/86 The a~ye is correct For form preparat~-a~-d distribution ~ see Procedures a~.~3bal Section 10, ~ Drilling, Pages 86 and 87 Alaska Well no. L3-24 Complete record for each day while drilling or workover in progress 13-3/8" @ 4380' 11,441' (284') Rng. 9-5/8" csg Wt. 10.0, PV 14, YP 8, PH 11.3, WL 6.0, Sol 11 Drl 11,157' to 11,441' - 21 std short trip, CBU, POH. Chg rams to 9-5/8" & tst @ 3000 psi. RU & rn 9-5/8" csg. 11376', 34.75°, S68.5E, 8805.27, 6154.52VS, 2164.65S, 5762.94E 11441', 34.5°, S69.2E, 8859, 6191VS, 2178S, 5797E 12141', 34.5°, S69.2E, 9436T, 6588VS, 2319S, 6168E 9-5/8" @ 11,416' 11,940' (499') Drlg Wt. 9.3, PV 5, YP 5, PH 11.9, WL 2.2, Sol Trc Rn 274 its, 9-5/8", 47#, L-80 BTC & NS-CC csg w/FC @ 11,325', FS @ 11,416'. Cmt w/150 sx 50/50 Pozz w/4% D-20, .5% D-65 & .2% D-46 & 650 sx C1 "G" w/1.5 gal/sx D-600, .05 gal/sx M-45, .06 gal/sx E-2009 & .3% D-65. Displ using rig pmps, bump plug. RIH w/8½" BHA to FC, tst csg to 3000 psi. DO cmt & flt equip + new hole to 11,451'. Conduct~formation tst to 12.4 ppg EMW. Drl 8½" hole to 11,940'. 9-5/8" @ 11,416' 12,141' (201'), Logging Wt. 9.3, PV 5, YP 4, PH 11.7, WL 12.6 Drl to 12,141', short trip, CBU, POOH. Spectra/MINI/DLL/CAL. RU DA, rn 9-5/8" @ 11,416' 12,141' (0'), POH Wt. 9.3, PV 5, YP 4, PH 11.4, WL 12.8, Sol 5* Fin logging MLL/DLL/SL f/TD to 9-5/8" shoe, ZDL/CNL/GR f/TD to 9-5/8" shoe. CBL/VDL/CCL/GR f/9-5/8" shoe to 9800', RD DA. RIH, make wiper trip. CBU, POH f/lnr. 12,141' (0'), PU 4-3/4 DC & 3-1/2 DP Wt. 9.3, PV 5, YP 5, PR 11.2, WL 7.0, Sol 5 RU & rn 7" lnr. Cmt w/360 sx 35/65 Pozz C1 "G" @ 14.0 displ w/215 bbls. Press to 3000 psi. TOL @ ll,lS6', FC 12,139'. Rel f/hgr & POOH. 7" @ 12,139 12,141' (0'), Drlg landing collar Wt. 9.3, PV 6, YP 16, PH 12.3, WL 8.0, Sol 5 RIH w/8-1/2" bit, cln out cmt to TOL, circ, POOH. CO lnr to LC; test csg to 3000 psi. Drlg LC. RIH w/6" bit, IDate ITiUe '1/16/87 Drilling Supervisor ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ICounty or Parish I Alaska Field ILease or Unit I Prudhoe Bay Auth. or W.O, no. ' ~Title AFE AL0150 I Accounting cost center code State Alaska Well no. L3-24 North Slope Borough ADL #28328 Drill Rowan 41 Operator ARCO Alaska, Inc. Spudded or W.O. begun AP1 50-029-21670 cost center prior to plugging and 21,66% abandonment of this well I Date Hour Prior status if a W.O, 0200 hrs. Spudded Date and depth as of 8:00 a.m. 12/22/86 Old TD 11/26/86 Complete record for each day reported 7" @ 12,139 12,141' TD, 12,094' PBTD, ND BOPE 9.3+ ppg NaC1 Drill cmt, circ out, test csg, displ to brine, test csg, LD DP, ND BOP. Install tbg head, adapter & mstr valve. Test packoff @ 5000 psi, test master valve @ 5000 psi. Release rig @ 1300 hfs, 12/20/86. New TD Released rig Date 1300 hrs. Classifications (oil, gas, etc.) Oil Producing method Flowing I PB Depth 12,141 ' IKind of rig I Z2/20/86 Type completion (single, dual, etc.) Single Official reservoir name(s) Lisburne 12~094' Rotary Potential test data Well no. Date Reservoir I Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % CdR Gravity Allowable Effective date corrected ~ve is correct 'For form pre~'~ttion~n~distribution~ see Procedti~eg Manual, Section 10, Drilling, Pages 86 and 87. Date [Title 1/16/87 Drilling Supervisor LISBURNE Date: 1-14-87 From: Para Lambert Enclosed are the following: OH Finals for L3-24 Acoustic CBL 12-16-86 Run 1 5" DA '~Spectralog 12-16-86 Run 1 2"&5" DA ~ Compensated Neutron/GR 12-16-86 Run 1 2"&5 DA --~Z-Densilog/GR (Poro) 12-16-86 Run 1 2"&5" DA '-~ Z-Densilog/GR (Raw) 12-16-86 Run 1 2"&5" DA ~DLL/MLL/GR 12-16-86 Run 1 2"&5" DA Received by:..---./ ' ~[ :::> ,. ~ r±ease slgf~.~'fd ~eturn to~.~m?:}~ambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 9951 D & M EXXON STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL ~ 38 ARCO ALASKA INC. LISBURN~ ~NGINBgRING Date: 12-30-86 From: Para Lamber Enclosed are the following: Magnetic Tape for Lisburne Well L3-24 OH LIS Unshifted 12-17-86 Run 1 DA Received by: ~-~.. / lea~~~return~~ to= P~ L~bert P ~ ~.. ~CO ~ INC. k~-~ 700 G Street ATO 477 Anchorage, ~. 