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198-015
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS SEP ( q 1. Operations Performed u fl �ry'❑ Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing M Operetiona-$ n M, - —° ': Fw�,e1 Suspend ❑ Perforate 11 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Reddll ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other. ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development 0 Exploratory ❑ 5. Permit to Dnll Number 198-015 3. Address. P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service 6. API Number: 50-029-22860-00-00 7, Property Designation (Lease Number): ADL 028302 & 028301 & 028300 8. Well Name and Number: PBU L141 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. LISBURNE OIL 11. Present Well Condition Summary: Total Depth: measured 14696 feet Plugs measured 12984, 13026 feet true vertical 10100 feet Junk measured 12926, 12940 feet Effective Depth: measured 12984 feet Packer measured 6246, 11113, 11289, 12960 feet true vertical 9303 feet Packer true vertical 5303, 8506, 8587, 9292 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20" 41-121 41-121 3060 1500 Surface 5102 13-3/8" 40-5142 40-4555 5020 2260 Intermediate 11187 9-5/8" 37-11224 37-8557 6870 4760 Liner 2043 7" 11030-13073 8465-9342 8160 7020 Liner 1324 4-1/2" 12976 - 14300 9299-9897 8430 7500 Perforation Depth: Measured depth: 11480 - 14258 feet True vertical depth: 8687-9876 feet 4-1/2" 12.6# 13CR85/13Cr80 / 35-11449/ 35-8671/ Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 12960 - 13039 12960 - 13039 Packers and SSSV4-1/2" HES TNT Perm Packer 6246 5303 (type, measured and 4-1/2" HES TNT Penn Packer 11113 8506 true vertical depth) 4-1/2" Baker S-3 Packer 11289 8587 3-1/2" Baker Packer 12960 9292 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: 759 14292 1442 2100 862 Subsequent to operation: No Test Available 14. Attachments: (required per 20 nac 25,070 25W1, &25,283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ I GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-061 Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: IM Speci list Contact Email: Ryan.Ciolkosz(0bp.com Authorized Signature: Date: �I Contact Phone: +1 907 564 5977 Form 10.404 Revised 04/2017 0/`� XT; q T� 1///7 ABOMSi�✓SP 2 0 2019 Submit Original Only Daily Report of Well Operations PBU L1-31 T/I/O=SSV/650/150, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS), pre pulling unit. PPPOT-T: Stung into test port (750 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port (200 psi), bled to 0 psi. Monitored for 10 min, no change in pressure. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). 4/1/2019 Bled void to 0 psi. T/I/O = 150/650/190. Temp = SI. BIC Line Injectivity Test (Pulling Unit). No AL. Pumped -2 gallons hydraulic fluid down both balance and control lines @ 4500 psi max pressure. Both line pressures dropped to -350 psi when pump was shut down. Assisted CIW with wellhead testing. 4/1/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:30. T/1/0=435/635/190 Temp= S/I (LRS Unit 42 - OA Integrity Test) Pumped 15.7 bbls crude down OA to reach test pressure of 1100 psi. After 5 min OA lost 83 psi with no visible leaks at surface kit. Bled OAP. Bled back - 1.5 bbls. Valve positions= SV, SSV, WV= closed IAC, OAC MV= Open 4/3/2019 FWHP= 328/634/369 T/110=150/640/170 Temp=Sl (LRS Unit 72 - MIT -T& OA Integrity Test) MIT -T to 2572 psi ***PASS*** Target pressure=2500 psi Max applied pressure=2750 psi. Pumped 3.5 bbls crude down Tbg to achieve test pressure of 2724 psi. Tbg lost 118 psi in 1st 15 mins and 34 psi in 2nd 15 mins for a total loss of 152 psi in 30 min test. Bled Tbg to 200 psi and got back - 4 bbls. Experience MDAS computer issues, LRS 42 taking over for OA integrity test. 4/3/2019 FWHP=435/635/190 ***WELL S/I ON ARRIVAL*** (PRE-RWO) INITIAL TWO = 300/650/300. MIRU & PT. PUNCH TBG 11,190'- 11,195'W/ 1.56" 4 SPF, 0 DEG PHASE, MEDIUM CHARGES. ALL LOGS TIED INTO TBG TALLY DATED 01 -FEB -2008 RIG DOWN FOR THE NIGHT. 4/7/2019 ***JOB CONTINUED ON 08 -APR -2019*** ***JOB CONTINUED FROM 07 -APR -2019*** (PRE-RWO) CUT 4-1/2" TBG AT 11 204' MD W/ 2.5" POLLARD RCT CUTTER. ALL LOGS TIED INTO TBG TALLY DATED 01 -FEB -2008 WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 1060/650/300. 4/8/2019 ***JOB COMPLETE 08 -APR -2019*** T/1/0=975/635/300 Temp=Sl LRS Unit 42 - Circ Out TxIA Pumped the following down tubing with IA returns to production HDR via L1-27 outlet well: 5 bbls 60/40 spear, 1080 bbls freshwater, 38 bbls diesel TBG freeze protect. Bullheaded 134 bbls diesel down IA with returns to PC leak. freeze protect choke trailer, hardline, outlet well flowline with 10 bbls 60/40. Swab, SSV=Shut. MV=Open. IA,OA=OTG 4/17/2019 FWHPS=900/1000/180 T/1/0=500/500/25 Set 4" CIW "H" BPV #141. Performed LTT...Pass, N/D upper tree, N/U Dryhole tree Temp #10 with blind on top. Torqued to API specs. Set VR plug in front side OA. N/D OA valve from front side, N/U on backside. Installed integrals on backside IA and OA valves. PT'd tree through tree cap blind... Pass. PT'd OA valve against VR plug... Pass. PT'd front side OA blind against VR plug... Pass. PT'd both backside IA & OA integrals against 4/19/2019 Iclosed valves... Pass. see "Field Charted Tests" FWP's BPV/500/25 see log for details. Daily Report of Well Operations PBU L1-31 TWO = BPV/510/150. Temp = SI. Bleed WHPs to 0 psi (Pre Pulling Unit). No AL, wellhouse or flowline. Dry hole tree. IA FL @ surface. OA FL @ near surface. Bled IAP to BT from 510 psi to 500 psi in 20 min (Fluid, 4 bbls). Bled OAP to BT from 150 psi to 0 psi in 1 hr (Gas to energized fluid, 3 gal). Monitored for 30 min. OAP increased 10 psi. Final WHPs = BPV/500/10. 7/29/2019 SV = C. MV = O. IA, OA = OTG. 11:30 T/I/O = BPV/500/20. Temp = SI. WHPs (Post bleed). No AL, wellhouse or flowline. Dry hole tree. IA FL @ surface. IAP unchanged, OAP increased 10 psi overnight. 7/30/2019 SV = C. MV = O. IA, OA = OTG. 16:15 Move pulling unit Sub complex from Peak to PBOC Scales @ 1800 hrs (start move/Stby rate). Meet Bell Survey and weigh unit to obtain bridge permits. Stby for Tool Service to mat pipeline 8/12/2019 crossings on route to L1-31 Move sub complex from Peak yard to weight scales. Obtain weights. Wait on Tool Service to lay mats over pipe lines and culverts. Move on well. Spot and connect modules, Derrick inpsection, spot caltwalk and beaver slide. Take on 697 bbls of 1235 bbls 9.8 brine. Well Sppt RU for circ out. Will tie-in tbg after BPV pulled. Sent AOGCC test notice. Sent Z-20 move notification. SCE review in progress Note Start move from Peak yard at 18:30 hrs 8/12/19. 8/13/2019 24 Hr Summary: Continue rigging up - trouble shoot Gas monitoring system (6 hrs NPT) Troubleshoot CanRig. Continue w/ small RU items related to new trailer. Valve shop pull BPV. Complete SCE Review /Update. Accept rig @ 12:00 Hrs. Well Sppt complete circ -out RU. Troubleshoot MM flowmeter in choke trailer. PJSM circulating out diesel, swap fluid to 9.8# 8/14/2019 brine. T/I/O=BPV/500/0 Pulled 4" CIW "H" BPV #141 through dryhole tree for AAO Rig.Tagged @ 8/14/2019 90". FWP's 500/500/0 see to for details T/1/0=0/0/0 Set 4" CIW " H' TWC #430 through dryhole tree for AAO. FWP's TWC/0/0 see 8/15/2019 log for details. 24 Hr Summary: PJSM: Complete circulating well to 9.8 brine. 1.5 wellbore volumes. Losses 15 bbls/hr while circulating T x IA @ 2.2 bpm. 135 psi tbg and 27 psi IA w/ wide open choke. 9.8 ppg in and out.Monitor for no -flow. Well on slight vac (170 psi over -balanced). Maintain continuous hole fill in IA @ 9 bbls/hr Set and testTWC 3900 psi above and 450 psi from below w/ rolling test @ 2.5 bpm (used 22 bbls). Remove dryhole tree. Terminate Control Lines. Check hanger threads (good). Take delivery of remainder of new tbg and completion equipment. NU BOPS. Change out studs on lower flange of double gate. 24 Hr Forecast: Complete stud change out, nipple up BOPE, test BOPE, unseat hanger, lay 8/15/2019 down tbg. 24 Hour Summary: PJSM: Maintain continuous IA hole fill @ —9 bbl/lir-.Change out studs on lower flange of the double gate, N/U to well head, N/U HCR valves, Choke and Kill Hose, Connect koomey hoses, Lost one leg of generator. Continue gravity hole fill @ —4.5 bbls/hr. Peak electrician, Peak completed trouble shooting the electrical system, plug changed out and rotation checked, system back running properly.Peak completed trouble shooting the electrical system, plug changed out and rotation checked, system back running properly, Complete rigging up for BOPE test, fill system with wate shell test 250 psi low, 3500 psi high. 24 hr Forecast Complete BOPE test, pull TWC, pull hanger to floor, circulate BU, lay down tbg 8/16/2019 land control lines. Daily Report of Well Operations PBU L1-31 24 Hr Summary: PJSM: Fill stack and lines to tanks, full shell test including mud line back to pump. Leak on Vam thread on test joint, change out pup, fill stack, shell test, notify Bob Noble of good shell test, continue testing, rig dwn test eq, make up safety jt, make up lubricator extensions for lubricator, rig up to pull TWC, test lubricator 250 lo, 2500 hi, good test, pull TWC, rig down lubricator, Make up landing jt into hanger, back out lock downs. 8/17/2019 24 Forecast: Pull and lay dwn hanger, CBU, lay dwn tbg as per well plan. 8/18/2019 Pulled 4" H TWC #430 through stack w/ 20' of ext @62'. RDMO. ***Job Complete*** 24 Hr Summary: PJSM: Pulled on tbg, worked pipe until it pulled free @ 170K partial cut, L/D hanger and landing jt, repair riser leak, rig up and CBU, Start to pull Tbg. Tripping / Evac drill. Repair emergeny horn, prep safety jt. Repair charge pump. Continue LD Tbg F/ 11,000' T/ 9324', L/D SSV, clear floor of control line spool, L/D F/ 9324'T/ 7284'. 24 hr Forecast: Finish laying down completion, pick up Baker packer, RIH to 7450' and test 8/18/2019 annulus to confirm casing leak depth. 24 hr Summary: CBU in attempt to recover two lost control line bands w/o success. L/D tbg F/ 7284'. Note some scale on pipe from hole depth 7120' - 7730. OCN to changer test packer setting depth to 7050' and upper production packer @ 7000'. Set 8.75" ID wear bushing. RU hyd pressure gauges to obtain Pulling Unit weight for bridge permit application. Clear and clean floor, pick up Baker EARSP, RIH with 4.5 Vam Top tbg F/ surface, T/ 1600'. 24 hr Forecast: RIH to 7050', set packer, test annulus to 3500 psi for 30 min, release packer, 8/19/2019 POH laying down tbg, RIH with completion. PJSM: RIH F/ 1600'.Set Baker EA Storm Packer @ 7050' mid -element. S/O 52k PU 68K. Attempt to PT IA to 2900 psi. 6 bbls to bbls to reach 1700 psi. SD. Pressure fell to zero in 5 mins. Establish LLR @ .35 bpm # 330 psi. Continue to pump and note returns from tbg. PUH and repeat tests @ 7015, 6891', and 6765' - Fail. TOH to 6000'. Good test to 2750 psi @ 6000'. Release packer and TIH. 6504' good charted test 2800 psi, RIH F/ 6504'T/ 6661' to test area again and confirm leak at 6661'.Set packer, closed annular, well started taking fluid @ 980 psi returns up the tbg, TOH laying down 4.5 Vam Top tbg. F/ 6661' T/ 6200' 8/20/2019 24 hr Forcast: ToH laying down tbg, rig up and run Calipher log, ***SLICKLINE SWCP #4522 RIG ASSIST AAO III*** RAN REED 40 ARM CALIPER FROM 7,200- SLM TO RIG FLOOR (good data) 8/21/2019 ***JOB COMPLETE*** PJSM: TOH F/ 6200' . LD Packer (no damage or visual wear). RU Slickline and run caliper from 7200', Run logs, rig dwn SL, (PULL WEAR RING) Prep for completion run, Run completion as per plan and Tally. 24 hr Forecast: RIH with 4.5 completion, space out tbg, land tbg, reverse in annular packer 8/21/2019 fluid. PJSM: RIH with 4 1/2" com letion Space out and land tbg hanger. Observed both sets of shear pins in the Overshot shear 8-9 K. Space out tbg, land hanger, RI lock downs, rig up and reverse circulate KI -3869 brine down IA. 24 hr Forecast: Complete placement of inhibitor in IA, wash off nipple face with 5 bbl dwn the 8/22/2019 tbg, drop ball and rod, set packers, test IA, Daily Report of Well Operations PBU L1-31 T/1/0=7/3/99 Temp=Sl (LRS Unit 76 - Assist American Pulling Unit: Set Packer, Freeze Protect, Test TWC) MIT -T PASSED to 3501 psi. (Max = 3600 psi, Target = 3500 psi) Pump 2.25 bbls 9.8# Brine into Tbg. to reach pressure. 1 st 15 min last 65 psi. 2nd 15 min lost 17 psi for a total loss of 83 psi in 30 min Bled IA to 2000 psi. CMIT-TxIA PASSED to 3500 psi. (Max = 3600 psi, Target = 3500 psi) Load IA w/ 13.5 bbl 9.8# Brine. Tbg tracked IA after 2600 psi. 1 st 15 min TAA loss of 26/27 psi. 2nd 15 min TAA loss of 10/11 psi for a total loss TAA of 36/38 psi. Pump 5 bbls 9.8# Brine down IA up TBG. 5 bbls brine down TBG up IA to confirm DCR valve shear. Freeze Protect down IA w/ 37 bbls diesel. U -Tube Freeze protect into Tbg. for 1 Hour. Well Support set 2 -Way Check set. Pump 4.6 bbls diesel down IA to pressure IA to 3500 psi for 5 Min. TWC test PASS, Bleed down pressures. 8/23/2019 FWHP=0/0/96. PJSM: Reverse circulate KI -3869 inhibitor down the IA, P/U landing joint and drop ball and rod, Call out Fullbore to set packer, set packer, good tbg test 30 min, Decision to continue with CMITAA to prove PKR set and compatant annular space to 3600 psi. Pumped 5 bbls each way to confirm DCK sheared completey, freeze protect well, 37 bbls diesel, let u -tube 1 hr, set TWC, tst TWC, blow down lines and rig dwn lines to tanks choke manifold, nipple down 8/23/2019 BOPE, PJSM: New crew back from days off, brought the crew up to date, walked through plan forward. Move BOP to moving cradle, NIU dry hole tree, test hanger void (good), leak tight test of tree (Good), pick up cellar area install gauges on OA and IA, leave both open for 8/24/2019 remote monitoring. Rig released at 06:00 hrs 8-24-19. PERFORATION SUMMARY REF LOG FM ON 03117/98 ANGLEAT TOP PERF: 58-@11480- Note: Refer to ProdwfiDn DB for historical pert data S¢E SPF INTERVAL OpNSaz DATE SEE PAGE 2 FOR PERFORATION DATA I 1399T I 4-12' LNR 12.6#, L -BO TBT, .0152 bpf, D = 3.958' I DATE FtEVBY1 COMMENTS DATE REV BY COMMENTS 0340198 POOL 7 ORTGNAL COWLETTON 03115/16 GClJMD CORRECTED PERF DEPTHS 10188 RN1O 0121/19 EPD/JMD SET PXN PLUG 01!16119 01108108NOES RVYO 0122119 JMC4JMD GLV C!O 1/12/19 0521/15 CJW PJC DMYSTAS # 1 & #2 04/17119 SIJMD TBG PUNCH & CUT 04A78119 0523/15 CJ W PJC DMY STA #2 0829!19 10 O 111 INTERVENTIONS RWO 0824/19 082&15 GSlJM GLV CK) OBA9115 09119119 CJWJMD PULLED PXN PLUG, SET FISH BP Exploration (Alaska) DATE 0822/19 0822/19 LHEA1 JATOR ELEV LEV = C1W L1-31 1= FMC BAKERC PERFS 53.8' Max An le = 72'(M 12657' Dakxn MD= 12,059. Awn- cc PERFORATION SUMMARY Fill LOG FM ON 03/17/98 ANGLEAT TOP PERF: 58" @ 11480' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2-7/8' 6 11480 - 11500 O 06/13/11 0828115 GS/JM GLV C/O 08)09/15 2-12' 1 11480 - 11510 O 10/04/99 2-7/8" 6 11500 - 11520 O 06/13/11 2-7/8" 6 11520 - 11530 O 06/11/11 2-1/8' 1 11652-11683 O 09/12/99 2-12' 6 11680 - 11692 O 07/14/02 2-1/8" 2 11683 - 12638 O 09/13/99 2-12' 6 11734 - 11757 O 07/14/02 2-12' 6 11787 - 11797 O 07/14/02 2-12" 6 11842 - 11863 O 07/13/02 2-12" 6 12110 - 12126 O 07/13/02 2-12" 6 12250 - 12266 O 07/13/02 2-1/8' 1 12638 - 12703 O 09/13/99 2-1/8" 1 12718 - 12831 O 09/11/99 4-12" SLTD 12995 - 13363 C 10/03/98 4-12' SLTD 13728 - 14258 C 10/03/98 4141b, SAFETY NOTES: WELL ANGLE> 70-g 12398' —4.172 -CHROME TBG"' DATE REV BY COMMENTS DATE REV BY COMMENTS 03A098 POOL 7 ORIGINAL COMPLETION 03/15/16 GC/JMD CORRECTED PERF DEPTHS 10/98 RWO 0121/19 EPD/JMD SET PXN PLUG 01/18119 01106108 NOES RWO 0122119 JMGIJMD GLV C/O 01/12119 0521/15 CJN/ PJC DMY TA'S # 1 & # 2 04/17!19 AS/JMD TBG PUNCH & CUT 04/08/19 0523/15 CJN/ PJC DMY STA #2 08/29/19 AAO-1111NTERVENTIONS RW0 0824119 0828115 GS/JM GLV C/O 08)09/15 09719119 CJWJMD PULLED PXN PLUG, SET FISH LISBURNE UNIT WELL: L1-01 PERMIT No: 1980150 API No: 50-029-22860-00 T11N. R14E_ 2199' FNI R 7s?s BP Exploration (Alaska) THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean McLaughlin Engineering Team Lead BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Lisburne Oil Pool, PBU LI -31 Permit to Drill Number: 198-015 Sundry Number: 319-061 Dear Mr. McLaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such farther 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 111day of February, 2019. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well 0 Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing 0 Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska). Inc 4. Current Well Class: Exploratory ❑ Development 0- 5. Permit to Drill Number 198-015 - 3. Address: P.O. Box 196612 Anchorage, AK 99519-8612 Stratigraphic ❑ Service ❑ 8. qpl Number: 50-029-22860-00-00 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 ❑ No 0 PBU LI -31 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028302. 028301 & 028300 PRUDHOE BAY, LISBURNE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14696 10100 11378 8632 2335 11378,12984,13026 12926 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 20" 41-121 41-121 3060 500 Surface 5102 13-3/8" 40-5142 40-4555 4930 2270 Intermediate 1 11187 9-5/8" 37-11224 371 6870 4760 Liner 2043 7" 11030 - 13073 8485 - 9342 8160 7020 Liner 1324 4-1/2" 12976 -14300 9299-9897 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11480- 13997 8687 - 9750 4-1/2" 12.8# / 2-7/8" 6.5# 13Cr80 / L-80 35 - 11449 / 12960 - 13039 Packers and SSSV Type: 4-1/2" Baker S-3 Packer Packers and SSSV MD (it) and TVD (ft): 11289/8587 3-1/2" Baker D Packer 12960 / 9292 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Clam after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: July 1, 2019 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz, Ryan R be deviated from without prior written approval. Contact Email: Ryan .Ciolkoszobp-com Authorized Name: Mdaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Engineering Team Lead - CTD 8 RWO Authorized Signature: �•�� Date: V.-IzO I I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integri�y ❑ BOP Test ld" Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑—/ Spacing Exception Required? Yes ❑ No <Y Subsequent Form Required: �Q •� y0 APPROVED BYTHE Approved by COMMISSIONER COMMISSION Date. N Form 10-403 Revised 04/2017 l ORIGINAL RBDMS`:A__r Z O 2019 vnw Submit Form and Approved application is valid for 12 months from the date of approval. Attachments in Duplicate To: Alaska Oil & Gas Conservation Commission 1N0Off From: Ryan Ciolkosz 0 b ,1� r n RWO/CTD Engineer ij,♦ Date: February 5, 2019 Re: L1-31 Sundry Approval Sundry approval is requested to perform a tubing swap on L1-31 to restore IA integrity to the production casing History and current status: L1-31 was completed as a Wahoo producer in September 1999. In early January the well test water cut jumped unexpectedly and follow-up diagnostics found a production casing leak at -7600' MD that was producing large amounts of water into the IA and through a gas -lift valve. Once discovered the well was immediately shut-in and declared non-operable. A tubing tailpipe blanking plug has been set to secure the well. Proposed plan: All American Oilfield 111 pulling unit will pull tubing and re -run a new tubing with staddle packers covering the IA leak on or around July 1st, 2019. The MASP is 2335 psi. AAO 111 BOPE will be configured as follows (BOP schematic attached for reference): • One Annular preventer • One Blind Ram -type preventer • Mud cross with outlets for choke and kill lines • One Ram -type preventer dressed with Ram or VBR depending on what pipe is being ran/pulled. Testing will be in accordance with State and BP policy of a 7 day BOP test. Testing will be 3500 psi high and v 250 psi low for all components. The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed tubing swap is attached for reference. Pre -Rig Prep Work: 1. V: PPPPOT-T/IC, function LDS, service tree valves 2. F: MIT -T 2500 psi. MIT -OA 1200psi ✓ 3. E: Tubing punch and RCT cut 4-1/2" tubing -11,207' MD 4. F: Circ well to 8.6 ppg brine & Freeze Protect 5. O: Purge control lines. If required. 6. V: Set BPV/TWC. Pre RWO Tree Work. 7. O: Bleed WHP(s) to zero. Remove the well house and flow line. Install wellhead valves as needed. Install dry hole tree. Level the pad as needed for the pulling unit. Proposed RWO Procedure: -4 v i ,,,rr L- 1. MIRU. ND tree. NU and test BOPE. Test to 3500 psi and the annular to 3500 psi. Pull TWC. 2. Circulate the well to brine and pull tubing from cut. 3. Perform test packer run and pressure test casing above leak at 7600' MD. —A,/,,C,, 4. Run new 4'/" 13Cr completion with 7" x 4.5" and 9-5/8" x 4.5" packer. MIT -T & MIT -IA to 3500 psi. 5. Freeze protect. Set TWC. ND BOPE. NU and test tree. RDMO. Post rig Work 1. Pull ball and rod and RHC sleeve 2. Set generic GLV 3. Pull plug in reducer nipple. Pull reducer nipple Ryan Ciolkosz RWO/CTD Engineer 564-5977 CC: Well File Joe Lastufka �esoe 76�i�1J 2 3 4 4'-2" o a e A A 3,_815/is" SHENKAI SL 13-5M ANNULAR 6'-10'/6" SHENKAI SL 13-5M DOUBLE RAM B 00 B 8._5„ 4,_6.118„ 11-416„ 3,_25/aN C 1'-93/ 0 C 0 10,1, sow CLOSING OPENNING VOLUME (GAL) MIN OPEN ITEMS CLOSING VOL OPENNING VOL 30° ANNULAR 23.59 17.41 DRAM 4.39 3.91 p HCR 0.40 0.40 HFOFHWTONINTMS THE CONTENTS OFTXIBCItW.WO ENERGY ME ME GRDPEESOORPESTEIiN MN AERO PROIlCT TTS sov 13-5M BOP STACK D ORANING VRAWNOi REPRCOUCTICN THIS A-000.15-002 gUMel TV MTE ' 2BlFeE201e N.T.S. M REVD ES L REFEREOTE RV FOR OMYNNG N111gUf TXE ETP(E88 RERMWUCT OPWTEWN �C""d^m 0 INTIK RELEME TY WP O1/Mn40f! Mg10YEe MJP S1TE ' 01IMer2016 A FI' 1 OF CONSTRICTION ETMeny HMCESCORP IS sTRlcnr vROHlercRn. REV DE6CRITIgi EV MGD GATE 1 2 1 3 4 TRIS_= CNV VYELLWAD- FMC ACIWTOR= 6AK92C TYPE 11030 8F E3" 2- BKR ZXP PKR D - 3.87" KOP= Y34T A4ax Angle-= _-72' _ 1265T =—._— Datum FM12.05 11 G 2 Wttm ND BK rx 9'( o 8900' SS 1 —115 1 68#, L-80 BTC, D - 12.415" H 6142- TVD DEV TYPE 11030 L7- BM TEBACK SLV, D =? 2- BKR ZXP PKR D - 3.87" 1103T 2'BKRMACLNRHGRD=? 1—� 1043' L-80 Minhnum ID = 226" @ 13026' 2-718" HES XN NIPPLE 4-12' TBG, 12.60, 13CR-80 VAM TOP, .0152 bpf, D = 3.958" 1rX5-BKR 71EBACKSLV,D=5.25' F r X 5- BKR FMC LNR F1OFi D = 4.t38' S X 4-12' XO. D - 3.958' 2-7/8' TBG, 6.5#, L-80 R1E 8RD, .0058 bpf, D = 2.441" FfY D 511..0371 buf. ]D=6.184' PERFORATION SIMMARY Fill' LOG: FM ON 03117/08 ANGLEATTOP PSE: 58' @ 114W Note: Refer to Production OB for historical pert data SIZE SPF I KrERVAL I OprVSgz I DATE SEE PAGE2 FOR PEWORATION DATA L-80 ET, .0152 bpf, ID = 3.958' 14300' TD 14880' LI -31 SSV NP. D = 3.813' GAS LFT MANORS ST M) TVD DEV TYPE VLV LATW PORT DATE 1 4766 4305 48 11 G 2 Okf/ BK 0 01112119 2 7590 6196 48 KBG-2 DMI BK 0 01112!19 3 9075 7166 48 KBG-2 DAM BK 0 1 01/02(06 4 10019 7834 46 KBG2 DMV BK 0 01/02/08 5 11006 8453 59 IW,2 DAM BK 0 01/07/08 7- X 4-1/2- BKR S-3 P KR D= 3.870- 6-12- FES X 4-10- FES XN FP D=3725" WLEG, D = 91- EP- BLOWN DOV*4-DLE ( X 3-12" BKR 0 PM D = 325' 12' X 2-71W XO PK D = 2.441' ■ ( 7JVS1f" 1--1Z-I YN-Cii,u=Z.M7- 1s037• HELm TT LOGG®1222/98 DATE REV BY COM.B4i5 DATE REV BY I OOWAENTS 03f30/98 POOL 7 ORIGINAL COMPLETION 03/15/16 GUAV CONED PEW DEPTHS RWO 01/21/19E3'D'JMD SETm PLt1G(Ot/18119) AMBS f81V001/12/19 JMG/J GLV a0 (01112/19) E05/21/1E P DhNMS#18#2 C-" P OMY STA #2 — oro (08/09+15) LBBLFM L"T VVaL Li -31 PB,MT No: '1980150 AH No: 50-029.22860-00 SEC 1, T11 K R14E, 2199 FN.. S 2525 FVVL BP Btptoragon (Alaska) FE7FOPATlOt4 St1A4MARY FEF LOG: FM ON 03117196 ANGLE AT TOP PEW: 58" Q 11480' Note: Defer to Production D6 for historical pert data SIZE SPF INTERVAL OpnISgz SHOT SOZ 2-718" 6 11480- 11500 O 06/13/11 DW( STA'S#i 2- V2' 1 11480 - 11510 O 10!0499 GLV d0 (06/09/15) 2-7/8" 6 11500- 11520 O 06/13/11 2-718" 6 11520 - 11530 O 06/11/11 2-1/8" 1 11652 - 11683 0 0911299 2-1/2' 6 11680 - 11692 O 07/14/02 2-1/8" 2 11683-12638 O MINN 2-1/2' 6 11734 - 11757 O 07/14/02 2-1/2" 6 11787- 11797 O 07/14/02 2-1/2' 6 11842-11863 O 07/13102 2-1/2" 6 12110 - 12126 0 07113102 2-112" 6 12250- 12266 0 07113/02 2-1/8" 1 12638-12703 O 0911399 2-118" 1 12718-12831 0 090199 4-1/2" SLTO 12995 - 13363 c 1010398 4-1/2" SLID 13728- 14258 c 1010398 L1-31 PERFS DATE FZFV BY COA90134TS DATE REV BY COWANTS 0313WN POOL 7 ORDINAL cOMPLETFON 03/15/16 GCJJAO CORE= FEW DEPTHS 10198 RNO 01/21119 EPCIAAD SET PXNR-UG(01/18/19) 01/06108 WES MO 01/22/19 ArdJLC GLV C/O (01112/19) 05/21/15 C" PJC DW( STA'S#i 05!23/15 CJW PJC CW STA #2 08/28/15 GLV d0 (06/09/15) LtSBLI;tE UNIT WELL: Lt -31 P9WT No. '1980150 AR No: 50-029-22860-00 SEC 1. T11 N RUE. 2199' FPL & 2529 FYVL BP Exploration (Alaska) I TRff= CKN WELLHEAD= FMC ACTUATOR= BAKB2C OKE. ELEV = 53.8' BF. ELEV = Ll-31 Proposed SAFETY NOTES: L ANGLE 70 @ 12398' KOP= 2347 70"CONDUCIOfZ Max Argle 1265T #, Datum DatunlVD= 8900'SS 133/8" CSG, 68#, L-80 BTC, D = 12.415" 6142' T BKR TEBACK SLV,D=? 11030' 7' X 4-12" BKR ZXP PKIZ D = 3.87- H1103T 7-X4-12' BKR FfX- LNR NGFZ D=? 11043- 9-5/8" CSG, 47#, L-80 BTC -M, D = 8.681" 11224' 4-12" RCT COT 11207' Minimum ID = 2.26" @ 13026' 2-7/8" HES XN NIPPLE 2 -TBG, 12.6#, 13CR-80 VAM TOP, N 11432' 52 bpf, D = 1958" X 5" BKR TIEBACK SLV, D = 5.25" I-1 12976' ( 5" BKR HMC LNR HGR, D = 4.438' 12983' 5" X 4-12" XO, ID= 3.958' 12980' 2-78T%6 .5#, L -BO EUE 8RD, - .0058 bp = 2.44T 7" LNR. 29#, L-80 HY D 511..0371 DDT. D = 6.184' PEWORATION SLM%RY REFLOGFM ON 03117/98 ANGLE AT TOP PERF: 58-@11480' Note: Refer to Production DB for historical perf data SIZE SPF I INTERVAL I OWSgz I DATE SEE PAGE 2 FOR PERFORATION DATA 4-12" LW 12.6#, L-80 IST, .0152 bpf, D = 3.958" 14300' ® 14690' FES ES CEMENTER S LET MANDRELS X NP, D=3.813" 4-12" FES X NP. D = 1813- 17"X X 4-12" HES TNT PKR 77TJ/' ��T4-�tc ronrr,u=you � 11217' 75,4-112"UNIQUE OVERSHOT 11261' 4-12" FES X NP, D = 3.813" 11272' 7- X 4-12' BKR S-3 PKR D = 3.870" 11348' 4-12" FB X NP, D = 3.813' 11378' 4-12" FES XN NP, D = 3.725- .725'4-12"VYLEG, DWY STA'S # 1  4- 1f2' VWLEG.D=3.958'1 1146T ELMD TT LOGO 06/11/11 D = 325" D = 2.441' { 12964' 1-1 TOP OF SAND (0911222)j 12994' 2-718 FES X NP, D = 2.313" 03115116 GGAU OORRECTED PERF DEPTHS 13026' 2-718" FES XN NP, D = 2.25' 13026' 2-78"PXN PLUG (09105t99) 13034' 7' FES CEMB�fTHR 13039' 2-718- WLEG, 1)=2.44Y1 13037' HamTT LOGGED 1222198 DATE REV BY ODWAWm DATE REV BY ODWARNTS 03/30198 POOL 7 ORIGINAL COMPLETION 03115116 GGAU OORRECTED PERF DEPTHS 10198RWO 0121119 94YAC SET PXN PLL1G (01/18119) 01!06(08fAGLV IBNO 0722119 JM GLV d0 (01/12719) 0521/15 DWY STA'S # 1  0523!15 DMY STA #2 o62e/1sao(oaD9ns) 10/10/99) LISBL1RrE LINT WELL L7-31 P'EF1tK No 1980150 AR No: 50-029-22860-00 11 R R14E, 2199 F NL & 2525' FVVL BP Exploration (Alaska) FEiFORATON SUINNARY RIF LOG: FM ON 03/17198 ANGLE AT TOP FE:F: 58'@ 1148(7 Note: Refer to Production EB for historical pert data SEE SPF PREiVAL Opn/Sgz SHOT SOZ 2-718' 6 11480 - 11500 0 06/13/11 0122/19.N" GLV 00(01/12/19) 2-172' 1 11480 - 11510 0 10/04/99 OW STA #2 2-7/8" 6 11500- 11520 0 06/13/11 2-718' 6 11520-IISM 0 06/11/11 2-1/8' 1 11652-11683 O 09/12199 2-12' 6 11680 - 11692 0 07/14/02 2-1/8" 2 11683- 12638 O 09113199 2-1/2" 6 11734- 11757 O 07/14/02 2-1/2' 6 11787- 11797 0 07114/02 2-1/2" 6 11842 - 11863 O 07113/02 2-112' 6 12110- 12126 0 07113102 2-112" 6 12250-12266 0 07/13102 2-118' 1 12638-12703 0 09/13199 2-118' 1 12718-12831 O 09/11199 4-1/2' SLTD 12995 -13363 C 10103198 4-112' SLID 13728 - 14258 C 10/0198 L1-31 PERFS DATE REV BY OOWM 34TS DATE REV BY COWENTS 034098 POOL 7 014GMWUL COMPLETION 03175116 GrJAU OORREUM FEE DEPTHS 1098 RINO 0121119 EFTYAU SET PRN R -UG (01/18/19) 01969& WES FWO 0122/19.N" GLV 00(01/12/19) 05/21/15 CJWPJC DM1' STA'S# 1  05/23/15 CJW PJC OW STA #2 0828115 GLV CTO (08109115) LISBURfE UNIT WELL: L1-31 FE Wff W:'1980150 AM No 50-029-22860-00 SEC 1. T11 N. R14E 2199 FTI. & 2525'M BP Exploration (Alaska) STATE OF ALASKA !ALASKA OIL AND GAS CONSERVATION COMM( N • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate m Alter Casing 0 Change Approved/ Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well CI Re-enter Susp Well 0 Other: CSG/G!5rfh lvfgfJ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number:• 198-015 3. Address: P.O.Box 196612 Anchorage, Development 0 Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: ' 50-029-22860-00-00 7. Property Designation(Lease Number): , ADL 0028300 8. Well Name and Number: , LISB L1-31 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,LISBURNE OIL 11.Present Well Condition Summary: RECEIVED Total Depth: measured " 14696 feet Plugs measured 13026 feet true vertical . 10100 feet Junk measured 12926 feet SEP 0 8 2015 Effective Depth: measured 14696 feet Packer measured 11289 feet true vertical 10100 feet Packer true vertical 8586.81 feet AOGCC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"133#H-40 41 -121 41-121 3060 1500 Surface 5102 13-3/8"68#L-80 40-5142 40-4555 5020 2260 Intermediate 11187 9-5/8"47#L-80 37-11224 37-8557 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: See Attachment feet True vertical depth: See Attachment feet � s. ,'' : AN 1 1 tui Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr8 25-11449 25-8671 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 11480'-12703.5' Treatment descriptions including volumes used and final pressure: 423 bbls of 3%kcl,78.2 bbls of 3%kcl w/336 gals of mutual solvent,273 bbls of SXE,77.4 bbls of VDA,114.8 bbls of MaxCO3;363 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 498 11935 0 2100 756 Subsequent to operation: Shut-In 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: J Daily Report of Well Operations Elf Exploratory ❑ Development p Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: .Oil I1 Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature pigaMovr Phone +1 907 564 4424 Date 9/8/15 Form 10-404 Revised 5/2015 V 7-1--- q7,1//:.1"-- ri / RBD SEP 10 2015 ry Submit Original Only • • Q,caaa0aa m Cfl O CI�fl N = O O �l) N O LO LO C N rl t` 0 y 0 00 Lr) 0 0 L O N P CO M M S O O N v- v- co co Ln CO 00 O 00 p I� N N- 10 N C)0) 0)co c00 CI I l i l l i I LONM - I� CO 0) 0) L M N N M CA O) V M O OM - N N I� M O V N N O O M - In v M • 0 nc I III CD r '4" ct M N N N CO _ - o cop O O M J J 2i M .N N M CA O `— N • W C00 U - i N O M O O c 6) N N C COO N- M N N J W H DI 0 — C1-1 W ' U N• D < 2 0 Uau ct ctz Z W W W W m Q D 1— Z Z_ Z_ D U U) Z J J J �- • a) N LO • CO O N M CO Cf) CS) N CO O M CO M O ci- CC) CO r N O r 100 M r-- (N = M M LL) CO O = _ I� M 0 M N Lf) CO CO O CD M i,- 0 CA r I- 0 ON- CO CO CO Cn 0 41 LO O r N w C) CD CD v- N- N- OD CO 00 CO LU CD C) CD CD M LC) Lf) 0 CO CO CO LC) CO N- ti co co CO o CO N- ti N- N- N- N- N- N- N M N- N- 0 OO 00 OO OO 00 0 0 OD OD M OO 00 OD O C)) CS) C) C) C) CA co co co co co co co co co co M 0 co co OD O0 00 CO OD CO OO CO M OD OD OD OD CO 00 CO OD OO OO F a O - i— W N N LC7 r N- M N ti L r m 0 CO O M c!' r r CO M d N N- CA CO N- CO 00 . 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O O ,_ Z W 1 1 Q J1 W LoLoiod fX 1 O A 11O NM MMMNNNMMOO Li IN Li_ = ,- ,- ,- ,--- ,---,- ,----,- = = .,- ..- .—_ -_ -_, cr aiI� (` — f� OaiO 6) C3) OOO ) Zd � 1U 11 W W LL W Q OJJ 2 H J J D J D r 0_ m O Y D X w J J J Q d w w < < )o (L T7 (n W LL ;n LL Cn d Q' .,—,-- = ,--- TTTT r T . . . . . . M M M M M M M M M M M M M M M M M T T T T T T . . . . . . . . . . . m a. a ac.) -1 d d W J J J J J J J J J J J J J J J J J Q Q m a) W Li Cl) Cl) a cc • • Packers and SSV's Attachment LISB L1-31 SW Name Type MD TVD Depscription L1-31 TBG PACKER 11037.16 8469.06 7" Baker ZXP Top Packer L1-31 TBG PACKER 11288.89 8586.81 4-1/2" Baker S-3 Perm Packer L1-31 TBG PACKER 12960.22 9292.35 3-1/2" Baker Model D Packer •1 _ •, cm, f j'c LFEAD= FMC L 1 '�3 1 ""4-1/2"HR M--4pry NOTES: L ANGLE>TO° 12398' 1 411 'ACTUATOR= BAKERC OKB.ELEV= 53.8' I 1989' —{4-1/2"HXO SSV NIP,D=3.813" BF.BEV= KOP= 2347' 20'CONDUCTOR, —115 I Max Angle= 72'@ 12657' # a D---120W --{13-318"HES ES CBMBdTB2 Datum MD= 12,059' _ " - D Datum TV D= 8900'SS ' GAS LFT MANDRELS 13-3/8'CSG,68#,L-80 BTC,D �,=12.415" — 5142' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4766 4305 48 KBG-2 DOE BK 16 08/09/15 7"BKR TEBAC3C SLV,D=? —1 11030' j 2 7590 6196 48 KBG-2 SO BK 20 08/09/15 3 9075 7186 48 KBG-2 DMY BK 0 01/02/08 7"X 4-1/2"BKR ZXP PKR,D=3.87" H 11037' / 4 10019 7834 46 KBG-2 MY BK 0 01/02/08 7"X 4-1/2"BKR HNC LNR HGR,D=? H 11043' 5 11006 8453 59 KBG-2 DAAY BK 0 01/02/08 9-5/8"CSG,47#,L-80 BTC-M,D=8.681' H 11224' J • 11251' H4-112"FES X NP,D=3-813" Minimum ID = 2.25" @ 13026' E 11272' H7"x4-1/2"BKR S-3PKR,D=3.870" 2-7/8" HES XN NIPPLE I I 11348' —4-1/2"Ila,XMP,D=3.813" I 11378' —14-112'HES XNNIP,D=3.725" 4-1/2"TBG,12.6#,13CR-80 VAM TOP, —{ 11432'— ' ` j 11432' H4-1/2"WLEG,D=3.958" .0152 bpf,D=3.958" — 11457' H ELM TT LOGGED 06/11/11 S.'s—. 12088' --I TMA RKB2 JOINT { 12926' —j FISH-BP-BLOWN DOWNHOLE(10/10/99) 12960' H T X 3-1/2"BKR D PKR,D=3.25" 1264' H3-1/2'X 2-7/8"XO FtN,D=2.441" 7"X 5"BKR TEBACK SLV,D=5.25" -- 12976' 7'X 5"BKR FMC LNR HGR,D=4.438" — 12983' 112984" H TOP OF SAND(09/10/99) 5"X 4-1/2"XO,D=3.958" —, 12990' R 12994' _H2-7/8 FES X NP,D=2.313" 1e' 13026' H2-7/8'I CS XN NP,D=2.25" 13026' H2-7/8"PXN PLUG(09/05/99) 4 ' D� 2-7/8"TBG,6,5#,L-80 EUE8RD, —I 13039' " .0058 bpf,D=2.441" 13034' --i7 HE5 CBIABYTER 13039' H2-718" WLEG,D=2.441" 7"LNR,29#,L-80 HYD 511,.0371 bpf,D=6.184" —I 13073' —4 I\ 13037' H ELMD IT LOGGED 12/22/98 PERFORATION SUMMARY FIEF LOG: FM ON 03/17/98 ANGLE AT TCW PERF: 58'©11480' Note:Refer to Production OB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 1 I SEE PAGE 2 FOR PERFORATION DATA I I I I 1 I I I I 13997' —1CBMBYT PLUG(04/17/99) 4-1/2"LW,12.6#,L-80 BT,.0152 bpf,ID=3.958" —{ 14300' niel TD H 14690' DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNfT 03/30/98 POOL 7 ORIGINAL COMPLETION 06/25/14 MGS/JMCI WBS CORRECTIONS WELL: L1-31 " 10/98 MVO 05/20/15 PJC SAND PLUG CORRECTION PERMIT No:'1980150 01/06/08 N4ES RINO 05/21/15 CAW PJC DRAY STA'S#1 AR No: 50-029-22860-00 03/09/09 JWPJC MAL DR.G CORRECTIONS 05/23/15 CAW PJC CMY STA#2 SEC 1,T11N,R14E, 2199'FM_&2525'FW.. 06/26/11 TM/PJC ADFEFFS(6/11-13/11) 08128/15 MGS/JAAO GLV C%O(08/09/15) 06/29/11 M-V PJC ELMD TT LOGGED(6/11/11) BP Exploration(Alaska) • L1 -31 S PERFS I I 1 1 41 1[ 1 111. 1 1 S I I . 1 1 PERFORATION SUIMMRY REF LOG:FM ON 03/17/98 ANGLE AT TOP PERF:58°@ 11480' Nate:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-718" 6 11480-11500 0 06/13/11 2-1/? 1 11480-11510 0 10/04/99 2-718" 6 11500-11520 0 06113/11 2-7/8" 6 11520-11530 0 06/11/11 2-1/8" 1 11652-11683 0 09/12/99 2-1/2" 6 11678-11690 0 07/14/02 2-1/8" 2 11683-12638 0 09/13/99 2-1/2" 6 11732-11755 0 07/14/02 ' 2-1/2" 6 11785-11795 0 07/14/02 , 2-1/2" 6 11840-11860 0 07/13/02 2-1/Y 6 12109-12125 0 07/13/02 a D 2-1/2" 6 12250-12266 0 07/13/02 2-1/8" 1 12638-12703 0 09/13/99 ' 2-1/8" 1 12718-12831 0 09/11/99 , 4-1/2" SLID 12995-13363 C 10/03/98 4-1/2" SLID 13728-14258 C 10/03/98 I I I I I I I I • • O -oC o I - o CL c •_ o rn a-m C) - I II oo CO o (n 3 '� o 0 5 >, o o '5 o N- -0 a 2 D_ OQ ON N 00 O • co a) < .C. „ N• Q N N 76 �t E a O C�co 0 O T Q C W U N Co N a) \ U) r-- r- N O O W co 2) O M (n fl m OC vi O M 2 �T1 0_ O y yi J - i 'O N N Co V O Co C N U C U _To I� W CO m a) O Q a co.. O T N cn -c /r- 00 J , H E °-Q r H LJ 0_ W c� nn a) 6 C I- z H 8 O ad a) a O w z -' so � .a) o o N � * -o a � E -o CL X *0 d CC O V Q , N N m *0 a O a. O 6 a) -2 N a) OLLI E ID O � OD U Z CC li Z O 0 o T' C a0i N'oc W W U ._ «f r (n 0 Z00 LL. � XO W QO H f (nm LV OO -) W a) O- - CO J X 2 2 m 0 � 0 E a �_ U w 1 0 c N W X a) a) IB r m �Zo � DZ poo"C o v Ev) -a0 � 0ZO °� Oo _ (n (n -o W rn (n F00 O) H Cl) o = O CO 0 p _co Q (n * g00u1O "gm * c S * U0 9-U0 ca a> NN -75U cD O J 70 - rn (>wW (0rnHm LU NW J : oT o 0w C)CCIDED N0 cim ,- 06N � t o +a. � -... _, U . "' U ♦- JU ~ m � (\' a) -6 E- �F- � O a > * > in 1 v) �v11 /��a11 m Q cn p >� CV a a ,n m r� I- _ c� Q-o c CC _ �' o '.=. J V > � Q22 VVZQ > Q2Ln > N E nj ,- ma < < .65 (n OJ � � Z Q a2SO � UOO NQ W mUO � � � � .� NNO _ d .NJ � Lim 00 0 .i � W (n7nZCC W WO � mZm > M E C2O � 4 *k -- N � Q � C 75 -I Nf OUO NOO LLr- H - QOW N ° Q `too � � a� E Ts 82 ‹t 11) Jn2O J > (n (n2ZZ0JCD mU) -a � II c\ 2 � � O �tzo� a65 � T � O CC Za_ zOoOi- oU0zZ - 00 � C'31- Z O ° NO - > 21}- W NQ a) ;O E E0 00 OvUOOoWC � OJ » cV O0 � 000 c o ¢ WD mmOo - 5 5 _ o YY � � Y W o +- - 'I W ('3O � � p c > � N U) --'' o �O0Nmm00v (n (nNmOO U o C_ �_ 000tiW (ncn O o ai a N oho J W O O 1- H D 0 Y Y 0 J _..1 0 0 11- cc 13 E Z D LLIcc 0 J N p o °'N °'25 c p W> 0 M 0 0 J J m m J W W V J J O > C j L 2 up ? O J m d. J W I I p C Cn ( M a > OZ 0UHJJIHJ5 � F- _I0) U > v) -0 . U (nI- (nJ � � O O _0 Oco � E � * - < 6OU B + U) a a &) (1) O- *r (n O- _1 : I. � N o _1 (n LIJ _j 0- : hH- � .g. � W � N- a1- * W I- Q Ln Ln in in Ln Ln Ln >- o 5 O O O O O Iin Lr) - O N N co co N N > NN N N N I- n n in in in co 0o 0 Q a v) T c � o E a1 (n T Q 0 ' 5 — M J O m N 4-• C O J cD Q a) cn CC Ts A 0 CICS a ro 0) co co Co U U 0 ) -0YY U N ? ai o o X p ❑ UZ MMCn > � N O ( O ( CO r V C N r- m CO ct N ,-- STATE OF ALASKA ALASKA ',AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ISI Exploratory ❑ ` 198 -015 3. Address: P.O. Box 196612 Stratigraphic Service p 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22860 -00 -00 8. Property Designation (Lease Number) : , 9. Well Name and Number: j ADLO- 028300 Lisburne L1 -31 10. Field /Pool(s): v PRUDHOE BAY FIELD / LISBURNE OIL POOL 11. Present Well Condition Summary: Total Depth measured 14696 feet Plugs (measured) 12984, 13026, 13997 feet true vertical 10100 feet Junk (measured) 12926 feet Effective Depth measured 13997 feet Packer (measured) 11037 11272 12960 feet true vertical 9750 feet (true vertical) 8469 8579 9292 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 42 - 115 42 - 115 Surface 5102' 13 -3/8" 40 - 5142 40 - 4555 5020 2260 Production 11187' 9 -5/8" 37 - 11224 37 - 8557 6870 4760 Liner 2043' 7" 11030 - 13073 8465 - 9342 8160 7020 Liner 1324' 4 -1/2" 12976 - 14300 9299 - 9897 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ - - i , M m JtJ� Off; True Vertical depth: _ i - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13CR -80 35 - 37 35 - 11432 2 -7/8" 6.5# L -80 12960 - 13039 9292 - 9327 Packers and SSSV (type, measured and true vertical depth) 7" Baker ZXP Top Packer 11037 8469 BKR S -3 Packer 15• 11272 8579 1 3 -1/2" Baker Model D Pa , ✓ cke � ' 12960 9292 C :114 — , ' 12. Stimulation or cement squeeze summary: Si ` r �. i% �ti��g ° Intervals treated (measured): r. ,r(,' �` .) a Treatment descriptions including volumes used and final pressure: 0",\ ` "' ?' 