99510 D & M EXXO~ FILE ROOM ~RAL FILES TRANSMITTAL # 129 ARCO ALASKA INC. LISBURNB ~NGINggRING Date: 12-26-86 From: Pam Lambert Enclosed are the following: OH Final for L3-24 Mudlog Run 1 2" Westlog Received by: '~~ Please sign and r~urn to=Pam Lambert .._~ ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D &M EXXON STATE~ STANDARD ' FILE ROOM CENTRAL FILES TRANSMITTAL # 127 November 19, 1986 blt. T. P. Oostermeyer Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Prudhoe Bay Unit L3-24 ARCO Alaska, Inc. Permit No. 86-182 Sur.. Loc. 870'.FNL, 845'FWL, Sec. 22, TllN, R15E, UM. Btmhole Loc. 1876'FSL, I879'FWL, Sec. 23, TllN, R15E, UM. Dear Mr. Oostermeyer: 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 diverter 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. ./~~ tmul~yours, C. V. Chat~er~ton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COP5MISSION jo Enclosure cc: Department of Fish & Game, itabitat Sectio~ w/o encl. Department of Enviroranental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASt._. OIL AND GAS CONSERVATION .)MMISSION PERMIT TO DRILL 20 AAC 25.005 t la. Type of work Drill ~ Redrill F-11 lb. Type of well. Exploratory [] Stratigraphic Test '.~ Development Oil Re-Entry [] DeepenFqI Service [] Developement Gas C Single Zone ,~ Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 60', PAD 21' feet Prudhoe Bay Field 3. Address 6. Property Designation Lisburne 0i 1 Pool P.0. Box 100360 Anchorage, AK 99510 ADL 28323 ALK 2321 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 870'FNL, 845'FWL, 5ec.22, T11N, R15E, UM Prudhoe Bay Unit/Lisburne 5tatewide At top of productive interval ~ Target 8. Well nurpber Number 2100'FSL, 1320'FWL, 5ec.23, TllN, R15E, UM L3-24 #8088-26-27 At total depth 9. Approximate spud date Amount 1876'FSL, 1879'FWL, Sec.23, TllN, R15E, UM 11/23/'86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 2,1 79 ' MD 0'~ 7422'TVD feet 59' from L3-22 ~ surf)ce 2560 (9541'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 1500 feet Maximum hole angle43.7 3Maximum surface 3560 psigAt total depth (TVD) 4490 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) ~0" ?n,, 9! _5# ~-~.n Weld 8! ' ~.0' 40' !2! ' !2! ' 2000# Pe~.e~_et 17-1/?"11~-'~1R" ~R .f).~ k'-C,~ RTl" 7f~' ~,q, 3, q, l~q' lflCl, ?b.~l <~r A.c, I i I 17-1/2"i13-~/~" 72.O# L-~O RTC. 4407' 1Oq' log' i/~lG' /~{30' ~OO .~x Cla.~.~ 12-1/4"9-5/8" ~,7.0# L-80 BTC 1227' 38' 38'1 1265' 8880' 568sxClassG&300sxASl&A 8-1/2" 7" 29.0# L-80 BTC 1114'11065' 8736'12179' ~,.~'~.1 ' 225sx14.0 ppcj Class 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 Liner Perforation depth: measured - true vertical 20. Attachments Filing fee ~ Property plat [] BOP Sketch'l~ Diverter Sketch ~i~ Drilling program ~ Drilling fluid program ,[~,~..Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby certify that thee foregoing is true and correct to the best of my knowledge S~gned ~, Title Date Commission Use Only ( FP6 ) PD/01 5 86-:I. 82 50- 029-21670 11 / ]. 9 / 86 for other requirements Conditions of approval Samples required [] Yes ,~. No Mud log required L--] Yes ~ No Hydrogen sulfide measures [] Yes ~ No Directional survey required ~Yes [] No Requiredwor,~0~r ~~/,/~~~3M; /~SM; ~ 10M; r-q 15M Other: ~~/,,~~ "~ by or der of Appr°voObyL /"X / Commissioner the commission Date _ Form 10-401 Rev. 12-1-85 triplicate L3-24 DR ILL I NG PROGRAM 1. Set 20" conductor and cement. A 20", 2000 psi annul ar diverter wi 11 be installed per the attached schematic. This is a variance from 20 AAC 25.035. 2. MIRU Rowan 41. Install 10" diverter lines and function test. Drill 17-1/2" hole to 1500'MD(1500'TVD). Build 2-1/2© per 100' to 43°41' oriented S68~08'E. End of curve is at 3248'MD(3083'TVD). Drill to 13-3/8" casing point 4516'IqD(4000'TVD), maintaining angle and direction. 4. Set 13-3/8" casing and cement to surface. Test casing to 2000 psi. Do top job if cement does not surface. 5, Install 13-5/8", 5000 psi, RSRRA BOP stack. Test BOP stack to 5000 psi, annular to 3000 psi. Test BOP stack weekly. Drill 10' of new formation and perform leakoff test. 6. Hold angle and drill 12-1/4" hole to 11265'MD(8880'TVD) 7. Set 9-5/8" casing and cement. Test casing to 3000 psi. 8. Drill 10' of new formation and perform leakoff test to 12.5 ppg EMW. 9. Drill 8-1/2" hole to approximately 12179'MD(9541'TVD). 10. Run open hole logs. 11. Run and cement 7" liner. 12. Clean out cement and change mud out to brine with 400' diesel cap. 13. Secure well and release rig. 14. Run cased hole logs. 15. MIRU completion rig. 16. Run production tubing string with packer and subsurface safety valve. 17. NU tree and test to 5000 psi. 18. Secure well and release completion rig. 19. Perforate and stimulate well. Page Two L3-24 Drilling Program NOTE: a. In accordance with Area Injection Order No. 4, excess non-hazardous fluids developed from well operations and as necessary to control the fluid level in the reserve pit, will be disposed of down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The an- nulus will be sealed with 300 sx of cement followed by Arctic Pack upon the completion of the fluid disposal process. b. The drilling fluid program and fluid surface system will conform to the regulations set forth in 20 AAC 25.033. c. Maximum surface pressure is based upon BHP of 4490 psi ~ 8960'TVD, less an oil column to 8660' less a gas column to the surface d. The existing wells within 200' of the proposed well are: L3-22, 59' at surface L3-23, 178' at surface L3-18, 179' at surface There are no closer approaches downhole. e. The minimum distance between the planned well L3-24, and the 3 Prudhoe Bay wells shown on the 1000' to 1 inch plan view map attached to this permit are: DS 4-22 passes 271' from L3-24 @ 9442'MD(7563'TVD) (L3-24 Depths) DS 4-24 passes 675' from L3-24 ~ 11343'MD(8937'TVD) (L3-24 Depths) DS 4-21 passes 1636' from L3-24 @ 7749'MD(6339'TVD) (L3-24 Depths) PD/O15a:dmr 11-13-86 L3-24 MUD PROGRAM Density Depth (TVD) #/gal Plas Yield Visc. Point Initial 1OM FL (CP) #/100 ft2 Gel Gel CC/30M Surf 8.8 Funnel to to 100- 13-3/8" 9.7 300 Csg Point 40-60 20+ 40+ 20+ 0 13-3/8" Csg Shoe 8.3 Minimum 6 2 5 25 0 to to Possible to to to to to K-lO 9.4 20 10 30 10 2 % Oil % pH and Solids Type of Mud 8-10 Spud Mud 3 Low Solids to Non-dispersed 7 K-lO 9.2 10 4 4 8 8 2 to to to to to to to to 9-5/8"Csg. Pt. 10.2 20 10 8 20 4 5 4 pH 9-10 to Low Sol ids/Low Lime 15 Non-di sper sed 9-5/8" Csg. Shoe 9.2 4 6 2 8 10 2 to to to to to to to to TD 9.6 10 10 8 20 4 8 4 Low Solids/ to Non-Dispersed 8 Salt 15,000 - 30,000 ppm NOTE: Exact mud properties will be selected by ARCO representative based on hole conditions. 1. Degasser 2. Shakers 4. 5. EQUIPMENT - DRILLING FLUID SYSTEM Pit level indicator (with both visual and audio warning devices) Drilling fluid flow sensor (with read out convenient to the driller's console) Trip tank 6. Agitators 7. Desander 8. Desilter 9. Centrifuge PD/014b: dmr 10-20-86 ROLVAN 4~ ~(U§ SYSTEM mixing pit #1-145 bbls mixing pit #2-1 45 bbls pill pit 6O bbls I pit #4 115 bbls pit #3 suction 115 bbls pit #5 trip tank 1 45 bbl s injection pit 145 bbls pit #6 -90 bbls pit#7- 90 bbls pit #8 40 bbls Brandt Doub l e-Deck er Shale Shak ers-(3 ) Demco Desander with 3- 12" diam. cones Demco Desilter with 14-6" diam. cones Dri lco Degasser Pioneer Centrifuge Main Pumps: National 12-P-160, (2) Gasbuster L8-24 6000 7000 8000 9000 10000 11000 0 1000 2000 3000 4000 S000 6000 7000 8000 0 ;~0'CONDUCI'OR TVD'11~I ' ' ' ' '" ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' 0 XoP 'rVD - 11~00 ARCID ALA,SKA, INC. 7.5 2000 '[~ 12.5 I~CAI I= 1 IN, = ltt{3{) FT. 2000 '~ 17,5 SURFACE:8;'O'FNL 845' F WL 22.',5 27.5 SEC 22 T11N R15E Ut I ];2.5 TARGET:2100'FSL 1320'f WL 'i 37,5~ ___ RFC ~.~ ~T11N R1RF 1.111 3000 3000] % .... cot ~vu-3uu3 ~u-3z~u u:~-- - - - 4000 5000 5000 s 68 D~.G 08 MIN r 022 AVI'.RAGE ANGLE 43 PEG 41 MIN -6201 FT( 70 TARGET) - · - 6000 I ' , ~, ... 7000 K-1t) TVD -- 736C MD -- 9163 ~3EP -- 4721 K-6 TVD ,,,, 7785 MD -- 1 750 DEP -- 5 27 _L x',,D84-22 t / % 8000 D84-~11 LCt TVD -- 848C MD -- 10725 'DEP -- 5800 SADLEROCHI; TVD "849(;I MD -' 10725 DEP "= 5800 Kt ,VIK TVD - 8'~'36 MD -- 11064 DEP '- 60:;}4 9-5/8'C ;G PT TVD -' 8880 MD '- 11265 DEP -' 6173 Tt~13 I I.~ RI IRKII= Tvrl = R;III"I ldll"t == 11.'"4~R I~F:P -- R')~1 ·'"'"';;--' 9000 ..... '~ JLAa-Ei' TVb = B0i0 MD = 11808 DEP - 8;201 7=CSG PT/T~) TVD -- 964' MD - 12179 DEP -- 6804 ' ' - 10000 ................................ ' ........ ' ....' ................................ 11000 0 1000 2000 3000 4000 5000 6000 7000 8000 VERTICRL SECTION 0'0I W"ldgSIO OOgSI ' N~JOOWq-80F 986I 'AON E - W COORDINRTES o - 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0- 0 . I . 0 - o I · ' ' ~ ' ' ' ' ' ' ' '"' '"' ' ~ ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ! , i , , , i , , , , , , , , , , , , , , , , ! , , ~ , , , , , , , , , , ', , , , , , , , i , , , , , , , , , - ! 000 0 ! 000 2000 3000 4000 5000 6000 7000 8000 9000 E - 1~ COOROINFtTES o Fi. - N COOROINF~T£S -300 -200 - 1 O0 0 1 O0 200 300 400 3169 ! ! ! i 0 o o o Zo Z 0 L3-2 I -300 814 -200 -100 0 100 200 300 400 E - IN COORDINFtTES E - N COOROINRTES o - 1000 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 ' )S4-,?.21 .... O$--i22 ~3~7 ~'~'~ ~ _22~~7 ~ ~285 L3 ~7850 ~ ~176 ~ ool)2 ' ' ' ouu~ ' z ~8~ 6~92 ~ .... 