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 720 8614 16 707 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 i Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil .. 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Elizabeth Barker Printed Name Elizabeth Barker 7� Title Data Manager Signature Phone 564-5674 Date 7/6/2011 MS JUL 0 7 20 i` 7 O� l(r Form 10 -404 Revised 10/2010 Submit bri Only < •l� /� 9 anal Y L1 -31 198 -015 PERF ATTACHMENT Sw Name Operation Date Peri Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base L1 -31 3/30/98 SL 12,995. 13,363. 9,307.76 9,468.49 L1 -31 3/30/98 SL 13,728. 14,258. 9,626.39 9,876.08 L1 -31 4/14/98 FIL 13,370. 13,408. 9,471.52 9,487.9 L1 -31 11/7/98 SQZ 14,281. 14,465. 9,887.52 9,980.22 L1 -31 4/17/99 SQZ 13,995. 14,167. 9,748.77 9,831.27 L1 -31 9/10/99 SPS 12,984. 13,026. 9,302.91 9,321.3 L1 -31 9/12/99 APF 12,637.5 12,638.5 9,165.85 9,166.16 L1 -31 9/12/99 APF 12,631.5 12,632.5 9,164.02 9,164.32 L1 -31 9/12/99 APF 12,355.5 12,356.5 9,073.27 9,073.63 L1 -31 9/12/99 APF 12,262.5 12,263.5 9,038.23 9,038.62 L1 -31 9/12/99 APF 12,253.5 12,254.5 9,034.7 9,035.1 L1 -31 9/12/99 APF 12,239.5 12,240.5 9,029.17 9,029.57 • L1 -31 9/12/99 APF 12,121.5 12,122.5 8,980.66 8,981.08 L1 -31 9/12/99 APF 12,108.5 12,109.5 8,975.14 8,975.57 L1 -31 9/12/99 APF 11,658.5 11,659.5 8,775.45 8,775.91 L1 -31 9/12/99 APF 11,731.5 11,732.5 8,808.71 8,809.16 L1 -31 9/12/99 APF 11,651.5 11,652.5 8,772.22 8,772.69 L1 -31 9/12/99 APF 11,751.5 11,752.5 8,817.68 8,818.13 L1 -31 9/12/99 APF 11,737.5 11,738.5 8,811.41 8,811.86 L1 -31 9/13/99 APF 12,061.5 12,062.5 8,954.97 8,955.4 L1 -31 9/13/99 APF 12,702.5 12,703.5 9,186.8 9,187.15 L1 -31 9/13/99 APF 12,689.5 12,690.5 9,182.29 9,182.63 L1 -31 9/13/99 APF 12,674.5 12,675.5 9,177.31 9,177.64 L1 -31 9/13/99 APF 12,091.5 12,092.5 8,967.89 8,968.32 L1 -31 9/13/99 APF 11,866.5 11,867.5 8,868.72 8,869.16 L1 -31 9/13/99 APF 11,856.5 11,857.5 8,864.3 8,864.74 L1 -31 9/13/99 APF 11,842.5 11,843.5 8,858.11 8,858.56 L1 -31 9/13/99 APF 11,706.5 11,707.5 8,797.41 8,797.86 • L1 -31 9/13/99 APF 11,696.5 11,697.5 8,792.86 8,793.32 L1 -31 9/13/99 APF 11,688.5 11,689.5 8,789.22 8,789.67 L1 -31 9/13/99 APF 11,682.5 11,683.5 8,786.47 8,786.93 L1 -31 10/2/99 BPS 11,630. 14,465. 8,762.21 9,980.22 L1 -31 10/3/99 SPS 11,545. 11,630. 8,720.91 8,762.21 L1 -31 10/4/99 APF 11,480. 11,510. 8,687.37 8,703.07 L1 -31 10/8/99 SQZ 11,544. 11,545. 8,720.41 8,720.91 L1 -31 10/9/99 SQZ 11,542. 11,545. 8,719.4 8,720.91 L1 -31 198 -015 PERF ATTACHMENT L1 -31 10/10/99 SPR 11,542. 11,630. 8,719.4 8,762.21 L1 -31 11/2/99 BPP 11,630. 12,932. 8,762.21 9,279.87 L1 -31 6/20/01 FIL 12,896. 12,932. 9,264.22 9,279.87 L1 -31 7/13/02 APF 11,840. 11,861. 8,857.01 8,866.29 L1 -31 7/13/02 APF 12,109. 12,125. 8,975.36 8,982.14 L1 -31 7/13/02 APF 12,250. 12,266. 9,033.33 9,039.6 L1 -31 7/14/02 APF 11,785. 11,795. 8,832.64 8,837.09 L1 -31 7/14/02 APF 11,732. 11,755. 8,808.94 8,819.25 L1 -31 7/14/02 APF 11,678. 11,690. 8,784.41 8,789.9 L1 -31 12/9/07 BPS 11,133. 14,258. 8,515.54 9,876.08 L1 -31 6/11/11 APF 11,520. 11,530. 8,708.22 8,713.33 L1 -31 6/13/11 APF 11,480. 11,500. 8,687.37 8,697.88 L1 -31 6/13/11 APF 11,500. 11,520. 8,697.88 8,708.22 • AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • MINIUM • • L1 -31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/11/2011 ***WELL FLOWING ON ARRIVAL * ** (ELINE PERF) 'INITIAL T /I /O= 1200/750/410 RIH WITH MH22 /UPCT /FH /10' 2 -7/8" HSD 2906 PJO 6 SPF OAL= 19' OAW = 230# FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 3.4', PERFORATION INTERVAL 11520'- 11530', CCL STOP DEPTH= 11516.6' ! VISUAL INDICATION OF FIRE AT SURFACE INSTRUCTED BY PE TO RIG DOWN AND RETURN TO SHOP TO PREP FOR Z- 38 RIG JOB WELL LEFT SHUT IN SWAB, SSV, WING CLOSED AND OTG 1 ** *JOB NOT COMPLETE CONTINUED ON 13- JUNE - 2011 * ** 6/13/2011 CONTINUED JOB FROM 11- JUNE -2011 ** *WELL SI ON ARRIVAL * ** (ELINE PERF) { INITIAL T /I /O= 2175/700/350 I RIH WITH MH22 /CCL/FH /20' 2 -7/8" HSD 2906 PJO 6 SPF OAL= 31' OAW = 230# 'FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 3.4', CCL STOP DEPTH = 1 11496.6', PERFORATED INTERVAL 11500'- 11520', VISUAL INDICATION OF FIRE AT SURFACE RIH WITH MH22 /CCL /FH /20' 2 -7/8" HSD 2906 PJO 6 SPF OAL= 31' OAW = 230# !FISHING NECK SIZE= 1.38" CCL TO TOP SHOT= 3.4', CCL STOP DEPTH= ;11476.6', PERFORATED INTERVAL 11480'- 11500', 'API DATA: CHARGE = 2 -7/8" HSD PJO, 6 SPF AND 60 DEG PHASING. ;PENETRATION = 24.3" AND ENTRACE HOLE = 0.31" ** *JOB TO BE CONTINUED ON 14- JUN - 2011 * ** 6/14/2011 . ** *JOB CONTINUED FROM 13- JUN - 2011 * ** (E -LINE PERF) 'POOH. VISUAL INDICATION OF FIRE AT SURFACE. RIG DOWN FINAL VALVES CONFIGURATION: SSV = OPEN, SWAN/WING /MASTER = ; CLOSED !FINAL T /I /O = 2000/700/340 PSI * ** JOB COMPLETE * ** WELL LEFT SHUT IN ON DEPARTURE 3 3 FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL W ELLHEAD = FMC • LI -31 SA F1/2" C Nit G "",LE> 70° @ 12398' ACTUATOR = BAKER C KB, ELEV = 53.8' 120" CONDUCTOR H 115' 1 BF. = = 1 4 -1/2" HXO SSV NP, ID = 3.813" 1 Ma ngle = 72° @ 12657' 13 -3/8" HES ES — 2011 1 — a _ Datum MD = 12,059' CEMENTER GAS LIFT MANDRELS Datum TVD = 8900' SS ST MD TV D DEV TYPE VLV LATCH PORT DATE 113 -3/8" CSG, 68 #, L -80 BTC, ID= 12.415" H 5142' Ell 1 4766 4305 48 KBG-2 DOME BK 18 01/28/08 2 7590 6196 48 KBG-2 SO BK 20 01/28/08 17" BKR TIEBACK SLV, ID = ? H 11030' 1---- 3 9075 7186 48 KBG-2 DMY BK 0 01/02/08 4 10019 7834 46 KBG -2 DMY BK 0 01/02/08 17" X 4 -1/2" BKR ZXP PKR, ID = 3.87" I — j 11037' 5 11006 8453 59 KBG -2 DMY BK 0 01/02/08 17" X 4-1/2" BKR HMC LNR HGR, ID = ? H 11043' 9 -5/8" CSG, 47 #, L -80 BTC-M, ID = 8.681" H 11224' 1r 1 11251' H4-1/2" 1/2" HES X NIP, ID ,= 3.813" 1 Minimum ID = 2.25" @ 13026' g j 11272' H7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" 1 2 -7/8" HES XN NIPPLE I 1 ( 11348' H 4 -1/2" HES X NIP, ID = 3.813" I 11378' 1 1 4 -1/2" HES XN NIP, ID = 3.725" I 4 -1/2" TBG, 12.6 #, 13CR -80 VAM TOP, -I 11432' — • 1 11432' H3 -1/2" WLEG, ID = 3.958" .0152 bpf, ID = 3.958" 1 11457' 1 — I ELMD TT LOGGED 06/11/11 1 il 12088' H 7" MARKER JOINT 1 ` 12926' 1 1 FISH- IBP- BLOWNDOWNHOLE(10 /10/99) 1 • 12960' 1-1 7" X 3 -1/2" BKR D PKR, ID = 3.25" 1 * ►j ITOP OF 2 -7/8" TBG H 12960' ( * il 12964' H 3 -1/2" X XO PIN, ID = 2.441" " 1 1297 I-{ X TIEBCK SLV, ID = 5.25 1 ITOP OF 4 -1/2" LNR 1 12976' 12983' 1 X 5" BKR HMC LNR HGR, ID = 4.438" - ‹-----_.‘ ++ 2984' 112990' Ii OF S 2N X (09/OD5/93)918„ 1 ,+ + 12994' —12-7/8 X NIP, ID = 2.313" 1 2 -7/8" TBG, 6.5 #, L -80, .0058 bpf, ID = 2.441" 13039' + , A I + + 13026' H2-7/8" XN NIP, ID = 2.25" 1 Ink + • 13026' H2 -7/8" PXN PLUG (XX/XX/XX ?) 1 17" LNR, 29 #, L -80 HYD 511, .0371 bpf, ID = 6.184" H 13073' + +� • ` 13034' H 7" HES CEMENTER 1 PERFORATION SUMMARY '+ ' 13039' H2 -7/8" WLEG, ID = 2.441" 1 REF LOG: FMI ON 03/17/98 ' '+ ( 13037' H ELMD TT LOGGED 12/22/98 1 ANGLE AT TOP PERF: 58° @ 11480' + + Note: Refer to Production DB for historical perf data + SIZE! SPF 1 INTERVAL 1 Opn /Sqz J DATE \ . SEE PAGE 2 FOR PERFORATION DATA 1 1 1 1 13997' J - 1 CEMENT PLUG (04/17/99) I 4 -1/2" LNR, 12.6 #, L -80 IBT, .0152 bpf, ID = 3.958" 1 - 1 14300' TD — 1 14690' I ' - DATE REV BY COMMENTS DATE REV BY COMMENTS LISBURNE UNIT 03/30/98 POOL 7 ORIGINAL COMPLETION . 02/19/09 ?/ PJC DRLG DRAFT CORRECTIONS WELL: L1 -31 ' 10/98 RWO 1 03/09/09 JWPJC FINAL DRLG CORRECTIONS PERMIT No: '1980150 01/06/08 N4ES RWO 06/26/11 TTR/ PJC ADPERFS (6/11- 13/11) AR No: 50- 029 - 22860 -00 02/09/08 JRA /PJC MIN ID CORRECTION 06/29/11 MH/ PJC ELMD TT LOGGED (6/11/11) SEC 1, T11 N, R14E, 2199' FNL & 2525' FWL 02/09/08 DAV /PJC GLV C/O (01/28/08) 01/13/09 ? /JMD DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • L1 -31 • PERFS 1 1 1 1 C 1 1 z x PERFORATION SUMMARY 1 1 REF LOG: FM ON 03/17/98 ANGLE AT TOP PERF: 58° @ 11480' 1 1 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 11480 - 11500 0 06/13/11 r 2 -1/2" 1 11480 11510 0 10/04/99 / 11 2 -7/8" 6 11500 - 11520 0 06/13/11 2 -7/8" 6 11520 - 11530 0 06/11/11 " 2 -1/8" 1 11652 - 11683 0 09/12/99 2 -1/2" 6 11678 - 11690 0 07/14/02 461( 2 -1/8" 2 11683 - 12638 0 09/13/99 2 -1/2" 6 11732 - 11755 0 07/14/02 !t` 2 -1/2" 6 11785 - 11795 0 07/14/02 ►!, 2 -1/2" 6 11840 - 11860 0 07/13/02 2 -1/2" 6 12109 - 12125 0 07/13/02 2 -1/2" 6 12250 - 12266 0 07/13/02 t 2 -1/8" 1 12638 - 12703 0 09/13/99 t 2 -1/8" 1 12718 -12831 0 09/11/99 , , 4 -1/2" SLTD 12995 - 13363 SLOT 10/03/98 ` `� 4 -1/2" SLTD 13728 - 14258 SLOT 10/03/98 , , , , , , , ••••• DATE REV BY COMMENTS 1 DATE REV BY COMMENTS LISBURNE UNIT 0 3/30/98 POOL 7 ORIGINAL COMPLETION 02/19/09 ?/ PJC DRLG DRAFT CORRECTIONS WELL: L1 -31 10/98 RWO 03/09/09 JN/PJC FINAL DRLG CORRECTIONS PERMIT No: '1980150 01/06/08 N4ES RWO 1 06/26/11 TTR/ PJC ADPERFS (6/11 - 13/11) API No: 50- 029 - 22860 -00 02/09/08 JRA /PJC MIN ID CORRECTION 06/29/11 MH/ PJC ELMD TT LOGGED (6/11/11) SEC 1, T11 N, R14E, 2199' FNL & 2525' FWL 02/09/08 DAV /PJC GLV C/O (01/28/08) 01/13/09 ? /JMD DRLG DRAFT CORRECTIONS i BP Exploration (Alaska) STATE OF ALASKA ~ ~' ALA OIL AND GAS CONSERVATION COM~SION ~'~~® REPORT OF SUNDRY WELL OPERATIONS JAN ~ ~ ~~Q~ 1. Operations Performed: ,?~aBSI(a dt) ~t tip COhS~ Qb'1'i(fl ~~ ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Ent ed Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ®Development ^ Exploratory 198-015 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22860-00-00" 7. KB Elevation (ft): 53 8' ~ 9. Well Name and Number: ~ Lisburne L1-31 8. Property Designation: 10. Field /Pool(s): - ADL 028300 ~ Prudhoe Bay Field / Lisburne Pool 11. Present well condition summary Total depth: measured 14696 /feet true vertical 10100 ~ feet Plugs (measured) 12984' Effective depth: measured 13997 feet Junk (measured) 12926' true vertical 9750 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 73' 20" 115' 115' Surface 5102' 13-3/8" 5142' 4555' 4930 2270 Intermediate 11187' 9-5/8" 11224' 8557' 6870 4760 Production Liner 2043' 7" 11030' - 13073' 8465' - 9342' 8160 7020 Liner 1324' 4-1/2" 12976' - 14300' 9299' - 9897' 8430 7500 Perforation Depth MD (ft): 11480' - 14258' ~,~ F~~ ~. ~ ~~~~ Perforation Depth TVD (ft): 8687 - 9876' 4-1/2", 12.6# 13Cr80 11432' Tubing Size (size, grade, and measured depth): 2-7/8" R 5# L-80 Packers and SSSV (type and measured depth): 7" x 4-1/2" Baker'S-3' packer; 11272'; 7" x 3- 1/2" Baker'D' packer 12960' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Wel! Schematic Diagram ®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: Contact Howard West, 564-5471 N/A Printed Name Terrie Hubble Title Drilling Technologist 0 ~ Prepared By Name/Number: ~ Signature Phone 564-4628 Date `~ ~~ Terrie Hubble, 564-4628 Form 10-404 Revised 04/2006 / Submit Original Only ~~~ Digital Well File Welt: Li-31 ~~Well History Well Date Summary L1-31 12/9/2007 ***CONTINUED FROM WSR 12/08/07*** BRUSHED SSSV AND XN NIPPLE SET SS C-SUB C~ 2002' SLM LOCKED OUT 3 1/2" SERIES 10 TRSSSV RAN FLAPPER CHECKER PULLED SS C-SUB FROM 2002' SLM SET XN PLUG C 11133' SLM (4 EA 3/16" AND 4 EA 5/64" EO PORTS) D SET) ***CONTINUED ON WSR 12/10/07*"' Page 1 of 1 L1-31 12/9/2007 T/I/0=54/700/300 Assist Slickline. Pumped 108 bbls of 180 deg. crude down tubing for while S/L brushed tubing. Final WHP= 425/450/300 ***casing valves open to gauges at time of departure*** L1-31 12/10/2007 T/I/0=360/400/300 Temp=Sl CMIT TxIA PASSED to 3500 psi (pre RWO) Pumped 9 bbls crude down Tbg to reach test pressure. T/IA lost 60/40 psi 1st 15 min, 20/40 psi 2nd 15 min. FWHP's=0/0/320 Annulus valves open to gauges, IA master & wing tagged w/MIT info. Well left s/i & DSO notified upon departure Li-31 12/10/2007 T/I/0=0/0/300, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Stung into test void to check pressure (100 psi), bled to 0 psi (gas/fluid). Functioned LDS, all moved freely. Pumped through void until clean fluid was achieved. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). PPPOT-IC: Stung into test void to check pressure (50 psi), bled to 0 psi (gas). Functioned LDS, all moved freely. Pumped through void until clean fluid was achieved. Pressured void to 3500 psi for 30 min test, lost 80 psi in 15 min, lost 20 psi in second 15 min (PASS). Li-31 12/10/2007 ***CONTINUED FROM WSR 12/09/07*** (sbhps) ATTEMPT TO CMIT TXIA, TRIPLEX BROKE DOWN ***WELL NORMALED UP, DSO NOTIFIED*** ***NOTE: SERIES 10 TRSSSV LOCKED OUT*** L1-31 12/12/2007 INITIAL T/I/O = 300/300/300 JET CUT TUBING AT 1109' W/ 2.50" SLB POWER CUTTER. DEPTH CORRECTED TO TUBING LY. NFIRMED JET~C jTTER FIRED AT SURFACE,NO CHANGE IN W/H PRESSURES. WELL LEFT SHUT-IN AND DSO NOTIFIED WELL SECURE. FINAL T/I/O = 350/300/300 ***JOB COMPLETE*** L1-31 12/13/2007 T/I/0= 350/400/400 Temp=Sl Circ-Out (Pre- RWO) Rig up and stand by for heater *** Job continued on 12-13-07 WSR*** L1-31 12/14/2007 *** Job continued from 12-13-07 WSR*** Circ-Out, 2000 i -- Establishe (HwU) t'umpea b DDis mecn spear, 1 Z:i23 DAIS 1 % down Tbg thru jet cut at 11090' up IA taking returns to flowline. Freeze protected TxIA with 160 bbls 120*F diesel, U-tubed for 1 hr. CMIT TxIA PASSED to 3500 psi, Pressured up TxIA to 3500 psi w/ 10 bbbls diesel. 2nd test results- 1st 15 min Tbg/IA lost 40/20, 2nd 15 min Tbg/IA lost 0/30 psi w/ a total of 40/50 psi loss in 30 min test. Freeze Protect flowline w/ 20 bbls neat. MiT OA FAiLEDto 2000 psi. Pressured up OA w/ 37.1 bbls diesel to reach 2000 psi. 2nd test results- 1st 15 min OA lost 1560 psi. Established LLROA= .3 bpm @ 2000 psi for 10 bbls Bled pressures down to 0 psi. Final WHPs 0/0/0 (IA/OA casing valves open to gauges, swab shut, needle valve open to gauge at time of departure) L1-31 12/17/2007 T=0 I/A=0 O/A=130 Set 4 1/16" C.I.W. B.P.V. H-Plug. Set Plug Pre- Rig for N4-ES. Did set plug #251 ~ 100"....no problems. Print Date: 1/30/2008 Page 1 of 1 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 1/30/2008 • • BP EXPLORATION Operations Summary Report Legal Well Name: L1-31 Common Well Name: L1-31 Event Name:. WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To i Hours ' Task I Code NPT 12/28/2007 16:30 - 21:00 4.50 MOB P 21:00 - 00:00 3.00 MOB P 112/29/2007 100:00 - 03:00 I 3.001 RIGU I P 03:00 - 04:30 1.50 KILL P 04:30 - 06:00 1.50 KILL P 06:00 - 06:30 0.50 KILL P 06:30 - 08:00 1.50 KILL P 08:00 - 11:30 I 3.501 KILL I P 11:30 - 12:30 1.00 KILL P 12:30 - 14:00 1.50 KILL P 14:00 - 16:00 2.00 WHSUR P 16:00 - 18:00 2.00 WHSUR N SFAL 18:00 - 19:30 1.50 WHSUR N SFAL 19:30 - 21:00 21:00 - 22:30 22:30 - 00:00 12/30/2007 00:00 - 01:00 01:00 - 04:00 04:00 - 08:30 08:30 - 10:00 10:00 - 11:00 11:00 - 13:30 1.501 WHSUR I P Start: 12/28/2007 Rig Release: 1/6/2008 Rig Number: Phase Page 1 of 5 Spud Date: 12/28/2007 End: 1 /6/2008 Description of Operations PRE Moved rig from DS-18 to L1 Pad. PRE Laid Herculite. Spotted rig modules over L1-31. Leveled and assembled rig modules. Spotted rig shop and camp. PRE Continued RU on L1-31. RU lines to pits. Raised and scoped derrick. Accepted rig ~ 02:00 hrs 12/29/2007. DSM spotted, bermed and RU tiger tank. RU hard lines to tree and tank. DECOMP Loaded 120 deg seawater in pits. Tested lines to 3500 psi. DECOMP PU lubricator and tested to 2600 psi. Pulled BPV. DECOMP Service rig, check crown o matic, PVT system, OK. DECOMP Check pressures, SITP = 0 psi, SICP = 0 psi, O/A = 200 psi. Rlg up lines & pressure test same to 3500 psi, OK. DECOMP PJSM. Line up and pump 40 bbls heated seawater down I/A, taking returns up tubing, removing diesel from tubing. Line up on tubing & pump down tubing ~ 5 bpm / 950 psi, taking returns thru choke & micro motion, to tiger tank. Pump 400 bbls, seawater returning. Shut down, bleed down & shut in, monitor, well pressure appears to be building on both sides. Resume pumping down tubing @ 5 bpm / 950 psi, taking clean seawater returns thru gas buster to pits. Pump total of 700 bbls. DECOMP PJSM. Shut down and monitor well. Allow any gas to migrate up hole, (many holes suspected in tubing). DECOMP PJSM. Line up and circulate down the back side, taking returns up the tubing, (50 bbls). Line up and pump down the tubing, taking returns up the I/A, (100) bbls. Conduct test on down hole barrier, 1750 psi tbg x I/A, 10 minutes, good test. Bleed off all pressure, monitor well, well dead. DECOMP PJSM. Set two way check.. Test from bottom @ 1000 psi, OK. ~ Attempt to test from top, bleeding off badly, unable to get above 1500 psi. DECOMP Wait on well support for another two way check valve. DECOMP Held crew change and performed pre-tour checks. Continued waiting for well support for TWC replacement. Held weekly rig leadership meeting, attended by WSLs, toolpushers, RLG, H. Williams. DECOMP Held PJSM. PU and RU lubricator. Tested same to 2700 psi for 5 minutes. Pulled failed TWC. RD lubricator, installed nevy 1.50 WHSUR P DECOMP Tested new TWC from above to 3500 si for 10 mute Tested TWC from below to 1000 si for 10 minutes. 1.50 WHSUR P DECOMP Bled void and blew down control lines. ND tree. 1.00 WHSUR P DECOMP Continued ND tree. 3.00 BOPSU P DECOMP NU BOPE. RU ROPE test equipment. 4.50 BOPSU P DECOMP Tested BOPE 250 osi low / 3500 psi high. Tested VBR with 3-1/2" test joint. BOPE test witness waived by L. Grimaldi, AOGCC, 21:00 hrs 12/28/2007. 1.50 BOPSU P DECOMP PJSM. Pick up lubricator, pressure test to 500 psi, OK. Pull two way check valve, lay down lubricator. 1.00 PULL P DECOMP PJSM. Pick up, make up landing joint, BOLDS, pull hanger to floor, 90K up wt, pulled very smoothly. UD landing joint. Make up circulating head. 2.50 PULL P DECOMP PJSM. Circulate bottoms up C«? 5 bpm / 500 psi. Pumped 675 bbls total .. seawater. Printed: 1/24/2008 2:48:16 PM • • BP EXPLORATION Operations Summary Report Page 2 of 5 ~, Legal Well Name: L1-31 Common Well Name: L1-31 Spud Date: 12/28/2007 Event Name: WORKOVER Start: 12/28/2007 End: 1/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2008 Rig Name: NABOBS 4ES Rig Number: Date 12/30/2007 From - To ~ Hours Task Code NPT '~ Phase- ~ Description of Operations 13:30 - 17:00 3.50 PULL P 17:00 - 18:00 1.00 PULL P 18:00 - 21:00 3.00 PULL P 21:00 - 00:00 3.00 PULL P 12/31 /2007 100:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:30 06:30 - 08:30 08:30 - 11:00 11:00 - 12:00 12:00 - 14:00 14:00 - 15:30 4.501 PULL I P 0.50 FISH P 1.00 FISH P 0.50 FISH P 2.00 FISH P 2.50 FISH P 1.00 WHSUR P 2.00 WHSUR P 1.50 WHSUR P 15:30 - 18:00 2.50 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 22:15 3.75 FISH P 22:15 - 23:15 1.00 FISH P 23:15 - 00:00 0.75 FISH P 1/1/2008 00:00 - 06:00 6.00 FISH P 06:00 - 06:30 I 0.501 FISH I P 06:30 - 09:30 I 3.001 FISH I P 09:30 - 11:00 I 1.501 FISH I P DECOMP PJSM. POOH w/ 3 1/2" completion string & control line. Recovered all control line bands, nothing lost down hole. Rig down spooler. DECOMP Continued POH and LD 3-1/2" completion. DECOMP Held crew change and performed pre-tour checks. Began seeing gas break out at surface. Circulated bottoms up C~ 6 bpm and 400 psi. DECOMP Continued POH and LD 3-1/2" tubing. Began seeing bad pins (broken threads) at 115 jts LD. Dime sized hole in jt 171, approximately 5535' md. 180 jts LD @ 00:00 hrs. DECOMP Continued POH and LD 3-1/2" tubing. Recovered 345 jts 3-1/2" tubing, 4 GLMs + 6.24' cut piece. Most pins had damaged threads. Cut end was flared (photos on S-Drive). DECOMP Installed wear bushing. DECOMP Cleared and cleaned rig floor. DECOMP Service rig. Check crown o matic, PVT system, OK. Perform derrick inspection. DECOMP PJSM. Remove wear bushing. Pick up /make up packer milling BHA. DECOMP PJSM. RIH w/ packer milling BHA on 3 1/2" DP. 73 jts, DECOMP PJSM. Pick up /make up Halliburton 9 5/8" storm packer, RIH & set ~ 33'. Up wt = 52K, down wt = 52K. Test to 2700 nsi / 15_ minutes /charted OK. POOH w/ Halliburton running tool. DECOMP PJSM. Pick up retrieving tool. BOLDS. Latch into 9 5/8" pack off, pull to 40K & shake pipe, work free, lay down pack off & install new ack off. Test same to 5000 psi / 30 minutes /good test. (NOTE: Wellhead was wrapped in herculite and steam applied to assist in easy removal of pack off). DECOMP PJSM. RIH w/ packer retrieving tool, latch up and release Halliburton packer, L/D same. Set wear bushing. DECOMP PJSM. Continue to RIH w/milling BHA on 3 1/2" DP, 1 x 1. DECOMP Held crew change and performed pre-tour checks. DECOMP Continued to RIH w/milling BHA on 3 1/2" DP, 1 x 1. DECOMP Held weekly rig safety meeting with all personnel. Discussed safety alerts, individual concerns, and completing month of December with no incidents. DECOMP Continued to RIH w/ milling BHA on 3 1/2" DP, 1 x 1. DECOMP Ta ed fish at 11 077' DPM. LD one jt, PU kelly. Established parameters: PU 148k Ib, SO 121 k Ib, Rot 135k Ib, 60 - 70 rpm, 150a - 160a, 3000 - 3200 Ib-ft, 3-1/2 bpm, 800 psi, 3k WOB. Pumped High Vis sweep after milling 4', then pumped sweep approx every hour. Varied WOB to 8k Ib, rpm to 70, up to 5-1/2 bpm C~? 1500 psi, torque up to 4000 Ib-ft. DECOMP Service rig. Check crown o matic, PVT system, OK. Conduct derrick inspection. DECOMP PJSM. Continue milling on packer. Establish parameters. Up wt148K, down wt 121 K, 135K rotating wt. Off bottom torque = 4000 ft/Ibs C~ 60 -80 RPM. Pumping 5 1/2 bpm ~ 1250 psi. Milling w/ 8 - 12K WOB. Mill from 11,082' - 11,085'. Incurred DECOMP PJSM. Pick up and circulate @ 2 bpm / 100 psi._Attempt to fill hole by pumping down the back side, no goo ± Watch for any gas migrating up while pumping down the drill pipe. Printed: 1/24/2008 2:48:16 PM • • BP EXPLORATION Operations Summary Report Legal Well Name: L1-31 Common Well Name: L1-31 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date From - To Hours ' Task ~' Code I'~ NPT 1 /1 /2008 11:00 - 13:00 ~ 2.00 FISH P 13:00 - 15:30 ~ 2.50 ~ FISH ~ P 15:30 - 19:00 I 3.501 FISH I P 19:00 - 19:30 0.50 FISH P 19:30 - 00:00 4.50 FISH P 1/2/2008 100:00 - 01:00 I 1.001 FISH I P 01:00 - 02:00 1.00 FISH P 02:00 - 03:30 1.50 FISH P 03:30 - 04:30 ~ 1.00 ~ FISH ~ P 04:30 - 06:00 1.50 FISH P 06:00 - 06:30 0.50 FISH P 06:30 - 07:30 1.00 FISH P 07:30 - 08:30 1.00 FISH P 08:30 - 09:30 1.00 FISH P 09:30 - 10:30 1.00 FISH P 10:30 - 15:30 5.00 FISH P 15:30 - 17:00 1.50 FISH P 17:00 - 22:00 I 5.001 FISH I P 22:00 - 23:00 1.00 FISH P 23:00 - 00:00 1.00 CLEAN P 1/3/2008 100:00 - 01:30 I 1.501 CLEAN I P 01:30 - 02:30 1.00 CLEAN P 02:30 - 06:30 4.00 CLEAN P Start: 12/28/2007 Rig Release: 1/6/2008 Rig Number: Page 3 of 5 Spud Date: 12/28/2007 End: 1 /6/2008 Phase j Description of Operations DECOMP PJSM. No gas, continue milling on packer. Mill to 11,087' & observe acker break free after several stalls. Milling with little or no returns. DECOMP PJSM. Stand back kelly, &RIH w/ 3 1/2" DP 1 x 1, chasing milled acker to 12 828' to u .401 jts total in the hol~ a w/ 4~ of # 401 sticking up. DECOMP PJSM. Circulate bottoms up. Getting returns now ... , circulating C~ 5 1/2 bpm / 1675 psi. FCP 6 BPM ~ 1500 psi. Had some gas to surface. Pumped total of 1050 bbls. S/D & monitor well. fluid level dropping. 70 bph loss rate while circulatin ~ 5 1/2 b m. DECOMP Check PVT alarms. Inspected derrick. DECOMP Set back kelly. Blow down lines. POOH & stand back 3 1/2" DP. DECOMP Finish POOH & standing back 3 1/2" DP._Continuous hole fill loss rate a roximatel 70 b DECOMP Stand back DCs, Break out & L/D milling assy. Mill showed 50% wear. DECOMP Clear & clean rig floor. Empty boot baskets. Baskets contained milling, rusty scale & 2 pcs of metal. DECOMP M/U BHA #2 to fish packer as follows: Spear, Stop Sub, Bumper Sub, Jars, Pump Out Sub, 9 ' Dcs. TL = 301.49'. DECOMP RIH w/ BHA #2 on stands of 3 1/2" DP. DECOMP Service rig, check crown o matic, PVT system, OK. Derrick inspection, OK. DECOMP PJSM. Continue to RIH w/fishing assembly on 3 1/2" DP. DECOMP PJSM. Slip and cut 84' of drilling line. DECOMP Continue to RIH w/fishing assembly on 3 1/2" DP. DECOMP PJSM. 401 jts in the hole. Kelly up. Establish parameters, 163K up wt, 125K down wt. Bring on pump ~ 3 bpm / 400 psi. Slack off & observe spear going into top of fish & corresponding pressure increase to 525 psi. Set down 25K on fish & pick up, repeat. No noticeable drag, but 525 psi (~ 3 bpm remains indicatin fish on• DECOMP PJSM. POOH w/ 3 1/2" DP & fishing BHA. Constant hole fill. DECOMP PJSM. Stand back drill collars, break down BHA. Attempt to tubing punch tail pipe below packer. Tubing punch failed, fractured cylinder. DECOMP PJSM. Used Hot-Tap to releave trapped pressure from tail pipe assy. From below the packer to the plug in XN nipple, was full of formation sand and mill cutting. DECOMP Clear & clean rig floor. DECOMP M/U BHA # 3 6" Bit, 3-Boot Baskets, Bit Sub, Bumper Sub, Jars, Pump Out Sub, 9' 4 3/4" DCs, 11 Stds (1030.18') 3 1/2" DP, X-O, 7" Csg Scraper, Bit Sub. TL = 1350.23'. RIH w/ same. DECOMP Con't to RIH w/ BHA # 3 on stands of 3 1/2" DP. RIH w/ 35 stands.(-3675') DECOMP Cut and slip 84 ft. of drilling line DECOMP Con't RIH with BHA #3 on 3 1/2" DP. RIH w/ 113 stands + 2 singles. P/U kelly to go thru TOL @ 11029'. Circulate & rotate thru liner top & work down to 11046' (20' in on kelly.) Pump 6 BPM C~ 1340 psi. Printed: 1/24/2008 2:48:16 PM C7 BP EXPLORATION Operations Summary Report Legal Well Name: L1-31 Common Well Name: L1-31 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 4ES Date From - To '. Hours Task Code i NPT Page 4 of 5 Spud Date: 12/28/2007 Start: 12/28/2007 End: 1 /6/2008 Rig Release: 1/6/2008 Rig Number: Phase it Description of Operations 1/3/2008 06:30 - 07:00 0.50 CLEAN P DECOMP Con't to RIH w/ stands of 3 1/2" DP to 12825'. (133 Stds + 2 singles + 17' of kelly) 07:00 - 08:00 1.00 CLEAN P DECOMP Work drill string & scrape casing. Bit C~ 12825' & Casing scraper @ top of perfs ~ 11480', 08:00 - 17:00 9.00 CLEAN P DECOMP POOH & UD 6 jts of 3 1/2" DP. Work string up & down 60' 4 times & scrape casing @ 11260'. Con't to POOH & UD 3 1/2" DP 1x1. 17:00 - 18:00 1.00 CLEAN P DECOMP PJSM. UD BHA. 9 Drill collars, pump out sub, jars, bit sub, 3 boot baskets, 6" Bit. 18:00 - 19:00 1.00 CLEAN P DECOMP Servive boot baskets & recover 2 gal. sand and pipe dope. UD 4 1/2" handling tools & equipment. 19:00 - 19:30 0.50 BOPSU P DECOMP Pull wear bushing from tbg. spool. 19:30 - 20:00 0.50 BOPSU P DECOMP Install test plug with 4 1/2" test joint. 20:00 - 21:30 1.50 BOPSU P DECOMP Pressure test 2 7/8 " x 5 " VBR and Annular. LP 250 psi, HP 3500 psi .Charted same. Notified AOGCC to witness test. Lou Grimaldi declined to witness. 21:30 - 22:00 0.50 BOPSU P DECOMP Pull and UD test joint & test plug. 22:00 - 23:00 1.00 BUNCO RUNCMP PJSM. Clean and clear rig floor 23:00 - 00:00 1.00 BUNCO RUNCMP PJSM. P/U and R/U Torque Turn equip & handling tools to run 4 1/2" Cr completion. 1/4/2008 00:00 - 01:00 1.00 BUNCO RUNCMP Con't to R/U rig floor to run 4 1/2" completion (torge turn equipment) 01:00 - 06:00 5.00 BUNCO RUNCMP Run 4 1/2" 12.6#, 13Cr-80, Vam To tbg completion, Baker-Loc all connections below packer. Use stabbing guide, hand-start each pin, used Jet Lube Seal Guard thread compound. Torque turn all connections to 4440 ft-Ibs. Ran 70 jts(-3050') C~3 0600 hrs. 06:00 - 12:00 6.00 BUNCO RUNCMP Con't to run 4 1/2" 12.6#, 13cr-80 tbg., to joint # 180 (-7805 ) 12:00 - 12:30 0.50 BUNCO RUNCMP Service rig and make Pre-tour inspections 12:30 - 15:00 2.50 BUNCO RUNCMP Con't to run 4 1/2" 12.6#, 13 cr-80 tbg. to joint # 219 (- 9440 ) 15:00 - 18:00 3.00 BUNCO RUNCMP R/U control line spoolers and hang sheave. Connect control lines to "HXO" SVL and test to 5000psi f/ 10 min. 18:00 - 23:30 5.50 BUNCO RUNCMP Con't to run 4 1/2" 12.6#, 13cr-80 tbg. with w/ SS control lines w/ 1- SS band/ joint, Ran total of 52 SS bands. Ran total of 267 jts of 4 1/2" tubing. WLEG @ 11432'. S-3 Packer ~ 11272' GLMs @ 11006', 10019', 9075', 7590' & 4767'. HXO ~ 1990'. See completion detail. 23:30 - 00:00 0.50 BUNCO RUNCMP P/U and M/U tbg. hanger and landing joint. NOTE: Hanger top thread = 4 1/2" TC-II 1/5/2008 00:00 - 01:30 1.50 BUNCO RUNCMP M/U SS control lines to tbg. hanger and tested 5000psi F/ 10 min. String PUW = 115 k, SOW = 92 k, LAND, RILDS, B/O and UD landing joint. 01:30 - 02:00 0.50 BUNCO RUNCMP Clear floor of Torq-turn equipment, and UD control line spoolers. 02:00 - 07:00 5.00 BUNCO RUNCMP R/U to Rev/circ. and spot trucks Rev/circ. 175 bbl hot (140 degrees) seawater down the annulus followed by 600 bbl hot inhibited seawater at 3 BPM C~3 90 psi. 07:00 -..09:00 2.00 BUNCO RUNCMP Drop rod/ball & allow to fall on seat. Pressure up on tubina to tubing. Bleed tubing to 1500 psi & SI. Pressure up on annulus & test casing & packer seal, hold for 30 min. Bleed tubing to 1200 psi & DCR sheared. Bleed tubing/annulus to 0 psi. Pump down thru DCR both ways to insure good clean shear. Open Printed: 1/24/2008 2:48:16 PM • BP EXPLORATION Page 5 of 5 Operations Summary Report Legal Well Name: L1-31 Common Well Name: L1-31 Spud Date: 12/28/2007 Event Name: WORKOVER Start: 12/28/2007 End: 1/6/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 1/6/2008 Rig Name: NABOBS 4ES Rig Number: ' Hours I Task Code NPT i Phase Description of Operations Date From - To 1/5/2008 07:00 - 09:00 2.00 BUNCO RUNCMP well & bleed off all lines. 09:00 - 10:00 1.00 BUNCO RUNCMP Drain stack, P/U tee bar & set TWC. Test from aboce & below to 1000 psi for 10 min. Tests good. 10:00 - 11:00 1.00 BOPSU P RUNCMP Drain BOP. Blow down & R/D lines. 11:00 - 12:30 1.50 BOPSU P RUNCMP N/D BOPE & set stack back. 12:30 - 17:00 4.50 WHSUR P RUNCMP N/U Adapter flange. Make HXO valve connections in tubing spool. Test SS control lines to 5000 psi for 10 min. 17:00 - 19:00 2.00 WHSUR P RUNCMP P/U and N/U 4 1/16" 5M flanged tree, Tested 5000 psi. F/10 min. OK 19:00 - 21:00 2.00 WHSUR P RUNCMP P/U Lubricator and test to 500 psi, Pull TWC and L/D Lubbrecator. 21:00 - 00:00 3.00 WHSUR P RUNCMP PJSM with Hot Oil crew. FUU Hot Oilers and tested lines to 3500 psi F/10 min. Freeze protect Well w/ 110 bbls Diesel (- 70 deg ). 2 BPM ~ 1000 psi. R/U and allow Well to U-Tube 1 hrs. 1/6/2008 00:00 - 01:00 1.00 WHSUR P RUNCMP Set BPV and tested 1000 psi from below, Charted F/10 min. 01:00 - 02:00 1.00 WHSUR P RUNCMP Blow down and R/D lines from Hot Oilers, Secure Tree, valve, & cellar. Rig released for move to L2-06 C~ 0200 hrs 01 /06/2008 Printed: 1/24/2008 2:48:16 PM TREE = 4-1 /8" CNV WELLHEAD T FMC ACTUATOR = BAKER C KB. ELEV = 53.8' __..._ BF. ELEV = KOP = 2347' Max Angle = 72 @ 12657 Datum MD = 12,059' Datum TV D = 8900' SS L1-31 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 4766 4305 48 KBG-2 DCK BEK 0 01/02/08 2 7590 6196 48 KBG-2 DMY SBK 0 01/02/08 3 9075 7186 48 KBG-2 DMY SBK 0 01/02/08 4 10019 7834 46 KBG-2 DMY SBK 0 01/02/08 5 11006 8453 59 KBG-2 DMY SBK 0 01/02/08 -°~°° I I 1g8g' -~4-1/2" HES HXO SSSVLN, ID = 3.813" GAS LIFT MANDRELS 13-3/8" CSG, 68#, L-80, ID = 12.415" 5142' TOP OF 7" LNR 11029' Minimum ID = 2.75" @ 11152' 3-1 /2" HES XN NIPPLE 9-5/8" CSG, 47#, L-80, ID = 8.681" 11224' 4-1/2" TBG, 12.6#, 13Cr-80, ID = 3.958" ~--~ 11431' PERFORATION SUMMARY REF LOG: FMI ON 03/17/98 ANGLE AT TOP PERF: 58 @ 11480' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERF BREAKDOWN TOP OF 2-7/8" TBG 12960' TOP OF 4-1 /2" LNR-I 12976' TOP OF 4-1/2" SLTD LNR 2-7/8" TBG, 6.5#, L-80, .00579 bpf, ID = 2.441" ~ 13037_- 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 13073' 4-1/2" SLTD LNR, 12.6#, .6392 bpf, ID = 3.958" 13363' 4-1/2" LNR, 12.6#, .6392 bpf, ID = 3.958" 13728' 4-1/2" SLTD LNR,11.5#, .6392 bpf, ID = 3.958" 14258' 4-1/2" LNR, 12.6#, L-80, .6392 bpf, ID = 3.958" 14300' TD 14690' 11037' BAKER ZXP PKR, ID = 3.87 11251' 4-1/2" HES X NIP, ID = 3.813" 11272' 7" X 4-1 /2" BAKERS-3 PKR, ID = 3.937" 11348' 4-1 /2" HES X NlP, !D = 3.813" 11378' 4-1/2" HES XN NIP, ID = 3.725" 11432' 4-1/2" TBG TAIL WLEG, ID = 4.00" NOTES: HORIZONTAL WELL, 70° @ 12398' 2-1/2" IBP- BLOWN DOWNHOLEDURING ACID STIM ON 10/10/99. 7" X 3-1/2" BAKER D PKR, ID = 3.25" 12~ gs4' I SAND TOP 12994' 2-7/8 X NIP, ID = 2.313" ~~ ,` 13026' 2-7/8" XN NIP W/ PXN PLUG, ID = 2.25" ' ~ ` W/ SAND CAP, RAN 09/05/99 ~ '~ ,~ _ 13037' 2-7/8" TUBING TAIL W/ WLEG, ' (ELMD), fD = 2.441" ~ '~ 13037' ELMD TT LOGGED 12/22!98 ,~ , 13997' CMT PLUG SEi' 04117/99, ~ 60 BBL MARASEAL GEL ' W/ 20 BBL CLASS G LARC CAP TOP AT 13997' SLM , j 14281' CMTED 11 /08/9 W/ 12.3 BBL CLASS G DATE REV BY COMMENTS DATE REV BY COMMENTS 03/30/98 ORIGINAL COMPLETION 10198 RWO 01/06/08 N4ES RWO LISBURNE UNfT WELL: L1-31 PERMIT No: x1980150 API No: 50-029-22860-00 SEC 1, T11N, R14E, 2199' FNL & 2525' FWL BP Exploration (Alaska) L1-31 ~ PERFORATION SUMMARY REF LOG: FMI ON 03/17/98 ANGLE AT TOP PERF: 58 @ 11480' Note: Refer to Production DB for historical perf da SIZE SPF INTERVAL Opn/Sqz DATI 2-112" 1 11480 - 11510 O 10/04/ 2-1/8" 1 11652 - 11683 O 09/12/ 2-1/2" 6 11678- 11690 O 07/14/ 2-1/8" 2 11683 - 12638 O 09/13/ 2-1/8" 1 12638 - 12703 O 09/13/ 2-1/8" 1 12718 - 12831 O 09/11/ 2-1/2" 6 11732 - 11755 O 07/14/ 2-1/2" 6 11785 - 11795 O 07/14/ 2-1/2" 6 11840 - 11860 O 07/13/.. 2-1/2" 6 12109 - 12125 O 07/13/02 2-1/2" 6 12250 - 12266 O 07/13/02 ~30~3 DATE REV BY COMMENTS DATE REV BY COMMENTS 03/30/98 ORIGINAL COMPLETION 10198 RWO 01/06/08 N4ES RWO LISBURNE UNff WELL: L1-31 PERMIT No: 1980150 API No: 50-029-22860-00 SEC 1, T11 N, R14E, 2199' FNL & 2525' FWL BP Exploration (Alaska) PERFS Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well 17-14 MPC-10 17-01 P2-30 L1-31 P2-10 17 -03A C-26 15-07C D-04B P2-24 P2-03 09-44 09-23 2-52/5-41 F-08A 02-16C L2-32 L5-09 02-12B 18-09B G-14A 05-20B Job# N/A 11767137 11824337 11686776 11865639 11846804 N/A 11824342 11594517 11591451 11865643 11855502 11855501 11824337 11846807 11638646 11628790 11695060 11492259 11767132 11366500 11485777 10942220 SGi~NED SEP 1 8 2007 Log Description JEWELRY/5BHP MIU\.. / ~&.¡ -1£.(_ MEM INJ PROFILE I >T": I "'>c<': _1"''11 <'"' SBHPS/JEWELRY LOG 1'11(', -D~.ç- PRODUCTION PROFILE I ~ ~ - (<<Pt."'\' LDL IC¡"k-h/.~ PRODUCTION PROFILE ,cr ~ -I"A '+ JEWELRY/SBHP /C ~- t:J./I_ LDL Iq¿¡( - l..'~ SBHP SURVEY .::If"I?-.- Oq.q SBHP SURVEY ;) ò3 - Ill) PRODUCTION PROFILE JetS<" - (V"'J'1< PRODUCTION PROFILE /£1":) _ ~t..J SBHP/JEWELRY /O¡(..... - QI ~ SBHP/JEWELRY I~ - t'I.::= PRODUCTION PROFILE }.I(.;":. - (')~ ~ USIT :)t\""=J-0 SCMT dt...,~-('¡ '7'6 RST ùï:l'_ .L_.... -1;2,-:}- · I.'" /4L... RST /C r1- 1Ì:1'-1 ~ ,KuJ"':J. MCNL f)o":l- -i'"\<:'~ ... I.~J"r MCNL IC\~. (Y'": .~ #- 1.~L[1Õ¡ MCNL I~~ -(\<Ç''': 'it /5LIO-ð MCNL ::J nLI _ ~:< (./ .. /l1\<'/::J 1 PLEASE ACKNOWLEDGE RECEIPT BY SI~~"""I~~'i~,',"'" '~,',', ~·,T1r+!".'}~,',',' NE COpy EACH TO: BP Exploration (Alaska) Inc. ~!.,- ~" "ft'" ~ \l ¡\.~ ¡J,..J Petrotechnical Data Center LR2-1 !.~,"" '..,., , '.-.~-', . 900 E. Benson Blvd. Anchorage, Alaska 99508 S E PI LII 007 Date Delivered: " 'j"" j', "'w Ci'I" \,OI\\\II\.,310n /\t$j!;¡ŒJ (\jl ,> \.:J; J::~,í 1,,). Date 08/17/07 08/13/07 08/15/07 08/25/07 08/14/07 08/17/07 08/17/07 08/22/07 08/23/07 08/24/07 08/21/07 08/19/07 08/16/07 08/16/07 08/18/07 06/28/07 08/24/07 OS/23/07 11/11/06 06/21/07 10/23/06 11/27/06 06/26/05 NO. 4406 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Endicott BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN ""h ~ Received by: ' ./L..- 09/10/07 . . e e Ll-31 (PTD #1980150) Problem Well Notice All, Well L 1-31 (PTD #1980150) has sustained casing pressure on the IA and has been classified as a Problem well. Wellhead pressures on 3/28/06 were 1630/1630/350. The Anchorage PE is evaluating secure options. Attached is a wellbore schematic. Please call with any questions. «L 1-31.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100,x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~.,~", Þ,;;"f'>'~'¡::;D \J'v"", . " \¡~.. (: ,"," ç) Content-Description: Ll-31.pdf Content-Type: application/octet-stream Content-Encoding: base64 ~f JA:k1f ~, rG""1(f :J..A Ik30f7>" 33tfs. (PJ1 0 ps.' tJJZO/s; 23,7~ 7. () ù~ S ó(ë. fer lb ~q L- JK't + /t/D I, ùft- 1 of 1 4/4/20068:33 AM e lREE= 4-1/8" OW WELLHEA D- FfI/iC L 1-31 SAFElY NOlES: HORIZONTAL WELL, 70' @ 12398' ACTIJATOR= BAKER C KB. ElEV = 53.8' BF. ELEV - KOP= 2347' 2075' 3-112" HES SERIES 10 SSSV, ID= 2.812" Max Angle = 72 @ 12657' . GA.S LIFT MANDRELS l:etum MD = 11833' '---' l:etum lV D = 8800' SS ST MD TVD DEV 1YPE VLV LATCH PORT DATE .JJ 1 2703 2691 18 MMG RK 113-3/8" CSG, 68#, L-80, ID = 12.415" I 5142' -µ ~ 2 5799 5001 47 MMG RK 3 8195 6595 49 MMG RK TOPOF 7"LNR 11029' t- !\ ) 4 10593 8215 51 MMG RK ~ . 11037' BAKER ZX P PKR I I Minimum 10 = 2.75" @ 11152' .~ ~ :8 -I 11095' 7" x 4-1/2" BAKER 503 PKR, ID = 3.937" I 3-1/2" HES XN NIPPLE '-' I : 11152' 3-1/2" HES XN NIP, D = 2.75" 1 13-112" TBG, 9.3#,L-80, .00870 bpf,lD = 2.938" I 11175' 11174' 3-1/2"TBGTAILW/LEG(ELMD), ID=2.905" I I 11160' H ELMD TT LOGGED 06/24/01 1 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 11224' µ ~ ÆRFORA TON SUMMARY ~ REF LOG: FMION 03/17/98 ~ ANGLEATTOPÆRF: 58@11480' 12926' 2-1/Z' IBP - BLOWN OOWNHOLEDURING I Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz [)o\ lE ACID SllM ON 10/10/99. SEE R\GE 2 12960' 7" X 3-112" BAKER D PKR, ID - 3.25" I FOR PERF BREAKDOWN I 12984' SAND TOP I hop OF 2-7/8" TBG 12960' r \" .