607~ II I ou~u o - 568;~ 0 " 18 527 L o 48~ ~6655 I ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ' '" ' ' ' ' ' ' ' ' ' ' ' "' , ' ' "' ' ' ' ' ' '~ ~'~ ' ~~' ' ' ' ' ' ' ' ' ' ' ' ' ' ' ''' ' ' "' ' ' ' ' ' ' ' ' ' ' ' ' ' - 1000 0 1000 2000 3000 ~000 5000 6000 7000 8000 9000 E - ~ COOROINBTES 13-5/8" SO00 PS! BOP STACK DIAGRAM ACCLIMLILATOR CAPACITY TEST l ANNULAR REVENTER j ! ¢ 1 P! PE RAHS BLIND RAH5 DRILLING SPOOL PE RAHS DRLG SPOOL CSG SPOOL r~l 3-3/8' ~1 STARTINO ~ * HEAD ALL BOP EQUIPMENT 5000 PSt RATED 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. Z. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT 15 45 SECONDS CLOSING TIME AND 1 PO0 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITHA NON-FREEZING LIQUID. 2. CHECK THAT ALL HOLp DOWN SCREWS ARE FULLY RETRACTED. MARK RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN TEST PLUG ON DRILL PIPE AND SEAT IN WELLHEAD. R U N I N LOC K DOW N SC R EWS. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES. 4 FUNCTIONALLY TEST CHOKES. 5. IN EACH OF THE FOLLOWING TESTS, FIRST HOLD A 250 PSI LOW PRESSURE TEST FOR A MINIMUM OF 3 MINUTES, THEN TEST AT THE HIGH PRESSURE. 6 INCREASE PRESSURE TO $000 PSI AND HOLD FOR A MINIMUM OF SMINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES AND OPEN CHOKES. INCREASE PRE55URE TO 5000 PSI AND HOLD FOR AT LEAST 3MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS THEN CLOSE BOTTOM SET OF PIPE RAMS. INCREASE PRESSURE TO 5000PSI BELOW THE BOTTOM SET OF PIPE RAMS AND HOLD FOR AT LEAST 3 MINUTES. 10. TEST REMAINING UNTESTED MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF VALVE AND ZERO PRESSURE DOWN- STREAM. 11. BLEE ~D PRESSURE TO ZERO. OPEN BOTTOM SET OF PIPE RAMS. 1Z. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND R~MSANDTESTTO 5000 PSI FOR AT LEAST 3 MINUTES. 1 3. BLEED PRESSURE OFF ALL EQUIPMENT. OPEN BLIND RAMS MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING LIQUID AND ALL YALYES ARE SET IN DRILLING POSITION. TEST STANDPIPE VALVES TO 5000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI. CHECK OPERATION OF DEGASSER. " RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. 51GN AND SEND TO DRILLING SUPERVISOR 1 @. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. JO 8-26-85 14. 15 16. 17 well ARCO ALASKA INC. .,ROWAN 41 DIVERTER Fillup line I 10" ball t I Riselr Flowline v~v L_ J 1"~" 11 vlv 't Conductor Note: Only one valve opens automatically when the diverter closes. The second valve will remain closed unless conditions require the use of the second vent line, The second vent line valve can be opened using controls located at the accumulator, This is a variance from 20 AAC 25.035 (2) Loc APPROVE DATE (2' tl~-u 8) (6) (29 tkru 31) (6) Add: ~.~,~. 2/~ C~olpgy: Engineering: I,,rVA HIM H.]H ~ rev: 07/18/86 6.0].1 ® 3. 4. 5. 6. 7. 8. e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. For 29. 30. 31. 32. ' ' attached Is the permit fee .......................................... Is well to be 'located in a defined pool .. ..... ~__~ Is well located proper distance from property i~g'[]l][[[]l[[][] Is Is Is Is Can permit be approved before fifteen-cbywait ........... well located proper distance from otherw~lls .... sufficient undedicated acreage available in thig'~i'. 1.1.1. 11111 ~ well to be deviated and is wellbore plat included ................ ~-m; the only affected party ' /~ operator ................................. Does operator have a bond in force ................................... Is a conservation order needed ................................. ' ..... Is achttnistrative approval needed ' Is the lease number appropriate ........ ; ............................ Does the well have a unique name and number ......................... Well No NO' _ _ , Is conductor string provided..' ...................................... Will surface casing protect fresh water zones ....................... ~z ..... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and inten~.diate 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 abandomment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressuz-e rating - Test to _~ psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented .. Additional requirements ............................................. GEO. AREA UNIT NO. ON/O F SHORE POOL INITIAL CLASS STATUS Well Histo,ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXl No special'effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER RECEIVED COMPANY NAME : BP EXPLORATION WELL NAME : G-24 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292167100 REFERENCE NO : 98435 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE **** REEL HEADER **** SERVICE NAME .. EDIT DATE : 98/08/25 ORIGIN : FLIC REEL NAME : 98435 CONTINUATION # : PREVIOUS REEL : COM~ENT : BP EXPLORATION, PRUDHOE BAY, G-24, API #50-029-21671-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/08/25 ORIGIN : FLIC TAPE NAME : 98435 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : BP EXPLORATION, PRUDHOE BAY, G-24, API #50-029-21671-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: G- 24 API NUMBER: 5002921671 O0 OPERATOR: BP EXPLORATION LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 24-AUG-98 JOB NUMBER: 98435 LOGGING ENGINEER: J. SPENCER OPERATOR WITNESS: J. RATHERT SURFACE LOCATION SECTION: 12 TOWNSHIP: 1 IN RANGE: 13 E FNL: 2703 FSL : FEL : 1974 FWL : ELEVATION (FT FROM MSL O) F~ELLY BUSHING: 72.10 DERRICK FLOOR: 71. O0 GROUND LEVEL: 34.60 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 10475.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: BCS LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH 88888.0 10296.0 10290.5 10286.5 10278.0 10272.5 10260.5 10254.0 10247.5 10240.5 10234.5 10225.5 10220.0 10219.0 10218.5 10217.0 10214.5 10201 5 10201 0 10191 0 10181 0 10168 0 100 0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88888.0 88888.0 10296.0 10296.0 10290.5 10290.5 10286.5 10278.0 10278.0 10274.0 10274.0 10261.0 10261.0 10253.5 10253.5 10247.5 10247.5 10240.0 10240.0 10234.5 10234.5 10225.0 10225.0 10220.0 10218.5 10215.0 10202.5 10220.5 10218.5 10215.0 10202.5 10192.0 10192.0 10181.0 10181.0 10168.0 10168.0 100.0 100.0 REMARKS: CONTAINED HEREIN IS THE CNTD DATA ACQUIRED ON BP EXPLORATION WELL G-24 ON 1-MAY-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #1 GRCH TO THE BASELINE GAM~A RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTD PASS #1 NPHI TO GR.BCS. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION : OOiCO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10300.0 10147.0 CNTD 10323.0 10147.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-i998 10:33 PAGE TYPE REPR CODE VALUE 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTD PU-S 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTD 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTD 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 NCNTCNTD CPS 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTD CPS 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTD CPS 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTD CPS 1187901 O0 000 O0 0 I 1 1 4 68 0000000000 GRCH CNTD GAPI 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTD LB 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTD V 1187901 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10323.000 NPHI. CNTD 37.666 NRAT. CNTD 5.588 CRAT. CNTD NCNT. CNTD 3486.762 FCNT. CNTD 624.000 CFTC. CNTD 588.783 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1713.000 CCL.CNTD 0.000 DEPT. 10147.000 NPHI.CNTD 16.049 NRAT. CNTD 2.885 CRAT. CNTD NCNT. CNTD 5399.586 FCNT. CNTD 1871.636 CFTC. CNTD 1766.007 CNTC. CNTD GRCH. CNTD 17.869 TENS. CNTD 1675.000 CCL. CNTD 0.000 5.936 3530.500 3.220 5514.536 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE ArUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0. 5000 FILE SUFk4ARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10300.0 10147.0 CNTD 10323.0 10147.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10318.0 10308.0 10299.0 10286.5 10280.0 10272.5 10270.0 10266.5 10261.0 10257.5 10253.5 10241 5 10240 5 10234 0 10231 0 10226 0 10225 0 10222.0 10218.5 10213.5 .......... EQUIVALENT UNSHIFTED DEPTH GRCH CNTD 88888.0 88888.0 10286.5 10280.0 10273.5 10267.5 10253.5 10240.0 10234.5 10225.0 10318.0 10308.5 10300.0 10271.5 102 61.5 10258.0 10241.0 10231.0 10226.0 10222.5 10220.5 10214.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 10202.0 10203.0 10200.5 10202.5 10195.0 10196.0 10182.0 10183.0 10176.5 10177.0 10175.0 10175.0 10169.5 10170.0 10166.0 10168.5 10160.5 10163.0 10157.0 10157.5 10151.5 10151.5 100.0 102.5 100.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTH CORRECTED DATA FOR CNTD PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #2 GRCH TO CNTD PASS #1GRCH; AND CNTD PASS #2 NPHI TO CNTD PASS #1 NPHI. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 1i 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTD PU-S 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTD 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTD 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTD CPS 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTD CPS 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTD CPS 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTD CPS 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTD GAPI 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTD LB 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTD V 1187901 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10323. 000 NPHI. CNTD 34. 721 NRAT. CNTD 5. 244 CRAT. CNTD NCNT. CNTD 3020. 747 FCNT. CNTD 576. 000 CFTC. CNTD 543. 492 CNTC. CNTD GRCH. CNTD -999.250 TENS. CNTD 1655. 000 CCL. CNTD O. 021 5. 602 3035. 840 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: EDITED CURVES LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMiENT: 0.5000 FILE SUMPLARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10300.0 9453.0 CNTD 10323.0 9453.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GR.BCS PASS NUMBER: BASELINE DEPTH 88888.0 10296.0 10290.0 10286.0 10275 5 10259 5 10254 5 10234 5 10215 0 10202 0 10167 5 10153.5 10135.0 10105.0 10044.5 10008.5 9960.0 9908.0 9845.5 9830.0 9824.0 9812.5 9792.5 9785.5 9776.5 9764.5 9757.0 9737.5 9716.0 9698.0 9687.0 9663.0 9646.5 9639.5 9626.0 9620.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTD 88888.0 88888.0 10296.0 10296.0 10290.0 10290.0 10286.0 10286.0 10276.5 10276.5 10261.5 10261.5 10254.0 10254.0 10234.5 10234.5 10215.5 10215.5 10202.5 10202.5 10168.5 10168.5 10155.0 10155.0 10136.0 10136.0 10106.0 10106.0 10044.5 10044.5 10009.0 10009.0 9960.5 9960.5 9908.5 9908.5 9846.0 9846.0 9830.5 9830.5 9824.5 9824.5 9813.5 9813.5 9793.0 9793.0 9786.0 9786.0 9776.5 9776.5 9764.5 9764.5 9758.0 9758.0 9738.5 9738.5 9715.5 9715.5 9699.5 9699.5 9688.0 9688.0 9664.0 9664.0 9647.5 9647.5 9640.5 9640.5 9626.5 9626.5 9621.0 9621.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 9613.5 9614.0 9607.0 9607.5 9600.5 9600.5 9596.0 9596.0 9588.0 9588.0 9583.5 9583.5 9572.5 9572.5 9567.5 9567.0 9554.0 9553.5 9513.0 9513.5 9508.0 9509.0 9496.5 9496.5 100.0 100.0 9614.0 9607.5 9600.5 9596.0 9588 0 9583 5 9572 5 9567 0 9553 5 9513 5 9509.0 9496.5 100.0 REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR CNTD PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CNTD PASS #3 TO THE BASELINE G~ RAY PROVIDED BY THE CLIENT (GR.BCS) ; AND CNTD PASS #3 NPHI TO GR.BCS. ALL OTHER CNTD CURVES WERE CARRIED WITH THE NPHI SHIFT. NOTE: GR.BCS WAS USED AS THE BASE CURVE FOR SHIFTING CNTD PASS #3 TO MAXIMIZE THE DEPTH CONTROL INTERVAL. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 10 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 3 1 1 4 68 0000000000 DEPT FT 1187901 NPHI CNTD PU-S 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTD 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTD 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTD CPS 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 FCNT CNTD CPS 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTD CPS 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTD CPS 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTD GAPI 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTD LB 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTD V 1187901 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10323. 000 NPHI. CNTD 35. 535 NRAT. CNTD 5. 367 CRAT. CNTD NCNT. CNTD 2885. 771 FCNT. CNTD 537. 678 CFTC. CNTD 507. 333 CNTC. CNTD GRCH. CNTD -999. 250 TENS. CNTD 1664. 000 CCL. CNTD O. 000 DEPT. 9453. 000 NPHI. CNTD 39. 626 NRAT. CNTD 5. 714 CRAT. CNTD NCNT. CNTD 2694. 737 FCNT. CNTD 471 . 579 CFTC. CNTD 444. 965 CNTC. CNTD GRCH. CNTD 970.240 TENS. CNTD 1524. 000 CCL. CNTD O. 000 5. 695 2990. 382 6. 152 2729. 