À 12994' 2-7/8X NlP,ID =2.313"1 TOP OF 4-112" LNR 1297~ r?, \ \ ITOPOF 4-1/2" SLTD LNR 1299~ ~. , .A 13026' 2-7/8" XN NIPW/ PXN PLUG, ID= 2.25" \ W/SANDCAp, RAN 09/05/99 \ \ 13037 2-7/8" TUBING TAIL W/ WlEG, \ 12-7/8"TBG, 6 5#,L-80, .00579 bpf, ID= 2.441" \ (ELMO), ID= 2.441" 13037' I \ , , \ I 13037 H 8..MD TT LOGGED 12122/98 I \ \ I r LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 13073' I \ \ \ , 4-1/2"SLTDLNR, 12.6#, .6392bpf, ID= 3.958" H 13363' 1 , \ \ 1 13997' ¡- CMT RUG SET 04/17/99, 4-1/2"LNR, 12.6#, .6392 bpf, D - 3.958" H 13728' I \\,~ 60 BBL Ml\RASEAL G8.. \ W/ 20 BBL CLASS G LARC , 1'- 11- CAP, TOP A T 13997' SLM \ 14-1/2" SL TO LNR, 11.5#, .6392 bpf,lD = 3.958" 14258' 14-1/2" LNR, 12.6#, L-80, .6392 bpf,ID= 3.958" I 14300' I ~~ ~ 14690' I 14281' CMlED 11108/98 W/12.3 BBL CLASS G [)o\ lE REV BY COMNENTS DATE REV BY COMMENTS lISBURNEUNff 03130/98 o RIG INA L COMRETJON 04/06/02 TMNltlh ÆRF CORRECllONS WELL: L1-31 10/98 RWO 06/30/02 [)o\ V /KK MN ID CORRECTION PERMrrNo: 1980150 12/14/00 SI50MNH CONVERlED TO CANV AS 07/13/02 CWSlKK ADPERFS A A No: 50-029-22860-00 03108101 SIS-LG FINAL SEC 1, T11N, R14E 720.62 ÆL 3835.18 FNl 10/25/01 RN/TP CORRECllONS BP Exploration (Alas ka) e ÆRFORA llON SUMM6.RY REF lOG: FMION03/17/98 ANGLE AT TOP PERF: 58@ 11480' Note: Refer to Production œ for historical erf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 1 11480- 11510 0 10/04/99 2-1/8" 1 11652 - 11683 0 09/12/99 2-1/2" 6 11678-11690 0 07/14/02 2-1/8" 2 11683 - 12638 0 09/13/99 2-1/8" 1 12638 - 12703 0 09/13/99 2-1/8" 1 12718 - 12831 0 09/11/99 2-1/2" 6 11732 - 11755 0 07/14/02 2-1/2" 6 11785- 11795 0 07/14/02 2-1/2" 6 11840- 11860 0 07/13/02 2-1/2" 6 12109- 12125 0 07/13/02 2-1/2" 6 12250 - 12268 0 07/13/02 [)o\ lE 03/30/98 10/98 12/14/00 03108/01 10/25/01 REV BY COMMENTS ORlGIN'\l COMREllON RWO SI50IVWH CONVERlED TO CANVAS SIS-lG FIN'\l RN/TP CORRECllONS DATE 04/06/02 06/30/02 07/13/02 L 1-31 PERFS , \ \ \ REV BY COMMENTS TMN'tlh ÆRF CORRECllONS [)o\ V/KK MN ID CORRECTION CWSlKK ADPERFS e LISBURNE UNrr WEll: l1-31 PERMrr No: 1980150 A A No: 50-029-22860-00 SEC1, T11N, R14E 720.62 Æl3835.18FNl BP Exploration (Alaska) "r",:.:;";:';¡C""'¡::"""'~'-") (,\:01 !! !!\ \ I r I [, rl)) U LtlJ U l1 "". ,-_OJ (rì' ¡r- ,! ' uJJ d~ "", ,', ,-', r;:'\ ilri 1'7, /ft,\I; !!-i[IU¡¡¡íf"\ì, /1\i!1 íi\\\.,-'"I,\ !,~\ lfÙ L6lf~ cQ) U ~ Lfl1 { i FRANK H. MURKOWSKI, GOVERNOR ! i AI.ASKA OIL AND GAS CONSERVATION COMMISSION! í 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 l ~Ø-6 rS- 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 Date ofSVS Test Failure Rate PBU Ll April 23, 2004 30.0% PBU L2 April 26, 2004 16,7% PBU L3 April 27, 2004 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 perfonnance testing as part of the 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 perfonnance 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 't th SVS test. Sincerely, fJ~ J . Nonnan, Chair Commissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via email) 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: 04/23/2004 Unit/Field/Pad: Greater Pi Mclntyre/Lisbume/L1 Separator psi: 1PS 450 HPS 450 Well Permit Separ Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI Code Code Code Passed Retest or SI GAS, CYCLE, SI LI-0l 1850550 7/19/2003 SI 11-02 1851720 450 350 320 P 5 P 4/27/2004 OIL L 1-09 1850010 450 700 690 P P P OIL LI-lO 1850830 4/30/1990 SI LI-14 1851400 3/1 0/1996 SI LI-15A 2031200 450 350 350 P P P OIL LI-21 1780300 450 600 550 P 5 P 4/27/2004 OIL LI-27 1891220 5/10/1994 SI LI-28 1880250 12/17/1992 SI 11-30 1900180 3/28/1995 SI 11-31 1980150 450 350 350 P 5 P 4/27/2004 OIL Wells: 5 Components: 10 Failures: 3 Failure Rate: Remarks: LI-02 4/23/2004: Called grease crew and heater LI-21 4/23/2004: Called grease crew LI-31 4/23/2004: Called grease crew Page 1 of 1 SVS PBU LIS L 1 04-23-04,xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION · REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X RE PERFS Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 54 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2200' FNL, 2755' FEL, Sec. 01, T11 N, R14E, UM (asp's 688633, 5975433) L1-31 At top of productive interval 9. Permit number / approval number 4448' FNL, 4694' FEL, Sec. 35, T12N, R14E, UM (asp's 681340, 5978285) 198-015 At effective depth 10. APl number 4723' FNL, 4078' FEL, Sec. 35, T12N, R14E, UM (asp's 681962, 5978025) 50-029-22860-00 At total depth 11. Field / Pool 3839' FNL, 723' FEL, Sec. 34, T12N, R14E, UM (asp's 680016, 5978862) Lisburne Oil Pool 12. Present well condition summary Total depth: measured 14696 feet Plugs (measured) Tagged TD @ 12331 (12/16/1999) true vertical 10100 feet Sand Top @ 12984' 2-7/8" PXN Plug @ 13026' (09/05/1999) Effective depth: measured 12331 feet Junk (measured) 2-1/2" IBP @ 12926' (10/10/1999) true vertical 9064 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 115' 20" 260 sx Arcticset 145' 145' 2884 sx PF 'E' & 500 sx Surface 5112' 13-3/8" 5142' 4555' Class 'G' Intermediate 11194' 9-5/8" 1000 SX Class 'G' 11224' 8557' Liner 2044' 7" 891 sx Class 'G' 11029' - 13073' 8465' - 9342' Liner 1324' 4-1/2" uncemented 12976' - 14300' 9299' - 9847' Perforation depth: measured Open Perfs 11480'-11510', 11652'-12331' Open Perfs below Tagged TD 12331 '-12703', 12718'-12831 ', Slotted Liner 13728'-14258' true vertical Open Perfs 8687'-8703', 8772'-9064' Open Perfs below Tagged TD 9064'-9187', 9193'-9237', Slotted Liner 9626'-9876' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 TBG @ 11175'. Packers & SSSV (type & measured depth) 9-5/8" x 7" BKR ZXP Packer @ 11037' MD. 7" x 4-1/2" BKR S-3 Packer @ 11095' MD. 7"x 3-1/2" BKR Model D Packer @ 12960'. 3-1/2" HES Series lq-S, s, S~..-@2O~5.',, MDi. .. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressureI,'~ i,i 'i i'~ £'!.¢~':-';:""'" 14. Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Mcr Water-B~!~.~:;!(~J i ~i; ~3a'sing P'resSure,'~,', ,~ Tubid.~' Pressure Prior to well operation 07/11/02 847 8070 3 ~, '.:'.!~;' ~,?- 767 Subsequent to operation 07/15/02 891 8746 0 772 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~.~~~~~,./.~ Title: Technical Assistant Date July 17, 2002 DeWayne R. Soh~rorr -- ~' ---- II1' ~,e'~are~[~aWayne R. Sch norr 564-517._4 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 07/07/2002 07/13/2002 07/14/2002 0~0~02 L1-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS SBHPS: DRIFT/TAG PERFORATING: PERFORATING PERFORATING: PERFORATING EVENT SUMMARY DRIFTED WITH 2.50" DUMMY GUN TO 12,300' SLM. POOH. NO TIGHT SPOTS ENCOUNTERED. <<< TURNED WELL OVER TO OPERATOR TO POP >>> 07/13/02 IN PROGRESS - COMPLETED THREE OF SIX GUN RUNS WITH 2.5" 2506 POWERJETS. PERF INTERVALS: 12250'- 12266'/12109'- 12125'/11840'- 11860'. ALL GUNS WERE SHOT WITH WELL FLOWING. WILL RETURN IN AM TO COMPLETE PERFORATING. LEFT WELL FLOWING. 07/14/O2 CONTINUED FROM PREVIOUS DAY. SHOT THREE 2.5" POWERJET GUNS W/6 SPF FOR A TOTAL INTERVAL OF 45'. THE INTERVALS WERE: 11785' - 11795', 11732' - 11755', 11678' - 11690'. ALL GUNS WERE SHOT WITH WELL FLOWING. SHUT-IN WELL TO POOH. TURNED BACK TO DSO TO POP. Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TESTS) 2 TOTAL 07/13-14/2002 RE PERFS THE FOLLOWING INTERVALS WERE PERFORATED USING 2.5" POWERJET 2506, LOADED 6 SPF, 60 DEGREES PHASING, RANDOM ORIENTATION. 11678'-11690' 11732'-11755' 11785'-11795' 11840'-11860' 12109'-12125' 12250'-12266' Page I DATE REV BY COMIVENTS DATE REV BY COMrvF_N'I-S 03/30198 OR~GINA L COMPLETION 04/06/02 TMN/tlh PERF CORRECTIONS 10/98 i RWO 06/30/02 DAV/KK MN ID CORRECTION 12214/00 SIS-MWH CONVERTED TO CANVAS 07/13/02 CWS/KK ADPERFS 03/08/01 SIS-LG FINAL 10125/01 RN/-I-P ;CORRECTIONS TRE = 4-1/8" CIW ~. ~ = 53.8' .... ............................................................................ ~tumWD= 8~0'SS 3 8~ ~5~ 40 ~G .......... ~R~TDN SUGARY A~LEATT~: ~114~' . ' - ' - N D : uctio B f~ historical peal data ~~ ~ S~E SPF ImmVAL O~/~z m~ ~ ' ~ / ' SEE PAGE 2 ~ '~ a2~o' H ~RP~F ~~ ' ' ' B~KDOWN 12-7/8"TBG, 6.5~,L-80,.00579bpf, ID=2.441" ~ 13037' I ? "~ /(~MD)'ID=2'441" W/20 BBk ~A~ G kARC P, TOPAT 1399~ SLM 14-1/2"SL~LN~11.5~,.O392~f, ID=3.958" H 142~' ~ ~ 4-1/2" LN~ 12.6~, L-80,.6392 bpf, ID= 3.958" H 143~' ~ ~ R~ BY I COM~N~ DATE I ~ BY ~ C~S LISBU~EUNE 0~30198 O~GI~LCOM~ON ~/06/02 TM~tlh ~RFCOR~C~O~ WELL: L1-31 L1-31 PERFS PERFORAlqON SUMMA RY REF LOG: FMI ON 03/17/98 ANGLE AT TOP PERF: 58 @ 11480' Note: Refer to Production B8 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 1 11480- 11510 O 10/04/99 2-1/8" I 11652- 11683 O 09/12/99 2-1/2" 6 11678- 11690 O 07/14/02 2-1/8" 2 11683 - 12638 O 09/13/99 2-1/8" I 12638- 12703 O 09/13/99 2-1/8" 1 12718 - 12831 O 09/11/99 2-1/2" 6 11732- 11755 O 07/14/02 2-1/2" 6 11785- 11795 O 07/14/02 2-1/2" 6 11840- 11860 O 07/13/02 2-1/2" 6 12109- 12125 O 07/13/02 2-1/2" 6 12250- 12266 O 07/13/02 I I WO 12/14~0018~s' MWHI OONVERTED TO OANV AS 10/2~011 RNrrP ICOR~ONS LISBURNE UNrF WELL: L1-31 PERIVlT No: 1980150 APl No: 50-029-22860-00 SEC 1, TI.I.N, L~14~ ~¢~ FEL 3835.18 FAL ,N~_.,,D ,j~it~l~l~ra~i~'rAlaska) _ MICROFILMED 7~30~02 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Saved as M:/weepie/microfilm_marker.doc Well Compliance Report File on Left side of folder ~98--015-0/. PR~E BAY ~ LIS~ Li23i 502 0292228'60200 ~CO MD 14696 T~D 10100: 'Completion Date: 3/30/98 Completed Status: 1-OIL Current: T Name D 8861 D 9302 L CDR/RAB-MD L CMR DEFT L DSSI L FMI-RAW L NGT L PEX-3DD/CN L PEX-AIT L PEX-CN L PEX-HALS L PEX-MCFL L PEX-NDT/GR L PEX-SSTVD PEX-SSTVD PROD/JWL/GLM RFT L STATTEM SRVY L TEM SRVY L TEM SRVY-SPIN/ L TEM SRVY/IPROF k USIT T 8352 Interval Sent Received T/C/l) SCHLUM PEX-CMP/HAL OH 1/21/99 1/27/99 PDS TEM OH 9/9/99 9/9/99 (_~AL 250-14696 OH 9/30/97 4/21/98 13072-13352 OH 1/21/99 1/27/99 D ~AL 10450-14280 [.~)./'Z"L/~ CH 5 1/19/99 1/21/99 O°tO ~A~ 10724-14680 OH 9/30/97 4/21/98 ~"~AL 11230-14680 OH 9/30/97 4/21/98 c~AL 11224-14680 OH 9/30/97 4/21/98 ~ 13072-13390 OH 1/21/99 1/27/99 ,~L 11224-14680 OH 9/30/97 4/21/98 ~F.~ 13072-13372 OH 1/21/99 1/27/99 ~'FI~/~L 13072-13402 OH 1/21/99 1/27/99 D k.FANA L 13072-13402 OH 1/21/99 1/27/99 ~NAL 11224-14680 OH 9/30/97 4/21/98 bd~'INAL 11224-14680 OH ~f~AL 13072-13402 OH ~.AL 10450-14280 ,"9~"L./C~ CH 5 ]SAL 11383-14497 OH t/FINAL 100-12965 9/30/99 CH 5 ~ 11094-13014 q/~O/~9 CH 5 /,¢I'NAL PRES 13000-14281 1/i ~/qq CH S ~AL 13000-13994 4/23/99 ~ CH S · 11046-12990 O. 5 k.J/ SCHLUM CN/AIT/SDN/FMI OH 9/30/97 4/21/98 1/21/99 1/27/99 1/19/99 1/21/99 090 9/30/97 4/21/98 10/13/99 10/27/99 9/9/99 9/9/99 O q O D 2/1/99 2/4/99 6/7/99 6/16/99 090 9/30/97 4/21/98 9/30/98 4/21/98 Tuesday, April 04, 2000 Page 1 of 2 Was the well cored? yes//n~ ~ Comments: Are Dry. Ditch Samples Required? ye n~.~And Received~_ Analysis Description Re~~6 Tu6sday, April 04, 2000 Page 2 0£2 1 O/13/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12857 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape , L1-31 STATIC TEMPERATURE LOG 990930 1 I , , D SIGNE DATE: f}~;l 2 ? i999 Al~ka 0il & Gas Cons. C0mmL~0n Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6S~2~. ~k y( - ~ STATE OF ALASKA ~-~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _X- - Pull tubing _ Alter casing _ Repair well _ O~e.,r,~,,, n;i ~, ~.~ P.r~r~ P. nmmi 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or I~'~lr~ "" Arlchor~,~l ARCO Alaska, Inc. Development__X RKB 54 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Lisburne Unit 4. Location of well at surface 8. Well number 2196' FNL, 2754' FEL, Sec. 01, T11N, R14E, UM L1-31 At top of productive interval 9. Permit number / approval number 831' FSL, 4694' FEL, Sec. 35, T12N, R14E, UM 98-0015 At effective depth 10. APl number 50-029-22860 At total depth 11. Field / Pool 3835' FNL, 721' FEL, Sec. 34, T12N, R14E, UM Lisburne Oil Pool 12. Present well condition summary Total depth: measured 14696 feet Plugs (measured) Tagged TOC @ 11542' MD (10/10/1999) true vertical 10100 feet Effective depth: measured 11542 feet Junk (measured) true vertical 8719 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 115' 20" 260 Sx Arcticset 115' 115' Surface 5088' 1 3-3/8" 2884 Sx PF E & 500 Sx Class G 51 42' 4555' Production 11170' 9-5/8" lOOO Sx C~ass G 11224' 8557' Liner 2039' 7" 891 sx c~ass G 1 3073' 9342' Liner 1305' 4-1/2" uncemented 14300' 9897' Perforation depth: measured 11480' - 11510'; (under Cmt cap/IBP 11652', 11659', 11683', 11689', 11697', 11707', 11732', 11738', 11752', 11787', 11790', 11843', 11857', 11867', 12062', 12092', 12109', 12122', 12240', 12254', 12263', 12356', 12632', 12638', 12675', 12690', 12703', 12718', 12751', 12793', 12801', 12809', 12817', 12831, slotted liner 13728' - 14258'). true vertical 8687' - 8703'; (under Cmt cap/IBP 8772', 8776', 8787', 8789', 8793', 8798', 8809', 8812', 8818', 8834', 8835', 8858', 8865', 8869', 8955', 8968', 8975', 8981', 9029', 9035', 9038', 9073', 9164', 9166', 9177', 9182', 9187', 9192', 9205', 9221', 9224', 9228', 9231', 9237', slotted liner 9626'-9876'). Tubing (size, grade, and measured depth) 3-1/2"9.3#, L-80 Tbg @ 11175' MD; 2-7/8"6.5#, L-80 Tbg @ 13037' MD. Packers & SSSV (type & measured depth) 7" X 3-1/2" BAKER 'D' PACKER, ID=3.25" @ 12961' MD; 7" X 4-1/2" BAKER S-3 PACKER @ 11096' MD. 3-1/2" HES SERIES 10 SSSV @ 2076' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) 0F It INAL Treatment description including volumes used and final pressure 14. Representative Daily Avera.qe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) - Subsequent to operation 1104 5345 181 - 750 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ._X Oil .__X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ Title ARCO EngineeringSupervisor Date Erin Oba Prepared by Paul Rauf 263-4990 -- Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE L1-31 "~- DESCRIPTION OF WORK COMPLETED ACID STIMULATION & PERFORATING OPERATIONS Date Event Summary 9/05/1999: RIH & set PXN Plug @ 13026' MD to isolate the slotted liner interval f/13728' - 14258' MD. 9/06/1999: RIH & dumped 25 lbs of of River Sand on PXN Plug. Tagged TOS @ 12984' MD. 9/12-13/1999: MIRU ELU. PT'd equip to 3000 psi. RIH & shot Add Perforations @: 11652' MD (Zone Wahoo 4) Reference Log: FMI 3/17/1998. 12122' MD (Zone Wahoo 3) 11659' MD (Zone Wahoo 4) 12240' MD (Zone Wahoo 2) 11683' MD (Zone Wahoo 4) 12254' MD (Zone Wahoo 2) 11689' MD (Zone Wahoo 4) 12263' MD (Zone Wahoo 2) 11697' MD (Zone Wahoo 4) 12356' MD (Zone Wahoo 2) 11707' MD (Zone Wahoo 4) 12632' MD (Zone Wahoo 1) 11732' MD (Zone Wahoo 4) 12638' MD (Zone Wahoo 1) 11738' MD (Zone Wahoo 4) 12675' MD (Zone Wahoo 1) 11752' MD (Zone Wahoo 4) 12690' MD (Zone Wahoo 1) 11787' MD (Zone Wahoo 4) 12703' MD (Zone Wahoo 1) 11790' MD (Zone Wahoo 4) 12718' MD (Zone Wahoo 1) 11843' MD (Zone Wahoo 4) 12751' MD (Zone Wahoo 1) 11857' MD (Zone Wahoo 4) 12793' MD (Zone Wahoo 1) 11867' MD (Zone Wahoo 4) 12801' MD (Zone Wahoo 1) 12062' MD (Zone Wahoo 3) 12809' MD (Zone Wahoo 1) 12092' MD (Zone Wahoo 3) 12817' MD (Zone Wahoo 1) 12109' MD (Zone Wahoo 3) 12831' MD (Zone Wahoo 1) Used 2-1/8" carriers & all shots @ 1 SPF underbalanced. POOH w/guns. ASF. RD. 9/18/1999: MITIAto 3000 psi - passed. Set 3-1/2" Frac Sleeve. 9/30/1999: Performed a Fullbore Acid Stimulation Treatment as follows: MIRU & PT'd equip. Pumped stimulation fluid schedule FB to treat the open perforation intervals listed above: (a) 170 bbls of Diesel & 21 bbls of Crude down backside, followed by (b) 117 bbls of 12% HCL - 10% Xylene @ 4.0 bpm, followed by (c) 217 bbls of 12% HCL - 10% Xylene w/ball-sealers @ 10.6 bpm / 6000 psi, followed by (d) 117 bbls of 2% filtered KCL water displacement, followed by (e) 118 bbls of 2% filtered KCL water overflush, followed by (f) shutdown. Good acid response of >500 psi breakback. Ran E-line temperature survey. RD. 10/01/1999: W/CTU, N2 lifted well. Attempted to flow well. Recovered 186 bbls of fluids. 10/02/1999: RIH & pulled Frac Sleeve. Set 2-1/2" IBP @ 11630' MD. 10/03/1999: RIH & dumped 2000 lbs of River Sand. TOS @ 11545' CTM. Pumped Crude. Page I · L1-31 ........ DESCRIPTION OF WORK COMPLETED ACID STIMULATION & PERFORATING OPERATIONS Date Event Summary 10/04/1999: 10/08/1999: 10/09/1999: 10/10/1999: 10/11/1999: RIH w/CT conveyed per[ guns & shot 30' of add perforations @: 11480' - 11510' MD (Zone Wahoo 5) Reference Log: FMI 3/17/1998. Tagged TOS @ 11541' MD. Used 2-1/2" carriers & all shots @ 1 SPF. POOH w/guns. ASF. RD. RIH & dump bailed 14.5 gallons of Cement onto IBP. RIH & dump bailed 16 gallons of Cement. TOC @ 11534' SLM. RU SLU. RIH & TOC @ 11542' MD. Set Frac Sleeve @ 1978'. RD. Performed a Fullbore Acid Stimulation Treatment as follows: MIRU & PT'd equip. Pumped stimulation fluid schedule FB to treat the Wahoo 5 Zone perforation intervals listed above: (a) 300 bbls of 12% HCL - 10% Xylene w/ball-sealers @ 12 bpm / 5000 psi, followed by (b) 200 bbls of 2% filtered KCL water 12 bpm / 5300 psi, followed by (c) shutdown. RD. W/CTU, N2 lifted well. Recovered 715 bbls of liquids. Returned well to production & obtained a valid welltest. Page 2 STATE OF ALASKA ALASK/' '. AND GAS CONSERVATION COMMI,.c N REPOR'i'~F SUNDRY WELL OPERATi"OrNS 1. Operations performed: Operation shutdown__ Stimulate_~ Plugging_~ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other __ _~. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2195' FNL, 2754' FEL, Sec. 1, T11N, R14E At top of production interval 831' FSL, 4694' FEL, Sec. 35, T12N, R14E At effective depth 1444' FSL, 724' FEL, Sec. 34, T12N, R14E At total depth 3835' FNL, 720' FEL, Sec. 34, T12N, R14E 5. Type of Well: Development Exploratory Stratigraphic Service .~. Datum elevation (DF or KB) KB 53.8 feet 7. unit or Property name LISBURNE UNIT 8. Well number L1-31 9. Permit number/approval98_0015 / n~ .¢} 10. APl number / 500292286000 ' 11. Field/Pool Lisburne Pool 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Conductor Surface Length 73' 5102' 11187' 365' Intermediate Liner Perforation depth: measured n/a true vertical 14696 feet Plugs (measured) 10100 feet 14696 feet 10100 feet Size Cemented 20" 260 SX Arcticset 13 2884 sx PF 'E' & 500 sx Class G 9 5/8" 1000 sx Class G 4 1/2" Slotted Liner Junk (measured) Note: Open Hole Completion 14300' - 14696' Tubing (size, grade, and measured depth) 3 1/2 in. 9.3# L-80 @ 0-11175' MD, 2 7/8 in. 6.5# L-80 @ 12960-13037' MD, Packers and SSSV (type and measured depth) 3 2/5 X 6 1/6 PKR @ 12960' MD, 2 4/5 x 3 1/2 TRSSSV @ 2075' MD None. 5' x 2' CTU w/2 1/4" nozzle @ Measured depth True vertical depth 115' 115' 5142' 4555' 11224' 8557' 13728' 9626' RECEIVED JUL 22 lg99 Alaska 0il & Gas Cons. Comm, issh Artchora~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Please refer to attached. Oil-Bbl Gas-Mcf Prior to well operation 20 200 Subsequent to operation 0 0 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations .,~ Representative Daily Average Production or Iniection Data Water-Bbl 16. Casing Pressure Tubing Pressure 370 1950 1400 200 2100 1100 Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify tha~he foregoing/is ~j~be ~qd correct to the best of my knowledge. Signed ~, ~, ~,~ Title ~ ~ ~C Form 10-404 Rev 06/15/88 q SUBMIT IN DUPLICATE L1-31 DESCRIPTION OF WORK COMPLETED CEMENT PLUG AND CT ACID STIMULATION Date Event Summary 04-17-1999 05-24-1999 MIRU CTU and Cementing Equipment. Pt'd to 4500 psi. Loaded well w/Slick Seawater. RIH w/CT and pumped: a) 5 bbls KCI Water b) 60 bbls Maraseal Gel c) 2 bbls KCl Water (used as a spacer) d) 20 bbls Class G Cement w/15.8 ppg LARC Cement Estimated cement top at 13995' MD. Freeze protected top 2500' w/60/40 Meth Water. RDMO. Performed CT Acid Stimulation Treatment. MIRU CTU & PT'd to 4000 psi. RIH w/CT and tagged TD at 13997' corrected SLM. The fluids were then pumped in the order listed: a) 50 bbls 4% NH4Cl at 1.9 bpm b) 10 bbls 10% HCl at 2 bpm c) 10 bbls 4% NH4Cl at 2 bpm d) 10 bbls 10% HCl at 2 bpm e) 10 bbls 4% NH4Cl at 2 bpm f) 7 bbls 10% HCl g) 7 bbls 4% NH4Cl h) 7 bbls 10% HCl i) 7 bbls 4% NH4Cl j) 235 bbls 2% Slick Seawater k) 27 bbls 4% NH4Cl I) 65 bbls Xylene m) 28 bbls 5% SDA n) 42 bbls 10% HCl o) 40 bbls 4% NH4Cl p) 89 bbls 10% HCl at 1.7 bpm q) 69 bbls 4% NH4Cl at 1.66 bpm r) 43 bbls 10% HCl s) 40 bbls 2% Slick Seawater at 1.7 bpm t) 35 bbls 5% SDA u) 65 bbls 10% HCl at 1.9 bpm v) 44 bbls 2% Slick Seawater w) 40 bbls 50/50 Meth Water Injectivity test results were: 1060 psi at 0.6 bpm 1130 psi at 1.2 bpm 1200 psi at 1.7 bpm 1300 psi at 2.0 bpm RDMO. Well returned to production. " GPMA Well' L1-31 TRSSSV-- PKR -- NIP -- WLEG -- PKR NIP WLEG Acid Treatment Acid Treatment TOC TOC L1.31 WEB Date' 6/16/99 APl: 500292286000 SSSV Type: CAT I Annular Fluid: loaded w/crude on 5/22/99 Reference Log: Last Tag: 14007' SLM Last Tag Date: 6/8/99 Well Type: PROD Orig Compltn: 3/30/98 Last W/O: Ref Log Date: TD: 14696 ftKB Max Hole 72 deg @ 12657 Angle @ TS: deg @ Angle @ TD: 58 deg @ 14696 Rev Reason: Post hydrates tag, run DV Last Update: 6/11/99 Angle: Date Note 10/24/98 Minimum ID is 2.25" at 13026' General NoteS Date Note 3/29/98 Well Status: ACTIVE 3/29/98 Tubing Hanger: @ 35' MD 10/11/98 Last Tag Depth (~ 12300 Other Depth TVD Type Description ID 2075 2075 TRSSSV 3-1/2" HES SERIES 10 SSSV, ID=2.812" 2.810 11095 8497 PKR 7" X 4-1/2" BAKER S-3 PACKER 3.930 11152 8524 NIP HES' XN', NIPPLE, ID=2.813", 2.75 NO GO 2.750 11174 8534 WLEG 3-1/2" TUBING TAIL W/ WLEG, (' ELMD) 3.520 12960 9292 PKR 7"X 3-1/2" BAKER 'D' PACKER, ID=3.25" 3.400 12994 9307 NIP 2-7/8 'X' NIPPLE, ID=2.313" 2.310 13026 9321 NOGO 2-7/8'XN' NIPPLE (2.25" ID) 2.250 NIP WLEG TOC 13037 9326 2-7/8" TUBING TAIL WI WLEG, (' ELMD) 2.500 13997 9750 Cement plug set 4/17/99, 60 bbl Maraseal gel wi 20 bbl class G 0.000 LARC cap, top at 13997' SLM 14281 9887 TOC Cemented 11/8/98 w/12.3 bbl class G 0.000 CaSing:Strings:;AI! i:i ::::: :i::::::::: :~:::: :: : :::::: :~ :: :~ : ::~ : ::: Size Weight Grade Top Btm Feet Description 13.375 68.00 L-80 0 5142 5142 SURFACE CASING 9.625 47.00 L-80 0 11224 11224 PRODUCTION CASING 8.681 29.00 L-80 11029 11034 5 LINER HANGER 7.000 29.00 L-80 11034 13073 2039 LINER 6.184 0.00 12983 12990 7 Liner Hanger 5.500 0.00 12990 12995 5 XO - pup 4.500 0.00 12995 13363 368 Slotted liner 4.500 0.00 13363 13728 365 Solid liner 4.500 0.00 13728 14258 530 Slotted liner 4.500 0.00 14258 14300 42 Guide shoe Tubing Strings, AIl: Size Weight Grade Top Btm Feet Description 3.500 9.30 L-80 0 11175 11175 TUBING 2.875 6.50 L-80 12960 13037 77 TUBING GasLiffMandrels/ValV~ ii i i:i ~ i i::::: : :: i:::: i :, ': !: : :: I Stn MD TVD Man Man VMfr VType rOD Latch Port TRO Date Vlv Mfr Type Run Comment 1 2703 2691 CAMCO MMG CA DV 1.5 RK 0.000 0 6/9/99 GLM 2 5799 5001 CAMCO MMG CA GLV 1.5 RK 0.250 2418 4/26/99 GLM 3 8195 6595CAMCO MMG CA GLV 1.5 RK 0.250 2413 4/26/99 GLM 4 10593 8215 CAMCO MUG CA OV 1.5 RE 0.310 0 5/23/99 GEM S tim U la t iO n S& Treatme n ts : : i ~ : : :t Interval Date Type 13039 - 14281 11/30/98 Acid Treatment 13039 - 14001 5/24/99 Acid Treatment Comment ,.~ I A I I- uI- ALASKA AND GAS CONSERVATION COMMI$-" REPOI:IT~,aF SUNDRY WELL OPEFIATImqS · Operations performed: Operation shutdown__ Stimulate ~ Plugging D~ Perforate __ Pull tubing __ Alter casing __ Repair well __ Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2195' FNL, 2754' FEL, Sec. 1, T11N, R14E At top of production interval 831' FSL, 4694' FEL, Sec. 35, T12N, R14E At effective depth 1444' FSL, 724' FEL, Sec. 34, T12N, R14E At total depth 3835' FNL, 720' FEL, Sec. 34, T12N, R14E 12. Present well condition summary Total Depth: measured: true vertical: Effective Depth: measured: true vertical: Casing Length Size Conductor 73' 20" Surface 5102' 13 Intermediate 11187' 9 5/8" Liner 365' 4 1/2" Perforation depth: measured n/a true vertical 5. Type of Well: Development Exploratory Stratigraphic Service 14696 feet Plugs (measured) 10100 feet 14696 feet 10100 feet Cemented Datum elevation (DF or KB) KB 53.8 feet 7. Unit or Property name LISBURNE UNIT 8. Well number L1-31 9. Permit number/approval 98-0015 / 10. APl number 500292286000 11. Field/Pool Lisburne Pool Junk (measured) 260 SX Arcticset 2884 sx PF 'E' & 500 sx Class G 1000 sx Class G Slotted Liner Note: Open Hole Completion 14300' - 14696' Tubing (size, grade, and measured depth) 3 1/2 in. 9.3# L-80 @ 0-11175' MD, 2 7/8 in. 6.5# L-80 @ 12960-13037' MD, Packers and SSSV (type and measured depth) 3 2/5 X 6 1/6 PKR @ 12960' MD, 2 4/5 x 3 1/2 TRSSSV @ 2075' MD None. 5' x 2' CTU w/2 1/4" nozzle @ 13. stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Measured depth True vertical depth 115' 115' 5142' 4555' 11224' 8557' 13728' 9626' RECEIVED 22 AlaSkit Oi! & Gas Cor~s. Commission Anchorage Copies of Logs and Surveys run - Daily Report of Well Operations ~_~' 17. I hereby cer~i~,Ct'~ct JCCe/f~'e¢oing/////////" ~ is true and correct to the best of my knowledge· Signed /~/~'///~'////////~'_~~_ Title 15. Attachments 16. 'Oil ~x Gas __ Suspended Service Tubing Pressure 0 650 Status of well classification as: Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Prior to well operation 0 0 0 Subsequent to operation 0 0 1500 Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Please refer to the attachements 0 R ! G ! I'~\~ ~A' L L1-31 DESCRIPTION OF WORK COMPLETED SET OPEN HOLE CEMENT PLUG AND CT ACID STIMULATION Date Event Summary 11-07-1998 11-30-1998 MIRU CTU and cementing equipment. Stabilized well at 900 psi circulating 2% KCI at 160 deg. Layed in 12.3 bbls 17 ppg Class G Cement from 14465'. Taking returns of 1:1 w/wellhead pressure at 900 psi. Estimated top of cement at 14230' CTM. Made 3 jet passes w/1 1/2# Biozan to 14275' CTM. Well freeze-protected to 2500' w/crude. Pin holed pipe and blew down reel w/N2. Performed CT Acid Stimulation Treatment. MIRU CTU & PT'd to 4000 psi. Loaded the wellbore w/880 bbls crude. RIH w/CT and tagged TD at 14260'. The following fluids were then pumped in the order listed: a) 3 bbls Methanol water b) 40 bbls SLK 2% KCI water at 1.2 bpm c) 43 bbls 5% HCI d) 250 bbls SLK 2% KCI water e) 50 bbls 4% NH4CI water f) 83 bbls Xylene at 1.2 bpm g) 99 bbls 10% HCI at 1.4 bpm h) 60 bbls 4% NH4CI water i) 25 bbls 5% SDA (Self Diverting Acid) j) 47 bbls 10% HCI at 1.5 bpm k) 29 bbls 4% NH4CI water I) 24 bbls 5% SDA m) 32.5 bbls 10% HCI n) 20.2 bbls 4% NH4CI water at 0.5 bpm o) 16.2 bbls 5% SDA p) 17.1 bbls 10% HCI q) 10.7 bbls 4% NH4CI water r) 8.6 bbls SDA s) 4.8 bbls 10% HCI t) 3 bbls 4% NH4CI water u) 2.4 bbls 5% SDA v) 3.8 bbls 10% HCI w) 2.4 bbls 4% NH4CI water x) 2 bbls 5% SDA y) 1.9 bbls 10% HCI z) 1.2 bbls 4% NH4Cl water aa) 1 bbl 5% SDA bb) 16.5 bbls 10% HCI cc) 23.4 bbls 4% NH4CI water dd) 115 bbls Methanol water at 1 bpm RDMO. Well returned to production. Well' L1-31 TRSSSV-- PKR -- NIP -- WLEG -- PKR NIP WLEG Acid Treatment TOC TOC L1-31 GPMA WEB Date: 5/10/99 APl: 500292286000 SSSV Type: CAT I - SSSV Annular Fluid: Reference Log: Last Tag: 13997' SLM Last Tag Date: 4/20/99 Well Type: PROD Orig Compltn: 3/30/98 Last W/O: Ref Log Date: TD: 14696 ftKB Max Hole 72 deg @ 12657 Angle @ TS: deg @ Angle @ TD: 58 deg @ 14696 Rev Reason: GLV installation Last Update: 4/29/99 Notes :: : :: Date Note 10/24/98 Minimum ID is 2.25" at 13026' ;neral Notes ; :i ::i: :: Date Note 3/29/98 Well Status: ACTIVE 3/29/98 Tubing Hanger: @ 35' MD 0/11/98 Last Tag Depth ~ 12300 JEWELRY: Depth TVD Type Description ID 2075 2075 TRSSSV 3-1/2" HES SERIES 10 SSSV, ID--2.812" 2.810 11095 8497 PKR 7"X 4-1/2" BAKER S-3 PACKER 3.930 11152 8524 NIP HES' XN', NIPPLE, ID=2.813", 2.75 NO GO 2.750 11174 8534 WLEG 3-1/2" TUBING TAIL W/WLEG, (' ELMD) 3.520 12960 9292 PKR 7"X 3-1/2" BAKER 'D' PACKER, ID=3.25" 3.400 12994 9307 NIP 2-7/8 'X' NIPPLE, ID=2.313" 2.310 13026 9321 NOGO 2-7/8'XN' NIPPLE (2.25" ID) 2.250 NIP 13037 9326 WLEG 13997 9750 TOC 14281 9887 2-7/8" TUBING TAIL W/WLEG, (' ELMD) 2.500 Cement plug set 4/17/99, 60 bbl Maraseal gel w/20 bbl class G 0.000 I_ARC cap, top at 13997' SLM TOC Cemented 11/8/98 w/12.3 bbl class G 0.000 Is'All : ~ : : : :: :: : ::: : Size Weight Grade Top Btm Feet Description 9.625 47.00 L-80 0 11224 11224 PRODUCTION CASING 13.375 68.00 L-80 0 5142 5142 SURFACE CASING 8.681 29.00 L-80 11029 11034 5 LINER HANGER 7.000 29.00 L-80 11034 13073 2039 LINER 6.184 0.00 12983 12990 7 Liner Hanger 5.500 0.00 12990 12995 5 ×O - pup 4.500 0.00 12995 13363 368 Slotted liner 4.500 0.00 13363 13728 365 Solid liner 4.500 0.00 13728 14258 530 Slotted liner 4.500 0.00 14258 14300 42 Guide shoe Size Weight Grade Top Btm Feet Description 3.500 9.30 L-80 0 11175 11175 TUBING 2.875 6.50 L-80 12960 13037 77 TUBING Gas Lift Mandrels/Valves:i: VMfr VType VOD Latch Port TRO Date Vlv Run Comment 1.5 RK 0.250 2413 4/26/99 GLM 1.5 RK 0.250 2418 4/26/99 GLM 1.5 RK 0.250 2413 4/26/99 GLM 1.5 RK 0.313 0 4/26/99 GLM Stn MD TVD Man Man Mfr Type 1 2703 2691 CAMCO MMG 2 5799 5001 CAMCO MMG 3 8195 6595 CAMCO MMG 4 10593 8215CAMCO MMG CA GLV CA GLV CA GLV CA OV Interval Date Type Comment 13039 - 14281 11/30/98 Acid Treatment 6/7~99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'i'N: Sherrie NO. 12630 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Well Job # Log Description Date Floppy LIS BL Sepia Disk Tape L1-31 TEMP SURVEY/IPROF 990423 I 1 L5-17 PROD. PROFILE/JEWELRY 990327 1 1 L5-23 PROD. PROFILE 990404 I I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907):~~I~" Thank 2/1/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12290 Compan~ Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape L1-31 PUMP IN TEMP SURVEY 990118 1 I SIG DATE: ~,la,;l~a Oil & ,~chora!t~: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 562-6521. Thank 1/21/99 NO. 12261 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'rN: Sherrie Companl Alaska Oil & Gas Cons Corem Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Colored Floppy Well Job # Log Description Date BL Sepia Print Disk L1-31 98637 PEX-HALS 981003 1 1 L1-31 98637 PEX-MCFL 981003 1 1 L1-31 98637 PEX-CNL 981003 1 1 L1-31 98637 PEX-3 DET DEN CNL 981003 1 1 L1-31 9863? CMR 981003 ] ] L1-31 98637 PEX-SSTVD 981003 1 1 SIG DATE: dkf'~ ~. 7 I99~ ~uaska Oil & Gas ~ns. C0mmi~i0n Plooso sign ond return OhO y of this tronsmi~ol to Shorrio ot tho obovo oddress or fox to (907) 5fi2-fi5~~you. 1 / 19/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12248 Companl Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne Floppy LIS Well Job # Log Description Date BL Sepia Disk Tape L1-31 PRODUCTION PROFILE 981222 I 1 L1-31 DEFT 981222 1 1 ~ ,~- ,~ ~,-~: ~:.-- ~ ~ ~ · ~-~,,, ~,~.,~ SIGN~/~~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) ~l~l~fl{~ Thank DATE: ~.:~,j~ STATE OF ALASKA ALASK~-OIL AND GAS CONSERVATION cO"~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I~lOperation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing I--IAIter Casing [] Repair Well [] Other SIotted Liner 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3080' NSL, 2755' WEL, SEC. 1, T11 N, R14E, UM At top of productive interval 831' NSL, 4694' WEL, SEC 35, T12N, R14E, UM At effective depth 1444' NSL, 724' WEL, SEC. 34, T12N, R14E, UM At total depth 1444' NSL, 724' WEL, SEC. 34, T12N, R14E, UM t5. Type of well: [] Development [] Exploratory [] Stratigraphic []Service 6. Datum Elevation (DF or KB) KBE = 53.8' 7. Unit or Property Name Lisburne 8. Well Number L1-31 9. Permit Number / Approval No. 98-0015 398-232 10. APINumber 50-029-22860 11. Field and Pool Lisburne 12. Present well condition summary Total depth: measured 14696' true vertical 10100 Effective depth: measured 14696' true vertical 10100 Casing Length Structural Conductor 73' Surface 5102' Intermediate Production 11187' Liner 1324' feet feet feet feet Size 20" 13-3/8" 9-5/8" 4-1/2 .... Plugs (measured) Junk (measured)5' Cemented MD TVD 260 sx Arctic Set (Approx.) 115' 115' 2884 sx PF 'E', 500 sx Class 'G' 5142' 4556' 1000 sx Class 'G' 11224' 8557' Slotted Liner 12976' - 14300' Perforation depth: measured N/A true vertical Note: Open Hole Completion 14300' - 14696' Tubing (size, grade, and measured depth) 3-1/2" 9.3# L-80 to 11175'; 2-7/8" 6.5# L-80 12996' - 13039' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Baker 7" Model D at 12960'; Baker 7" Model S-3 Packer at 11095'; SCSSV HES Series10 at 2012' REC V Li) Intervals treated (measured) ORIGINAL Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Prior to well operation: Subsequent to operation: 15. Attachments 116. Status of well classifications as: I--I Copies of Logs and Surveys run [] Daily Report of Well Operations J ............ ~' ...... 17. I hereby certify that the forgoing is true. nd correct to the best of my knowledge Signed 1~ ~ Lowell C/~~~--~-~ / _~,,~ ~u[u6 E-r~9 Supervisor ( /// . Prepared By Name/Number: Form 10-404 Rev.k~d6/15/88 Casing Pressure Tubing Pressure Service Date i,/-' :~"'-'-~' ~In Carol Withey, 564-4114 Submit Duplicate Facility Date/Time 10 Sep 98 11 Sep 98 12 Sep 98 13 Sep 98 14 Sep 98 15 Sep 98 16 Sep 98 17 Sep 98 18 Sep 98 19 Sep 98 20 Sep 98 21 Sep 98 22 Sep 98 23 Sep 98 24 Sep 98 Lis DS 01 Progress Report Well L1-31 Rig POOL 7 Duration 06:00-18:00 12 hr 18:00-06:00 12 hr 06:00-21:00 15 hr 21:00-06:00 9 hr 06:00-08:00 2 hr 08:00-16:00 8 hr 16:00-03:00 11 hr 03:00-06:00 3 hr 06:00-08:30 2-1/2 hr 08:30-12:00 3-1/2 hr 12:00-17:00 5 hr 17:00-06:00 13 hr 06:00-06:00 24 hr 06:00-08:00 2 hr 08:00-16:30 8-1/2 hr 16:30-17:15 3/4 hr 17:15-21:00 3-3/4 hr 21:00-06:00 9 hr 06:00-18:00 12 hr 18:00-19:00 1 hr 19:00-06:00 11 hr 06:00-09:00 3 hr 09:00-16:00 7 hr 16:00-06:00 14 hr 06:00-14:00 8 hr 14:00-16:00 2 hr 16:00-06:00 14 hr 06:00-18:00 12 hr 18:00-23:00 5 hr 23:00-06:00 7 hr 06:00-15:00 9 hr 15:00-17:00 2 hr 17:00-21:00 4 hr 21:00-00:00 3 hr 00:00-06:00 6 hr 06:00-16:30 10-1/2 hr 16:30-22:30 6 hr 22:30-06:00 7-1/2 hr 06:00-15:00 9 hr 15:00-18:00 3 hr 18:00-18:30 1/2 hr 18:30-21:00 2-1/2 hr 21:00-00:00 3 hr 00:00-05:00 5 hr 06:00-10:00 4 hr 10:00-11:00 1 hr 11:00-11:30 1/2hr 11:30-13:30 2 hr 13:30-14:30 1 hr 14:30-16:00 1-1/2 hr 16:00-17:30 1-1/2 hr 17:30-19:00 1-1/2 hr 19:00-06:00 11 hr 06:00-10:00 4 hr Activity Rigged down Drillfloor / Derrick Rigged down Drillfloor / Derrick Rigged down Drillfloor / Derrick (cont...) Rig moved 15.00 % Rig moved 15.00 % (cont...) Repaired Handling equipment Rig moved 15.00 % Rig moved 15.00 % Rig moved 15.00 % (cont...) Rigged up Additional services Rigged down Well control Rig moved 15.00 % Rig moved 25.00 % (cont...) Rig moved %s Repaired Handling equipment Rig moved 25.00 % Repaired Handling equipment Rig moved 27.00 % Rig moved 28.00 % Repaired High pressure lines Rig moved 30.00 % Rig moved 30.00 % Rigged up Handling equipment Rig moved 33.00 % Rig moved 38.00 % Rig moved 39.00 % Rig moved 40.00 % Rig moved 50.00 % Rigged up Handling equipment Rig moved 55.00 % Rig moved 60.00 % Rig moved 65.00 % Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Drillfloor / Derrick Rigged up Top drive Rigged up Top drive Rigged up Drillfloor / Derrick Held safety meeting Rigged up Top drive Rigged up Drillfloor / Derrick Cleared Mud shakers Rigged up Fluid system Circulated at 11088.0 ft Rigged up Well control Circulated at 11088.0 ft Installed Hanger plug Rigged down Xmas tree Rigged up BOP stack Held safety meeting Rigged up BOP stack Rigged up BOP stack Page Date 1 04 November 98 Facility Date/Time 25 Sep 98 26 Sep 98 27 Sep 98 28 Sep 98 29 Sep 98 Lis DS 01 Progress Report Well L 1-31 Rig POOL 7 Page Date Duration Activity 10:00-11:30 11:30-12:30 12:30-14:00 14:00-20:30 20:30-00:00 00:00-04:00 04:00-06:00 06:00-20:00 20:00-20:30 20:30-23:00 23:00-02:30 02:30-04:30 04:30-05:30 05:30-06:00 06:00-18:00 18:00-00:00 00:00-01:00 01:00-01:30 01:30-02:30 02:30-04:00 04:00-04:30 04:30-06:00 06:00-06:30 06:30-11:00 11:00-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-19:30 19:30-22:00 22:00-23:00 23:00-06:00 06:00-07:00 07:00-09:00 09:00-13:00 13:00-14:00 14:00-15:00 15:00-20:00 20:00-21:00 21:00-22:00 22:00-00:00 00:00-00:30 00:30-04:30 04:30-05:30 05:30-06:00 06:00-07:00 07:00-08:30 08:30-12:00 12:00-13:30 13:30-14:30 14:30-15:45 15:45-16:15 16:15-18:00 18:00-18:30 1-1/2 hr lhr 1-1/2 hr 6-1/2 hr 3-1/2 hr 4 hr 2 hr 14 hr 1/2 hr 2-1/2 hr 3-1/2 hr 2 hr 1 hr 1/2 hr 12hr 6hr lhr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 4-1/2 hr 1 hr 1 hr 1 hr lhr 4-1/2 hr 2-1/2 hr 1 hr 7 hr 1 hr 2 hr 4 hr 1 hr 1 hr 5 hr 1 hr 1 hr 2 hr 1/2 hr 4 hr 1 hr 1/2 hr 1 hr 1-1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 1-1/4 hr 1/2 hr 1-3/4 hr 1/2 hr Rigged up Casing hanger running tool Rigged down BOP stack Rigged up BOP stack Tested Well control Retrieved Hanger plug Circulated at 11040.0 ft Pulled Tubing in stands to 10580.0 fi Pulled Tubing in stands to 0.0 ft Rigged down Tubing handling equipment Rigged up Bottom ram Made up BHA no. 1 Singled in drill pipe to 2144.0 ft Rigged up Drillstring handling equipment Singled in drill pipe to 2334.0 ft Singled in drill pipe to 11088.0 fl Drilled installed equipment - Permanent packer Flow check Drilled installed equipment - Permanent packer R.I.H. to 12940.0 ft Circulated at 12940.0 ft Flow check Circulated at 12940.0 ft Circulated at 12940.0 ft Pulled out of hole to 2145.0 ft Pulled out of hole to 415.0 ft Pulled BHA Made up BHA no. 2 R.I.H. to 2150.0 ft R.I.H. to 12892.0 ft Circulated at 12892.0 ft Functioned downhole tools at 12940.0 ft Pulled out of hole to 3200.0 fi Pulled out of hole to 2100.0 fl Pulled out of hole to 90.0 fl Pulled BHA Made up BHA no. 3 R.I.H. to 2180.0 fl R.I.H. to 12975.0 ft Milled Permanent packer at 13027.0 ft Circulated at 13027.0 ft Pulled out of hole to 10224.0 ft Circulated at 10224.0 ft Pulled out of hole to 2180.0 fi Pulled out of hole to 460.0 ft Pulled BHA Pulled BHA (cont...) Made up BHA no. 4 Made up BHA no. 4 Made up BHA no. 4 R.I.H. to 2180.0 fi R.I.H. to 4000.0 ft Repaired Drillstring handling equipment R.I.H. to 8640.0 ft Held safety meeting 2 04 November 98 Facility Date/Time 30 Sep 98 01 Oct 98 02 Oct 98 03 Oct 98 04 Oct 98 Progress Report Lis DS 0l Well L1-31 Page 3 Rig POOL 7 Date 04 November 98 18:30-20:30 20:30-21:00 21:00-02:00 02:00-05:00 05:00-06:00 06:00-12:00 12:00-13:00 13:00-13:30 13:30-17:00 17:00-18:00 18:00-18:30 18:30-20:00 20:00-23:00 23:00-23:30 23:30-00:30 00:30-03:30 03:30-06:00 06:00-14:00 14:00-15:00 15:00-18:00 18:00-20:30 20:30-22:00 22:00-22:30 22:30-00:30 00:30-01:00 01:00-04:30 04:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-14:30 14:30-18:00 18:00-00:00 00:00-00:30 00:30-01:30 01:30-03:00 03:00-04:30 04:30-05:30 05:30-06:00 06:00-09:30 09:30-10:00 10:00-11:00 11:00-12:30 12:30-17:00 17:00-18:30 18:30-19:30 19:30-20:30 20:30-02:00 02:00-04:00 04:00-04:30 04:30-05:00 05:00-05:30 05:30-06:00 06:00-08:30 Duration 2 hr 1/2 hr 5 hr 3 hr 1 hr 6 hr 1 hr 1/2 hr 3-1/2 hr 1 hr 1/2 hr 1-1/2 hr 3 hr 1/2 hr 1 hr 3 hr 2-1/2 hr 8 hr 1 hr 3hr 2-1/2 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1 hr 1 hr 1/2 hr 6 hr 3-1/2 hr 6 hr 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 1 hr 1/2 hr 3-1/2 hr 1/2 hr 1 hr 1-1/2 hr 4-1/2 hr 1-1/2 hr 1 hr lhr 5~ 1/2 hr 2 hr 1/2 hr 1/2 hr 1/2 hr 1/2 hr 2-1/2 hr Activity R.I.H. to 13000.0 ft Circulated at 13026.0 ft Milled Permanent packer at 13026.0 ft Circulated at 13032.0 ft Pulled out of hole to 12132.0 ft Pulled out of hole to 2185.0 ft (cont...) Pulled out of hole to 450.0 ft Pulled BHA Laid down fish Serviced Draw works Held safety meeting Made up BHA no. 5 R.I.H. to 4332.0 ft R.I.H. to 5273.0 ft Serviced Block line R.I.H. to 13043.0 ft Washed to 13325.0 ft Washed to 13325.0 ft (cont...) Circulated at 14083.0 ft Washed to 14696.0 ft Circulated at 14696.0 ft Pulled out of hole to 13040.0 ft R.I.H. to 14696.0 ft Circulated at 14696.0 ft Circulated at 14696.0 ft Pulled out of hole to 4332.0 ft Pulled out of hole to 1500.0 ft Pulled out of hole to 450.0 ft (cont...) Pulled BHA Serviced BOP stack Tested BOP stack Rigged up sub-surface equipment - Formation logs Ran Drillpipe in stands to 12665.0 ft Circulated at 12700.0 ft Installed Subs Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations (cont...~ Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Pulled Drillpipe in stands to 3880.0 ft Pulled Drillpipe in stands to 137.0 ft Rigged down sub-surface equipmen( Made up BHA no. 5 R.I.H. to 11830.0 ft Flow check R.I.H. to 13420.0 ft Reamed to 13450.0 ft R.I.H. to 14640.0 ft Circulated at 14696.0 ft Circulated at 14696.0 ft (cont...) Facility Date/Time 05 Oct 98 06 Oct 98 07 Oct 98 08 Oct 98 Progress Report Lis DS 01 Well L1-31 Page Rig POOL 7 Date 08:30-12:00 12:00-13:00 13:00-14:30 14:30-16:00 16:00-18:00 18:00-19:30 19:30-20:30 20:30-22:30 22:30-01:00 01:00-06:00 06:00-06:15 06:15-06:30 06:30-07:30 07:30-09:00 09:00-09:30 09:30-11:30 11:30-15:30 15:30-16:30 16:30-18:00 18:00-20:00 20:00-20:30 20:30-21:00 21:00-02:00 02:00-03:00 03:00-06:00 06:00-13:30 13:30-16:00 16:00-16:30 16:30-01:00 01:00-01:30 01:30-04:00 04:00-04:45 04:45-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-12:30 12:30-14:00 14:00-16:30 16:30-00:00 00:00-04:45 04:45-06:00 Duration 3-1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 2hr 1-1/2 hr 1 hr 2 hr 2-1/2 hr 5 hr 1/4 hr 1/4 hr 1 hr 1-1/2 hr 1/2 hr 2 hr 4 hr 1 hr 1-1/2 hr 2 hr 1/2 hr 1/2 hr 5 hr 1 hr 3 hr 7-1/2 hr 2-1/2 hr 1/2 hr 8-1/2 hr 1/2 hr 2-1/2 hr 3/4 hr 1-1/4 hr 1/2 hr 1-1/2 hr 1 hr 3-1/2 hr 1-1/2 hr 2-1/2 hr 7-1/2 hr 4-3/4 hr 1-1/4 hr Activity Pulled out of hole to 6000.0 ft Serviced Block line Pulled out of hole to 3800.0 ft Pulled out of hole to 2200.0 ft Laid down 1700.0 ft of 3-1/2in OD drill pipe Pulled BHA Rigged up Casing handling equipment Ran Liner to 1310.0 ft (4-1/2in OD) Ran Tubing to 1300.0 fi (2-7/8in OD) Ran Drillpipe to 5-1/2in (13070.0 fi OD) Ran Drillpipe to 13070.0 ft (5-1/2in OD) (cont...) Circulated at 13073.0 ft Ran Liner to 14300.0 ft (4-1/2in OD) Set Liner hanger at 12980.0 ft with 3000.0 psi Pulled Drillpipe in stands to 12975.0 ft Circulated at 12975.0 ft Pulled Drillpipe in stands to 3300.0 ft Pulled Drillpipe in stands to 1300.0 ft Rigged down sub-surface equipment - Setting tools Laid down 1300.0 ft of Tubing Rigged up sub-surface equipment - Permanent packer Removed Tubing handling equipment Ran Drillpipe in stands to 13038.0 ft Set packer at 12960.0 ft with 2000.0 psi Laid down Drillpipe of 2000.0 ft Laid down 10900.0 ft of Drillpipe (cont...) Laid down 2018.0 ft of Drillpipe Removed Bore protector Rigged up Tubing handling equipment Installed SCSSSV Ran Tubing in stands to 11134.0 ft Installed Tubing hanger Set packer at 11095.0 ft with 3500.0 psi Set packer at 11095.0 ft with 3500.0 psi (cont...) Tested Permanent packer - Via annulus Tested Hanger plug Removed BOP stack Rigged up Xmas tree primary components Tested Tubing hanger Fill pits with Brine Circulated at 10600.0 ft Installed Hanger plug 4 04 November 98 MEMORANDUM State of Alaska / //Alaska Oil and Gas Conservation Commission / TO' David Johnsto/~n. DATE: 9124/98 Chairman THRU: Blair Wondzell, c ~ FILE NO: .DOC P. I. Supervisor FROM: Larry Wade. SUBJECT: Petroleum Inspector BOP Test Poole 7 PBU L1-31 PTD 98-015 September 24,1998: I traveled to Lisbourne to witness a BOP test on Poole 7. They had just had a 13 day rig move from Niakuk. The testing went fairly well. A ram door seal failed on the BOP stack. Other than that there was no failures and the testing was conducted across shifts which extended the test time somewhat. SU¥1MARY: Witnessed a BOP test on Poole 7, 0 failures, 5 hours Attachments: ad1 gixfe.xls cc; NON-CONFIDENTIAL · STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Drlg Contractor: Operator: Well Name: Casing Size: 7" Test: Initial X Workover: X DATE: Poole Rig No. 7 PTD # 98-015 Rig Ph.# ARCO Rep.: Les Peak L1-31 Rig Rep.: Set @ 14696' Location: Sec. ~ Weekly g/24/98 659-4814 John West T. R. Meridian Other Test Pressures 25015000 TEST DATA~ , ,, ,,, MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On-Location X Standing Order Posted (Gen) X Well Sign X Drl. Rig ok Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. 1 1 2 Test Pressure 250/5000 25O/5OOO P/F P P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/35OO PIF P P 250/5000 250/5000 P 250/5000 P 250/5000 P · 250t5000 P 250/5000 P 250/5000 MUD SYSTEM: V'~ual Alarm Tdp Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 17 No. Flanges ~34 Manual Chokes f Hydraulic Chokes I Test Pressure 250/5000 25O/5OOO Func~oned Func~oned P/F P P P P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2,975 1,700 minutes 38 sec. 2 minutes 55 sec. X Remote: X 2000-2010-2000 2000-2010-2000 P~g. TEST'RESULTS Number of Failures: 0 ,Test Time: 5.0 Hours. Number of valves tested 25 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. !. Supervisor at 279-1433 I I I II I REMARKS: Distribution: odg-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector FI-021L (Rev.12/94) STATE WITNESS'IS, EQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO WaNed By: W*~messed By: I I Adlgixfe Larry Wade WELL LOG TRANSMITTAL P~Active Diagnostic Services, Inc. To: ARCO Alaska, Inc. AOGCC Lori Taylor RE: Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 LOG DIGITAL/ MYLAR / BLUE LINE DIGITAL WELL DATE TYPE CD-ROM SEPIA PRINT(S) REPORT DATA FILM Open Hole I I 1 L1-31 q-~ -e~ Res. Eval. CH I I 1 Mech. CH 1 Caliper Survey I Signed' ~.,~, ~;'_~~~-~ Date' ~/~~~ Print Name: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, A/< 99734 Phone:(907)659-2307 Fax:(907)659-2314 E-mail: pdsprudhoe@NA800.net Website: wv,-w.memo~,log.com Final Log Distributio: STATE OF ALASKA ALASK,~OIL AND GAS CONSERVATION COq~IMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program []Operation Shutdown [] Re-Enter Suspended Well []Stimulate 2. Name of Operator ARCO Alaska Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 Type of well: [] Development [] Exploratory I--~ Stratigraphic [--1Service 4. Location of well at surface 3080' NSL, 2755' WEL, SEC. 1, T11N, R14E, UM At top of productive interval 831' NSL, 4694' WEL, SEC 35, T12N, R14E, UM At effective depth 1444' NSL, 724' WEL, SEC. 34, T12N, R14E, UM At total depth 1444' NSL, 724' WEL, SEC. 34, T12N, R14E, UM 6. Datum Elevation (DF or KB) KBE = 53.8' 7. Unit or Property Name Lisburne 8. Well Number L1-31 9. Permit Number 98-0015 10. APl Number 50-029-22860 11. Field and Pool Lisburne 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 14696' feet 10100 feet 14696' feet 10100 feet Length Size Structural Conductor 73' 20" S u rface 5102' 13-3/8" Intermediate Production 11187' 9-5/8" Liner 2043' 7" Plugs (measured) Junk (measured) 13420' MD, 5' x 2" CTU with 2-1/4" nozzle Cemented MD TVD 260 sx Arctic Set (Approx.) 115' 115' 2884 sx PF 'E', 500 sx Class 'G' 5142' 4556' 1000 sx Class 'G' 11224' 8557' 898 sx Class 'G' 11030' - 13073' 8465' - 9342' Perforation depth: measured N/A true vertical Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) Note: Open hole completion MD 13073' - 14696' RECEIVE 3-1/2" 9.3# L-8011183' ; 3-1/2" 9.3# L-8013021'-130~kaOii&GasCons. Com~l Anchorage Baker 7" Model S-3 Packer at 11091'; Baker 7"x 3-1/2" FB-1 Packer at 13021'; SCSSV HES SerieslO at 2067' 3. Attachments [] Description summary of proposal ~-I Detailed operations program [] BOP sketch 14. Estimated date for commencing operation September 14, 1998 16. If proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Bill Isaacson, 564-5521 15. Status of well classifications as: [~ Oil [] Gas [] Suspended Service Prepared By Name/Number: Carol Withey, 564-4114 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed :~¢./~ ~~_ Title Drilling Superintendent DanStv ~1~/1~ ¢,¢-~, ..,<),~/_,r'E Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity __ BOP Test f Location clearance __ Mechanical Integrity Test__ Subsequent form re~td 10- .... · .,.~na~ Signed By ¢,~.o,4e~.~e¢,~ Approved by order of the Commission 0avid W. Johnston ,,,,ov%~, ~'~,~commissioner Form 10-403 Rev. 06/15/88 /~/~"~ I Approval No. Date ¢ ~""2/~-' ¢¢ Submit In Triplicate r~iori LISBURNE WELLS #L1-31 WORK OVER SUMMARY Objective The objective of the L1-31 workover is to clean out the Alapah open hole interval that has bridged off, plug the well back to eliminate water zones, and run a slotted liner across the Alapah formation. SCOPE PRE-RIG WORK: Pull gas lift valve from station at 10,566' MD and displace the well to kill weight brine. Chemical cut 3-1/2" tubing above Baker S-3 packer. Freeze protect well to +2000' tvd. RIG WORK: MIRU rig. Pull the existing 3-1/2", 9.3# L-80 EUE-M completion string. Mill out and retrieve permanent packers at 11,091' and 13,021'. Cleanout open hole with 6" bit from 13,073' to 14,696' TD. Mill fish or push to bottom. Plug 8-1/2" hole back from 14,696' to 14,300' with cement. Run and set a 4-1/2" slotted liner across the open hole interval. Rerun same completion. Freeze protect well. Secure well and release rig. WELL HISTORY L1-31 was drilled and completed in March 1998 with Pool Rig 7. The well was drilled to a TD of 14,696' MD. A 7" liner was cemented across the Wahoo interval and the Alapah was left as an open hole completion. The well was completed with 3-1/2" tubing with 2 permanent production packers. Production was not able to access the open hole interval below 13,400' and it is assumed that the shale stringers in the open hole have bridged off the well, preventing the well from being stimulated and produced. An attempt was made to clean out the open hole with CTU. However, this was not successful and a fish was left in the open hole. Fish measures at 5' x 2" with 2-1/4" nozzle. L1-31 Current Completion 3-1/2' Tubing with X nipple 9-5/8' Casing set just above Lisbume 7' Liner cemented across NI of Wahoo L1-31 Proposed Completion ECP & Prod packer & 3-1/2' TT with XN Open hole across Alapah 4-1/2' slotted liner Across Alapah Cement Plug set across lower B zone. PBTD at 14250'MD Matt Brown 6/24/98 L1-31 WO diagram.xls 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 E~ Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc, 98-0015 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22860 4. Location of well at surface ~' ': ......................... ~ ~ , ¢,.%~. ~'I~';~~ ,. ]~ -.. 9. Unit or Lease Name 3080' NSL, 2755' WEL, SEC. 1, T11N, R14E, UM ~ ......... Lisburne At top of productive interval~I.._/~ ~'-~./-- .~/)'~¢; ~)~_..~i '' ~" 10. Well Number 831' NSL, 4694' WEL, SEC 35, T12N, R14E, UM i "~j~'!~..3 ~!~W~/i~,~. L1-31 At total depth ' .....]__~,__(_~__~_._.; ~~ 11. Field and Pool 1444' NSL, 724' WEL, SEC. 34, T12N, R14E, UM ~' ...................... '~'~"'""~'-'""" Lisburne 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 53.8'I ADL 028300 12. Date Spudded I 13. D~:to I.D. Reached I 14. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 2/6/98 3/16/98 3/30/98 ....... N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)119. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 14696' 10100 FTI 14696' 10100 FTI [~Yes ~]NoI 2067' MDI 1800' (Approx.) 22. Type Electric or Other Logs Run MWD/GR, CDR, USlT, FMI/GR, RFT 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" ~133# H-40 42' 115' 30" 260 sx Arctic Set (Approx.) 13-3/8" 68# L-80 40' 5142' 16" 2884 sx PF 'E', 500 sx Class 'G' 9-5/8" 47# L-80 37' 11224' 12-1/4" 1000 sx Class 'G' 7" 29# L-80 11030' 13073' 8-1/2" 898 sx Class 'G' t 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None Open hole completion MD 13073'-14696' 3-1/2", 9.3#, L-80 11183' 11091' MD TVD MD TVD 3-1/2", 9.3#, L-80 13021 '-13092' 13021' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 140 bbls diesel 27. PRODUCTION TESTt~ D 1 ~-I k l ^ I Date First Production I Method of Operation (Flowing, gas lift, etc.) U ~-~ I ~,) I I ~J J-~ L. ~i8sk8 0ii & Gas COBS. 04/08/98I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-DEL GAS-MCF WATER-DEL CHOKE SIZE IGAS-O'~'[.'[:~I~~- TEST PERIOD 1 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Wahoo Zone 6 11383' 8635' Wahoo Zone 7 11383' 8635' Wahoo Zone 5 11471' 8682' Wahoo Zone 4 11591' 8743' Wahoo Zone 3 12026' 8773' Wahoo Zone 2 12176' 9003' Wahoo Zone 1 12495' 9121' Alapah (Top) 13059' 9336' Alapah Zone D 13422' 9494' Alapah Zone C 13678' 9605' Alapah Zone B 14168' 9832' Alapah Zone A 14638' 10070' 31 List of Attachments Summa~ of Daily Drilling Repo~s, Su~eys ~,nch0rage /1 here correct ,o the best o, now,ed e Signed. ~~~ , / A // Lo~ell '~ /~'iling Engineering Supe~isor Date / LI~ 98-0015 Prepared By Name/Number: Carol Withey, 564-4114 ~umber Permit No. / Approval No. iNSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5.' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21-' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28.' If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Operator ARCO Performance Enquiry Report Date 01:36, 28 May 98 Page 1 The analysis is from - 21:00, 12 Feb 98 - to - 12:00, 24 Feb 98 Programs in Result Table: L1-31 Drill and Complete Well Type Time From Time To L1-31 Event 21:00, 12 Feb 98 21:00, 12 Feb 98 L1-31 Event 12:00, 24 Feb 98 12:00, 24 Feb 98 Duration Description 0 hr 0 min Obtained leak off 0 hr 0 min Obtained leak off E.M.W.(equivalent mud weight) 13.0 14.6 Hole Size MDR 12-1/4 8-1/2 Facility Date/Time 05 Feb 98 06 Feb 98 07 Feb 98 08 Feb 98 09 Feb 98 10 Feb 98 11 Feb 98 Lis DS 01 Progress Report Well L1-31 Page 1 Rig POOL 7 Date 27 May 98 Duration Activity 06:00-07:00 07:00-09:30 09:30-10:30 10:30-16:00 16:00-21:00 21:00-01:00 01:00-02:00 02:00-04:30 04:30-06:00 06:00-07:30 07:30-08:30 08:30-12:00 12:00-17:30 17:30-06:00 06:00-14:30 14:30-15:30 15:30-06:00 06:00-09:30 09:30-10:30 10:30-12:30 12:30-13:30 13:30-06:00 06:00-10:00 10:00-11:30 11:30-14:00 14:00-16:00 16:00-18:30 18:30-21:00 21:00-22:00 22:00-00:00 00:00-02:00 02:00-06:00 06:00-08:00 08:00-08:45 08:45-09:30 09:30-12:00 12:00-13:00 13:00-14:00 14:00-15:00 15:00-16:00 16:00-17:30 17:30-19:00 19:00-20:30 20:30-21:00 21:00-22:00 22:00-00:15 00:15-01:00 01:00-02:30 02:30-05:30 05:30-06:00 06:00-06:30 06:30-15:00 15:00-16:00 16:00-20:00 1 hr 2-1/2 hr 1 hr 5-1/2 hr 5 hr 4 hr 1 hr 2-1/2 hr 1-1/2 hr 1~1/2 hr 1 hr 3-1/2 hr 5-1/2 hr 12-1/2 hr 8-1/2 hr 1 hr 14-1/2 hr 3-1/2 hr 1 hr 2 hr 1 hr 16-1/2 hr 4 hr 1-1/2 hr 2-1/2 hr 2 hr 2-1/2 hr 2-1/2 hr 1 hr 2 hr 2 hr 4 hr 2 hr 3/4 hr 3/4 hr 2-1/2 hr 1 hr 1 hr 1 hr 1 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr lhr 2-1/4 hr 3/4 hr 1-1/2 hr 3 hr 1/2 hr 1/2 hr 8-1/2 hr 1 hr 4 hr Held safety meeting Rigged up Drillfloor / Derrick Held safety meeting Rigged up Drillfloor / Derrick Rigged up Divertor Rigged up Drillfloor / Derrick Racked back drill pipe Repaired Iron roughneck Racked back drill pipe Racked back drill pipe (cont...) Tested Well control Racked back drill pipe Made up BHA no. 1 Drilled to 1289.0 ft Drilled to 1945.0 ft (cont...) Took MWD survey at 1945.0 ft Drilled to 3330.0 ft Drilled to 3539.0 ft (cont...) Circulated at 3539.0 ft Pulled out of hole to 1760.0 ft R.I.H. to 3539.0 ft Drilled to 4352.0 ft Drilled to 5157.0 ft (cont...) Circulated at 5157.0 ft Pulled out of hole to 1760.0 ft R.I.H. to 5157.0 ft Circulated at 5157.0 ft Pulled out of hole to 1107.0 ft Laid down 740.0 ft of 5-1/2in OD drill pipe Pulled BHA Rigged up Casing handling equipment Ran Casing to 13-3/8in (1804.0 ft OD) Ran Casing to 3131.0 ft (13-3/8in OD) (cont...) Installed DV collar Circulated at 3131.0 ft Ran Casing to 5100.0 ft (13-3/8in OD) Circulated at 5100.0 ft Rigged up sub-surface equipment - Casing hanger Circulated at 5142.0 ft Rigged up Handling equipment Circulated at 5142.0 ft Mixed and pumped slurry - 372.000 bbl Displaced slurry - 780.000 bbl Functioned DV collar Circulated at 2011.0 ft Mixed and pumped slurry - 850.000 bbl Displaced slurry - 301.000 bbl Rigged down Casing handling equipment Rigged down Divertor Installed Casing spool Installed Casing spool (cont...) Rigged up BOP stack Installed BOP test plug assembly Tested Well control Progress Report Facility Lis DS O1 Well L1-31 Rig POOL 7 Page 2 Date 27 May 98 Date/Time 20:00-22:30 22:30-23:30 23:30-00:00 12 Feb 98 00:00-00:30 00:30-01:30 01:30-03:30 03:30-04:00 04:00-06:00 06:00-07:00 07:00-08:30 08:30-09:30 09:30-10:00 10:00-15:00 15:00-19:30 19:30-20:00 20:00-21:00 21:00-06:00 13 Feb 98 06:00-07:00 07:00-10:00 10:00-20:00 20:00-21:30 21:30-23:30 23:30-00:30 14 Feb 98 00:30-01:00 01:00-02:00 02:00-02:30 02:30-03:00 03:00-06:00 06:00-12:00 12:00-18:00 18:00-19:00 19:00-20:30 20:30-02:00 15 Feb 98 02:00-04:00 04:00-06:00 06:00-08:00 08:00-08:30 08:30-10:30 10:30-11:30 11:30-12:00 12:00-14:30 14:30-19:00 19:00-21:00 21:00-22:00 22:00-23:30 23:30-00:30 16 Feb 98 00:30-06:00 06:00-06:00 17 Feb 98 06:00-10:00 10:00-11:30 11:30-13:30 13:30-15:00 15:00-06:00 18 Feb 98 06:00-06:00 Duration 2-1/2 hr lhr 1/2 hr 1/2 hr 1 hr 2 hr 1/2 hr 2 hr 1 hr 1-1/2 hr lhr 1/2 hr 5hr 4-1/2 hr 1/2 hr 1 hr 9 hr lhr 3 hr 10hr 1-1/2 hr 2hr lhr 1/2 hr lhr 1/2 hr 1/2 hr 3hr 6hr 6 hr 1 hr 1-1/2 hr 5-1/2 hr 2 hr 2 hr 2 hr 1/2 hr 2hr 1 hr 1/2 hr 2-1/2 hr 4-1/2 hr 2 hr lhr 1-1/2 hr 1 hr 5-1/2 hr 24 hr 4 hr 1-1/2 hr 2 hr 1-1/2 hr 15hr 24 hr Activity Made up BHA no. 2 Singled in drill pipe to 822.0 ft Repaired Top drive Functioned Survey instruments Singled in drill pipe to 2011.0 ft Drilled installed equipment - DV collar Serviced Top drive Singled in drill pipe to 3900.0 ft Singled in drill pipe to 5055.0 ft (cont...) Circulated at 5055.0 ft Tested Casing Held safety meeting Repaired Draw works Drilled cement to 5190.0 ft Circulated at 5190.0 ft Performed formation integrity test Drilled to 5857.0 ft Drilled to 5966.0 fi (cont...) Serviced Mud shakers Drilled to 6632.0 fi Circulated at 6632.0 ft Pulled out of hole to 5130.0 ft Serviced Block line Serviced Draw works R.I.H. to 6632.0 ft Drilled to 6647.0 ft Serviced Mud shakers Drilled to 6820.0 fi Drilled to 7190.0 ft (cont...) Circulated closed in well at 7190.0 ft Monitor wellbore pressures Circulated at 7190.0 ft Drilled to 7468.0 fi Circulated at 7468.0 ft Pulled out of hole to 4086.0 ft Pulled out of hole to 822.0 ft (cont...) Laid down 465.0 ft of 5-1/2in OD drill pipe Pulled BHA Serviced Drillfloor / Derrick Repaired Well control Made up BHA no. 3 Singled in drill pipe to 3025.0 ft R.I.H. to 7230.0 fi Reamed to 7383.0 ft Circulated closed in well at 7383.0 fi Reamed to 7468.0 ft Drilled to 7817.0 ft Drilled to 8968.0 ft (cont...) Drilled to 9193.0 fi (cont...) Circulated at 9193.0 fi Pulled out of hole to 7412.0 ft R.I.H. to 9193.0 fi Drilled to 10224.0 fi Drilled to 10642.0 fi (cont...) Progress Report Facility Lis DS 01 Well L1-31 Rig POOL 7 Page 3 Date 27 May 98 Date/Time 19 Feb 98 06:00-07:30 07:30-09:00 09:00-15:30 15:30-19:00 19:00-19:30 19:30-22:30 22:30-23:00 23:00-01:30 20 Feb 98 01:30-02:00 02:00-02:30 02:30-06:00 06:00-07:00 07:00-08:00 08:00-08:30 08:30-09:30 09:30-10:30 10:30-06:00 21Feb98 06:00-11:30 11:30-13:00 13:00-15:00 15:00-15:30 15:30-21:00 21:00-03:00 22 Feb 98 03:00-06:00 06:00-06:30 06:30-08:00 08:00-08:30 08:30-09:30 09:30-16:00 16:00-16:30 16:30-20:00 20:00-21:00 21:00-01:00 23 Feb 98 01:00-02:30 02:30-03:30 03:30-04:00 04:00-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-11:00 11:00-16:30 16:30-20:00 20:00-00:00 24 Feb 98 00:00-01:30 01:30-03:00 03:00-06:00 06:00-08:30 08:30-09:00 09:00-10:00 10:00-11:30 Duration 1-1/2 hr 1-1/2 hr 6-1/2 hr 3-1/2 hr 1/2 hr 3 hr 1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 3-1/2 hr 1 hr lhr 1/2 hr 1 hr 1 hr 19-1/2 hr 5-1/2 hr 1-1/2 hr 2hr 1/2 hr 5-1/2 hr 6hr 3 hr 1/2 hr 1-1/2 hr 1/2 hr lhr 6-1/2 hr 1/2 hr 3-1/2 hr lhr 4 hr 1-1/2 hr lhr 1/2 hr 1 hr 1 hr 1/2 hr 1-1/2 hr 1 hr 1 hr 1/2 hr 1/2 hr 5-1/2 hr 3-1/2 hr 4 hr 1-1/2 hr 1-1/2 hr 3 hr 2-1/2 hr 1/2 hr 1 hr 1-1/2 hr Activity Drilled to 10644.0 ft (cont...) Circulated at 10644.0 ft Pulled out of hole to 380.