926 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 11 FILE HEADER FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTD $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 40 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CFTC CNAV CPS 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 C$FfC CNAV CPS 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTD GAPI 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 TENS CNTD LB 1187901 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10323. 000 NPHI. CNAV 35. 970 NRAT. CNAV 5. 399 CRAT. CNAV NCNT. CNAV 3130. 780 FCNT. CNAV 579.168 CFTC. CNAV 546. 482 CNTC. CNAV GRCH. CNTD -999.250 TENS. CNTD 1713.000 DEPT. 10147.000 NPHI. CNAV 16.186 NRAT. CNAV 2.929 CRAT. CNAV NCNT. CNAV 5393. 020 FCNT. CNAV 1841. 064 CFTC. CNAV 1737.165 CNTC. CNAV GRCH. CNTD 17. 869 TENS. CNTD 1675. 000 5. 744 3185.256 3.238 5447. 983 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01COI DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE . FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 13 FILE SUR~UkRY VENDOR TOOL CODE START DEPTH CNTD 10349.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTD COMP. NEUTRON $ STOP DEPTH 10146.0 1 -MAY- 98 8C0-609 1504 1 -MAY-98 10329.0 10327.0 9450.0 10324.0 1800.0 NO TOOL NUMBER CGRS-A 863 CNT-D 146 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10475.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER & METHANOL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -50 FAR COUNT RATE HIGH SCALE (CPS): 3950 NEAR COUNTRATE LOW SCALE (CPS): 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 14 NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): 20000 REMARKS: TIED INTO SWS BHCS DATED 16-DEC-86. PUMPED 613 BBLS SEAWATER AND 80 BBLS METHANOL TOTAL. LOGGED A TOTAL OF 8 PASSES ATTEMPTING TO KEEP BACK THE GAS. HAD TO LOG WHILE PUMPING 5 BBL/MIN SEAWATER TO GET ANY REPRODUCIBILITY. LOGGED ONE LONG PASS AND AND TWO REPEAT (SHORT) PASSES DUE TO FLUID CONSUMPTION. LOGGING ATTEMPTS #6, #7, & #8 EQUAL PASSES #1, #2, & #3 RESPECTIVELY. THE CHANGE IN APPEARANCE OF GAS FROM 10180' ON PASS #1 TO 10145' ON PASS #3 SUGGESTS POSSIBLE POOR CEMENT, VERTICAL PERMIABILITY, LEAKING PACKER OR SLIDING SLEEVE. LOGGED ON SANDSTONE MATRIX. FIELD PICK GOC @ 10239' FiD. TAGGED TD AT 10327'. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 15 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 RTNR PS1 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 RCFT PS1 CPS 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PSI CPS 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 CCL PS1 V 1187901 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 10349.500 NPHI.PS1 24.469 RTNR.PS1 4.000 TNRA.PS1 RCNT. PS1 4000.000 RCFT. PS1 1000.000 CNTC. PS1 4103.672 CFTC. PSi GR.PS1 55.938 TENS.PSi 966.000 CCL.PS1 -0.010 DEPT. 10145.500 NPHI.PS1 16.333 RTNR.PS1 3.029 TNRA.PS1 RCNT. PS1 5232.067 RCFT. PS1 1727.088 CNTC. PS1 5507.610 CFTC. PSi GR.PSi 21.343 TENS.PSi 1637.000 CCL.PS1 -999.250 4.349 943.563 3.258 1629.616 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 16 FILE HEADER FILE NUMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: O. 5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTD 10345.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10145.5 1 -MAY-98 8C0- 609 1504 1 -MAY-98 10329.0 10327.0 9450.0 10324.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMSLA RAY CNTD COMP. NEUTRON $ TOOL NUMBER ........... CGRS-A 863 CNT-D 146 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10475.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER & METHANOL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNTRATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 17 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -50 FAR COUNT RATE HIGH SCALE (CPS): 3950 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS BHCS DATED 16-DEC-86. PUMPED 613 BBLS SEAWATER AND 80 BBLS METHANOL TOTAL. LOGGED A TOTAL OF 8 PASSES ATTEMPTING TO KEEP BACK THE GAS. HAD TO LOG WHILE PUMPING 5 BBL/MIN SEAWATER TO GET ANY REPRODUCIBILITY. LOGGED ONE LONG PASS AND AND TWO REPEAT (SHORT) PASSES DUE TO FLUID CONSUMPTION. LOGGING ATTEMPTS #6, #7, & #8 EQUAL PASSES #1, #2, & #3 RESPECTIVELY. THE CHANGE IN APPEARANCE OF GAS FROM 10180' ON PASS #1 TO 10145' ON PASS #3 SUGGESTS POSSIBLE POOR CEMENT, VERTICAL PERMIABILITY, LEAKING PACKER OR SLIDING SLEEVE. LOGGED ON SANDSTONE MATRIX. FIELD PICK GOC @ 10239' FID. TAGGED TD AT 10327'. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 18 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 RTATR PS2 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1187901 O0 000 O0 0 6 1 I 4 68 0000000000 RCFT PS2 CPS 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1187901 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10345.500 NPHI.PS2 24.469 RTNR.PS2 4.000 TNRA.PS2 RCNT. PS2 4000.000 RCFT. PS2 1000.000 CNTC. PS2 4103.672 CFTC. PS2 GR.PS2 0.000 TENS.PS2 1051.000 CCL.PS2 -0.019 DEPT. 10145.000 NPHI.PS2 16.839 RTNR.PS2 3.198 TNRA.PS2 RCNT. PS2 5063.291 RCFT. PS2 1583.158 CNTC. PS2 5399.821 CFTC. PS2 GR.PS2 20.738 TENS. PS2 1626.000 CCL.PS2 -999.250 4.349 943.563 3.327 1493.810 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 19 FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUF~VZARY VENDOR TOOL CODE START DEPTH CNTD 10345.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) '. LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 9451.0 1 -MAY-98 8C0-609 1504 1 -MAY-98 10329.0 10327.0 9450.0 10324.0 1800.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTD COMP. NEUTRON $ TOOL NUMBER CGRS-A 863 CNT-D 146 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 10475.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEA WATER & METHANOL NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL SANDSTONE 2.65 BLUELINE COUNTRATE NORMALIZATION IN OIL ZONE LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 20 TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): -50 FAR COUNT RATE HIGH SCALE (CPS): 3950 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 20000 TOOL STANDOFF (IN): REMARKS: TIED INTO SWS BHCS DATED 16-DEC-86. PUMPED 613 BBLS SEAWATER AND 80 BBLS METHANOL TOTAL. LOGGED A TOTAL OF 8 PASSES ATTEMPTING TO KEEP BACK THE GAS. HAD TO LOG WHILE PUMPING 5 BBL/MIN SEAWATER TO GET ANY REPRODUCIBILITY. LOGGED ONE LONG PASS AND AND TWO REPEAT (SHORT) PASSES DUE TO FLUID CONSUMPTION. LOGGING ATTEMPTS #6, #7, & #8 EQUAL PASSES #1, #2, & #3 RESPECTIVELY. THE CHANGE IN APPEARANCE OF GAS FROM 10180' ON PASS #1 TO 10145' ON PASS #3 SUGGESTS POSSIBLE POOR CEMENT, VERTICAL PERMIABILITY, LEAKING PACKER OR SLIDING SLEEVE. LOGGED ON SANDSTONE MATRIX. FIELD PICK GOC @ 10239' ~iD. TAGGED TD AT 10327'. THIS FILE CONTAINS THE RAW CNTD DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 44 4 66 I 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 23 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 21 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 NPHI PS3 PU 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 RTNR PS3 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 TNRA PS3 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 RCNT PS3 CPS 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 RCFT PS3 CPS 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 CNTC PS3 CPS 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 CFTC PS3 CPS 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3 LB 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 CCL PS3 V 1187901 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 10345.000 NPHI.PS3 8.415 RTNR.PS3 2.000 TNRA.PS3 RCNT. PS3 2000.000 RCFT.PS3 1000.000 CNTC. PS3 2051.836 CFTC. PS3 GRIPS3 55.938 TENS.PS3 1063.000 CCL.PS3 0.010 DEPT. 9450.500 NPHI.PS3 37.887 RTNR.PS3 5.857 TNRA.PS3 RCNT. PS3 2767.933 RCFT. PS3 472.574 CNTC. PS3 2742.941 CFTC. PS3 GR.PS3 440.278 TENS.PS3 1507.000 CCL.PS3 -999.250 2.175 943.563 5. 961 445. 903 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/08/25 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : * * * * TAPE TRAILER * * * * SERVICE NAME : EDIT DATE : 98/08/25 ORIGIN : FLIC TAPE NAME : 98435 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : BP EXPLORATION, PRUDHOE BAY, G-24, API #50-029-21671-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 25-AUG-1998 10:33 PAGE: 22 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/08/25 ORIGIN : FLIC REEL NAME : 98435 CONTINUATION # : PREVIOUS REEL : CO~4ENT : BP EXPLORATION, PRUDHOE BAY, G-24, API #50-029-21671-00 m i 3.553 2~,7~7 ' '39'1. 095 _::].':. ~ 35 ' ~.'-* .~ 1 Z 5.723 11333.]33 -17,957 ~,1~ 7~8 ~,531 6.6~?- 1~,. 7~6 33i, 391 3.17~ :3.535 3.3~9 1 1 ~, ]6- 53:3: 2.33] 3.33? 15.535 15.313 1.3]~ ~?..1~] 1,915 1,10.~ 55.~9] S~] SSN LS~I 3.535 l~.Jll 3.q55 ~.~I$ 2.523 3.4~5 17'S~ 2.~B1 ,, -112.¢~¢ 33.¢97 ~_Z.351 2.g25 t175~.-3]3 -33.721 115.~_53 ~.353 t~.5~ 1155~.]]3 -52.55] 23.550 1].'355 15.271 51 , ;, ;,5 92.53? 17~1 5:;~ 595 Z15.;~+ ~3 577. 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