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Made up BHA no. 4 R.I.H. to 1300.0 ft Tested M.W.D. tool - Via string R.I.H. to 8000.0 ft R.I.H. to 9975.0 ft (cont...) Reamed to 10044.0 ft R.I.H. to 10605.0 ft Washed to 10644.0 ft Set tool face Drilled to 11140.0 ft Drilled to 11248.0 ft (cont...) Circulated at 11248.0 ft Pulled out of hole to 10130.0 ft R.I.H. to 11248.0 ft Circulated at 11248.0 ft Pulled out of hole to 380.0 ft Pulled BHA Removed Wear bushing Tested Top ram Held safety meeting Rigged up Casing handling equipment Ran Casing to 5140.0 ft (9-5/8in OD) Circulated at 5140.0 ft Ran Casing to 8180.0 ft (9-5/8in OD) Circulated at 8180.0 ft Ran Casing to 11224.0 ft (9-5/8in OD) Circulated at 11224.0 ft Rigged up High pressure lines Tested High pressure lines Mixed and pumped slurry - 205.000 bbl Displaced slurry - 600.000 bbl Displaced slurry - 820.000 bbl (cont...) Rigged down Casing handling equipment Installed Seal assembly Rigged up Top ram Tested Top ram Installed Wear bushing Made up BHA no. 5 Singled in drill pipe to 3984.0 ft R.I.H. to 11142.0 ft Tested Casing - Via annulus and string Drilled cement to 11200.0 ft Circulated at 11200.0 ft Circulated at 11200.0 ft (cont...) Drilled cement to 11248.0 ft Drilled to 11268.0 fl Circulated at 11268.0 ft Facility Date/Time 25 Feb 98 26 Feb 98 27 Feb 98 28 Feb 98 01 Mar 98 02 Mar 98 03 Mar 98 04 Mar 98 Lis DS 01 Progress Report Well L1-31 Page 4 Rig POOL 7 Date 27 May 98 11:30-12:00 12:00-21:00 21:00-22:30 22:30-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-13:00 13:00-14:00 14:00-14:30 14:30-06:00 06:00-05:30 05:30-06:00 06:00-06:30 06:30-13:00 13:00-14:30 14:30-15:00 15:00-18:30 18:30-19:00 19:00-19:30 19:30-22:00 22:00-03:00 03:00-03:30 03:30-06:00 06:00-14:30 14:30-16:30 16:30-17:30 17:30-18:30 18:30-00:00 00:00-01:00 O1:00-03:30 03:30-06:00 06:00-06:30 06:30-08:00 08:00-10:00 10:00-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-15:00 15:00-15:30 15:30-16:30 16:30-18:00 18:00-18:30 18:30-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 06:00-11:00 11:00-12:00 Duration 1/2 hr 9 hr 1-1/2 hr 5-1/2 hr lhr 1 hr 1 hr 1/2 hr 1 hr 4-1/2 hr lhr 1/2 hr 15-1/2 hr 23-1/2 hr 1/2 hr 1/2 hr 6-1/2 hr 1-1/2 hr 1/2 hr 3-1/2 hr 1/2 hr 1/2 hr 2-1/2 hr 5hr 1/2 hr 2-1/2 hr 8-1/2 hr 2 hr 1 hr 1 hr 5-1/2 hr 1 hr 2-1/2 hr 2-1/2 hr 1/2 hr 1-1/2 hr 2 hr 8hr 1/2 hr 11-1/2 hr 1/2 hr 8-1/2 hr 1/2 hr 1 hr 1-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 5 hr 1 hr Activity Performed formation integrity test Drilled to 11448.0 ft Circulated at 11448.0 ft Pulled out of hole to 915.0 ft Laid down 372.0 ft of 5-1/2in OD drill pipe Pulled BHA Made up BI-IA no. 6 Serviced Drillfloor / Derrick Tested M.W.D. tool - Via string R.I.H. to 11224.0 ft Serviced Block line Took MWD survey at 11448.0 ft Drilled to 11770.0 ft Drilled to 11962.0 ft (cont...) Circulated at 11962.0 ft Circulated at 11962.0 ft (cont...) Pulled out of hole to 560.0 ft Pulled BHA Retrieved Wear bushing Tested BOP stack Installed Wear bushing Serviced Drillfloor / Derrick Made up BHA no. 7 R.I.H. to 11960.0 ft Functioned downhole tools at 11962.0 ft Drilled to 11989.0 ft Drilled to 12089.0 ft (cont...) Circulated at 11089.0 ft Drilled to 12094.0 ft Took MWD survey at 12094.0 ft Pulled out of hole to 557.0 ft Pulled BHA Made up BHA no. 8 R.I.H. to 5000.0 ft Held safety meeting R.I.H. to 11920.0 ft Logged hole with LWD: Formation evaluation (FE) from 11920.0 ft to 12094.0 ft Drilled to 12292.0 ft Held safety meeting Drilled to 12530.0 ft Held safety meeting Drilled to 12665.0 ft Tested MWD - Via string Circulated at 12665.0 ft Took MWD survey at 12398.0 ft Held safety meeting Drilled to 12814.0 ft Held safety meeting Drilled to 12918.0 ft Held safety meeting Drilled to 13104.0 ft Drilled to 13123.0 ft (cont...) Circulated at 13123.0 ft Progress Report Facility Lis DS O1 Well L1-31 Rig POOL 7 Page 5 Date 27 May 98 Date/Time 12:00-12:30 12:30-13:30 13:30-15:00 15:00-16:30 16:30-18:00 18:00-00:00 05 Mar 98 00:00-01:30 01:30-02:00 02:00-04:00 04:00-04:30 04:30-05:00 05:00-06:00 06:00-06:05 06:05-06:30 06:30-10:00 10:00-17:00 17:00-18:15 18:15-19:00 19:00-06:00 06 Mar 98 06:00-06:00 07 Mar 98 06:00-06:00 08 Mar 98 06:00-23:30 23:30-01:00 09 Mar 98 01:00-06:00 06:00-08:00 08:00-11:00 11:00-15:30 15:30-18:00 18:00-18:30 18:30-19:30 19:30-20:00 20:00-21:30 21:30-22:00 22:00-06:00 10 Mar 98 06:00-06:00 11 Mar 98 06:00-20:30 20:30-22:00 22:00-05:00 12 Mar 98 05:00-06:00 06:00-06:30 06:30-11:30 11:30-14:30 14:30-17:00 17:00-17:30 17:30-20:30 20:30-21:45 21:45-06:00 13 Mar 98 06:00-06:00 14 Mar 98 06:00-12:00 12:00-13:30 13:30-20:00 20:00-21:00 21:00-22:00 22:00-02:30 Duration 1/2 hr 1 hr 1-1/2 hr 1-1/2 hr 1-1/2 hr 6 hr 1-1/2 hr 1/2 hr 2 hr 1/2 hr 1/2 hr lhr 0hr 1/4 hr 3-1/2 hr 7 hr 1-1/4 hr 3/4 hr llhr 24 hr 24 hr 17-1/2 hr 1-1/2 hr 5 hr 2 hr 3 hr 4-1/2 hr 2-1/2 hr 1/2 hr lhr 1/2 hr 1-1/2 hr 1/2 hr 8 hr 24 hr 14-1/2 hr 1-1/2 hr 7 hr 1 hr 1/2 hr 5 hr 3 hr 2-1/2 hr 1/2 hr 3hr 1-1/4 hr 8-1/4 hr 24 hr 6 hr 1-1/2 hr 6-1/2 hr 1 hr lhr 4-1/2 hr Activity Circulated at 13123.0 ft Pulled out of hole to 11224.0 ft Serviced Block line R.I.H. to 13123.0 ft Circulated at 13123.0 ft Pulled out of hole to 572.0 ft Pulled BHA Installed BOP test plug assembly Tested All functions Installed Wear bushing Serviced Top drive Made up BHA no. 9 Made up BHA no. 9 (cont...) Held safety meeting Made up BHA no. 9 R.I.H. to 12138.0 ft Reamed to 12216.0 ft R.I.H. to 13123.0 ft Drilled to 13194.0 ft Drilled to 13330.0 ft (cont...) Drilled to 13490.0 ft (cont...) Drilled to 13560.0 ft (cont...) Circulated at 13560.0 ft Pulled out of hole to 4000.0 ft Pulled out of hole to 250.0 ft (cont...) Pulled BHA Made up BHA no. 10 R.I.H. to 6180.0 ft Held safety meeting R.I.H. to 10300.0 ft Serviced Top drive R.I.H. to 13520.0 ft Reamed to 13560.0 ft Drilled to 13617.0 ft Drilled to 13835.0 ft (cont...) Drilled to 14010.0 ft (cont...) Circulated at 14010.0 ft Pulled out of hole to 929.0 ft Pulled BHA Held safety meeting Tested Well control Made up BHA no. 11 R.I.H. to 6647.0 ft Serviced Top drive R.I.H. to 13784.0 ft Reamed to 14010.0 ft Drilled to 14084.0 ft Drilled to 14425.0 ft (cont...) Drilled to 14465.0 ft (cont...) Circulated at 14465.0 ft Pulled out of hole to 214.0 ft Pulled BHA Made up BHA no. 12 R.I.H. to 11220.0 ft Progress Report Facility Lis DS O1 Well L1-31 Page 6 Rig POOL 7 Date 27 May 98 Date/Time 15 Mar 98 02:30-03:00 03:00-03:30 03:30-05:00 05:00-06:00 06:00-00:00 16 Mar 98 00:00-01:30 01:30-03:00 03:00-04:00 04:00-06:00 06:00-07:30 07:30-14:30 14:30-16:00 16:00-19:00 19:00-20:00 20:00-22:30 22:30-23:30 23:30-03:00 17 Mar 98 03:00-05:00 05:00-06:00 06:00-11:30 11:30-12:00 12:00-18:30 18:30-19:00 19:00-22:30 22:30-02:00 18 Mar 98 02:00-05:30 05:30-06:00 06:00-07:00 07:00-11:30 11:30-13:00 13:00-14:00 14:00-17:30 17:30-22:00 22:00-22:30 22:30-01:00 19 Mar 98 01:00-06:00 06:00-17:30 17:30-18:30 18:30-22:00 22:00-23:00 23:00-00:00 20 Mar 98 00:00-04:00 04:00-04:30 04:30-06:00 06:00-09:30 09:30-16:30 16:30-18:00 18:00-23:00 23:00-00:00 21 Mar 98 00:00-04:00 04:00-06:00 06:00-07:00 07:00-14:00 14:00-16:30 Duration 1/2 hr 1/2 hr 1-1/2 hr 1 hr 18hr 1-1/2 hr 1-1/2 hr lhr 2 hr 1-1/2 hr 7 hr 1-1/2 hr 3 hr lhr 2-1/2 hr 1 hr 3-1/2 hr 2 hr lhr 5-1/2 hr 1/2 hr 6-1/2 hr 1/2 hr 3-1/2 hr 3-1/2 hr 3-1/2 hr 1/2 hr 1 hr 4-1/2 hr 1-1/2 hr lhr 3-1/2 hr 4-1/2 hr 1/2 hr 2-1/2 hr 5 hr 11-1/2 hr lhr 3-1/2 hr 1 hr 1 hr 4 hr 1/2 hr 1-1/2 hr 3-1/2 hr 7 hr 1-1/2 hr 5 hr 1 hr 4 hr 2 hr lhr 7 hr 2-1/2 hr Activity Serviced Block line Serviced Top drive R.I.H. to 14465.0 ft Drilled to 14473.0 ft Drilled to 14696.0 ft (cont...) Circulated at 14696.0 ft Pulled out of hole to 12700.0 £t R.I.H. to 14696.0 ft Circulated at 14696.0 ft Circulated at 14696.0 ft (cont...) Pulled out of hole to 929.0 ft Pulled BHA Rig waited · Service personnel Rigged up Wireline units Conducted electric cable operations Rigged down Wireline units Rig waited · Service personnel Rigged up Logging/braided cable equipment Repaired Logging/braided cable equipment Repaired Logging/braided cable equipment (cont...) Rigged up Logging/braided cable equipment R.I.H. to 11050.0 ft Circulated at 11050.0 ft Installed Logging/braided cable equipment Ran logs on tubulars Ran logs on tubulars Rigged down Logging/braided cable equipment Rigged down Logging/braided cable equipment (cont...) Pulled out of hole to 80.0 ft Rigged down Logging/braided cable equipment Rigged up Logging/braided cable equipment Repaired Formation logs R.I.H. to 10693.0 ft Circulated at 10693.0 ft Rigged up Logging/braided cable equipment Ran logs on tubulars Ran logs on tubulars (cont...) Rigged down Logging/braided cable equipment Pulled out of hole to 80.0 ft Rigged down sub-surface equipment - Formation logs Rigged up sub-surface equipment - Formation logs R.I.H. to 11095.0 ft Circulated at 11095.0 ft Rigged up Logging/braided cable equipment R.I.H. to 11680.0 ft Ran logs on tubulars Rigged down sub-surface equipment - Formation logs Pulled out of hole to 80.0 ft Rigged down Logging/braided cable equipment Tested Well control Made up BHA no. 13 Made up BHA no. 13 (cont...) R.I.H. to 14696.0 ft Circulated at 14696.0 ft Facility Date/Time 22 Mar 98 23 Mar 98 24 Mar 98 25 Mar 98 26 Mar 98 Lis DS 01 Progress Report Well L1-31 Rig POOL 7 Duration Activity 16:30-18:00 18:00-19:00 19:00-23:00 23:00-02:30 02:30-03:30 03:30-04:00 04:00-06:00 06:00-07:30 07:30-11:00 11:00-13:00 13:00-14:30 14:30-20:00 20:00-23:00 23:00-06:00 06:00-11:30 11:30-12:00 12:00-14:30 14:30-16:30 16:30-17:30 17:30-18:30 18:30-19:30 19:30-22:00 22:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-08:00 08:00-12:00 12:00-15:00 15:00-21:00 21:00-22:00 22:00-00:30 00:30-04:00 04:00-05:00 05:00-06:00 06:00-07:30 07:30-09:30 09:30-11:00 11:00-17:00 17:00-19:30 19:30-20:30 20:30-20:45 20:45-21:30 21:30-22:30 22:30-23:30 23:30-04:00 04:00-06:00 06:00-08:00 08:00-09:30 09:30-13:30 13:30-15:30 15:30-16:00 16:00-21:00 21:00-21:30 1-1/2 hr lhr 4 hr 3-1/2 hr 1 hr 1/2 hr 2 hr 1-1/2 hr 3-1/2 hr 2hr 1-1/2 hr 5-1/2 hr 3 hr 7 hr 5-1/2 hr 1/2 hr 2-1/2 hr 2 hr 1 hr 1 hr lhr 2-1/2 hr 5 hr lhr 2 hr 1/2 hr 1-1/2 hr 4hr 3 hr 6 hr 1 hr 2-1/2 hr 3-1/2 hr 1 hr 1 hr 1-1/2 hr 2 hr 1-1/2 hr 6 hr 2-1/2 hr 1 hr 1/4 hr 3/4 hr lhr 1 hr 4-1/2 hr 2hr 2 hr 1-1/2 hr 4hr 2 hr 1/2 hr 5hr 1/2 hr Pulled out of hole to 12315.0 ft R.I.H. to 14696.0 ft Circulated at 14696.0 ft Pulled out of hole to 11200.0 ft Serviced Block line Serviced Top drive Pulled out of hole to 7000.0 ft Pulled out of hole to 5055.0 ft (cont...) Laid down 4185.0 ft of 5-1/2in OD drill pipe Pulled BHA Rigged up Casing handling equipment Ran Liner to 2054.0 ft (7in OD) Rigged up Drillstring handling equipment Ran Drillpipe in stands to 8000.0 ft Ran Drillpipe in stands to 13073.0 ft (cont...) Circulated at 13073.0 ft Functioned Inflatable packer Circulated at 13073.0 ft Mixed and pumped slurry - 184.000 bbl Displaced slurry - 297.000 bbl Reverse circulated at 11030.0 ft Rigged down Handling equipment Pulled Drillpipe in stands to 20.0 ft Retrieved Setting tools Installed BOP stack Installed BOP stack (cont...) Rigged up Drillstring handling equipment Made up BHA no. 14 Singled in drill pipe to 3695.0 ft R.I.H. to 12715.0 ft Tested Liner Drilled cement to 13033.0 ft Drilled installed equipment - DV collar R.I.H. to 14696.0 ft Circulated at 14696.0 ft Circulated at 14696.0 ft (cont...) Circulated at 14696.0 ft Serviced Fluid system Pulled out of hole to 3698.0 ft Laid down 1650.0 ft of 3-1/2in OD drill pipe Pulled out of hole to 372.0 ft Pulled BHA Made up BHA no. 15 R.I.H. to 2010.0 ft Rigged up Drillstring handling equipment R.I.H. to 13030.0 ft Circulated at 13030.0 ft Serviced Fluid system Circulated at 13030.0 ft Pulled out of hole to 2010.0 ft Pulled BHA Rigged up Wireline units Conducted electric cable operations Rigged down Wireline units Page Date 7 27 May 98 Progress Report Facility Lis DS 01 Well L1-31 Page 8 Rig POOL 7 Date 27 May 98 Date/Time 21:30-23:00 23:00-01:00 27 Mar 98 01:00-06:00 06:00-09:30 09:30-10:30 10:30-11:00 11:00-00:00 28 Mar 98 00:00-00:30 00:30-03:30 03:30-06:00 06:00-16:00 16:00-17:00 17:00-20:30 20:30-22:00 22:00-22:30 22:30-04:00 29 Mar 98 04:00-06:00 06:00-07:00 07:00-09:00 09:00-10:00 10:00-11:00 11:00-13:00 13:00-14:30 14:30-15:30 15:30-16:30 16:30-17:30 17:30-00:00 30 Mar 98 00:00-03:30 03:30-04:30 04:30-06:00 06:00-07:00 Duration 1-1/2 hr 2 hr 5 hr 3-1/2 hr 1 hr 1/2 hr 13 hr 1/2 hr 3 hr 2-1/2 hr 10 hr lhr 3-1/2 hr 1-1/2 hr 1/2 hr 5-1/2 hr 2 hr 1 hr 2 hr 1 hr 1 hr 2 hr 1-1/2 hr 1 hr 1 hr lhr 6-1/2 hr 3-1/2 hr lhr 1-1/2 hr 1 hr Activity Rigged up Completion string handling equipment Serviced Permanent packer Ran Drillpipe in stands to 6375.0 ft Ran Drillpipe in stands to 13092.0 ft (cont...) Functioned Permanent packer Repaired Swivel Laid down 10321.0 ft of 5-1/2in OD drill pipe Rigged up Drillstring handling equipment Laid down 2700.0 ft of 3-1/2in OD drill pipe Rigged up Tubing handling equipment Ran Tubing to 9115.0 ft (3-1/2in OD) Tested Tubing retrievable safety valve Ran Tubing to 11186.0 ft (3-1/2in OD) Installed Hanger assembly Worked toolstring at 11192.0 ft Reverse circulated at 11185.0 ft Rigged down sub-surface equipment - Hanger assembly Rigged down sub-surface equipment - Hanger assembly (cont...) Tested Hydraulic packer Investigated pressure change Tested Hydraulic packer Repaired High pressure lines Tested Hydraulic packer Rigged up Well control Rigged down Completion string handling equipment Serviced Well control Rigged down BOP stack Installed Xmas tree primary components Removed Hanger plug Circulated at 2000.0 ft Installed Hanger plug Anadrili/Schlumberger Survey Report WELL INFORMATION TD Date: Client: ARCO Alaska, Inc. Field: Lisburne Well Name: LI-$1 Permanent datum: Mean Sea Level Depth measured from: RKB Elevation of kelly bushing: 53.80 Elevation of rig floor: 53.80 Elevation of ground level: 13.20 Magnetic Declination: 28.40 Grid Convergence: 0.00 Total Correction: 28.40 TIE IN POINT Measured Depth: 0.00 True Vertical Depth: 0.00 Inclination: 0.00 Azimuth: 0.00 N/S displacement: 0.00 E/W displacement: 0.00 Azimuth from rotory table to target: 287.5 ORIGINAL NAR BPXA PDC Measured Station Station Station Vertical Vertical Depth Inclination Azimuth Interval Depth Section (ft) (deg) (deg) (ft) (ft) (fi) 0.0 0.00 0.0 0.00 0.00 0.00 370.1 0.52 200.4 370.10 370.09 0.08 480.3 0.67 179.4 110.10 480.19 -0.09 572.1 0.96 187.8 91.90 572.08 -0.39 666.1 0.64 189.3 94.00 666.07 -0.59 756.7 0.52 201.7 90.60 756.67 -0.64 848.9 0.48 192.7 92.20 848.86 -0.64 941.7 0.68 207.7 92.80 941.66 -0.57 1034.5 0.71 206.6 92.80 1034,45 -0.38 1129.0 0.65 206.2 94,50 1128.94 -0.21 1221,7 0,35 188,1 92,70 1221,64 -0,18 1310,9 0,29 191,8 89,20 1310,84 -0,24 1402,1 0,61 223,3 91,20 1402,04 -0,06 1498,9 0.47 195,9 96,80 1498,83 . 0,16 1594,9 0.11 117,1 96,00 1594,83 0,06 Latitude (N/-S) (ft) 0.00 -1.57 -2.69 -3.99 -5.28 -6.17 -6.93 -7.80 -8.80 -9.80 -10.56 -11.05 -11.63 -12.38 -12.80 Departure Displac mere (El-W) at Azimuth (ft) (fl) (deg) 0.00 -0,59 -0,75 -0,85 -1,04 -1,28 -1,52 -1,86 -2,37 -2,87 -3.14 -3.23 -3.61 -4.07 -4.10 0.00 0.00 1.68 200.40 2.79 195.66 4.08 192.06 5.39 191.17 6.30 191.70 7.10 192.34 8.02 193.40 9.11 195.08 10.22 196.32 11.01 196.58 11.51 196.28 12.17 197.24 13.03 198.19 13.44 197.74 Dog Leg Severity (deg/ht) 0.00 0.14 0.24 0.34 0.34 0.19 0.10 0.27 0.04 0.06 0.36 0.07 0.43 0.30 0.48 Anadrill Schlumberger Page I 3/17/98 Measured Station Station Depth Inclination Azimuth (fi) (deg) (deg) Station Interval (ft) 1690.6 0.40 109.3 95.70 1781.8 0.40 141.7 91.10 1877.8 0.25 103.2 96.10 1969.9 1.16 310.6 92.10 2064.7 3.02 308.7 94.80 2157.7 4.99 308.5 93.00 2251.1 7.43 303.4 93.40 2346.9 9.92 304.0 95.80 2440.9 10.98 306.3 94.00 2534.5 13.49 301.4 93.60 2630.9 16.22 293.9 96.40 2725.9 18.87 290.3 95.00 2818.6 21.25 288.2 92.70 2911.8 22.27 290.3 93.20 3004.4 23.66 292.9 92.60 3097.2 24.72 293.7 92.80 3191.3 27.96 293.8 94.10 3279.9 30.50 292.8 88.60 3373.0 32.77 292.5 93.10 3470.7 35.26 291.9 97.60 3562.8 36.49 292.9 92.10 3656.2 37.66 293.9 93.50 3753.5 39.86 292.9 97.30 3853.6 42.39 292.4 100.10 3946.4 45.42 294.4 92.70 4037.8 44.79 294.3 91.50 4131.2 44.58 294.7 93.40 4221.2 47.49 294.0 90.00 4320.4 47.16 293.6 99.20 4413.0 47.14 293.6 92.60 4508.6 47.79 294.0 95.50 4599.4 48.36 294.8 90.90 4694.0 48.48 295.6 94.60 4791.0 48.33 295.4 97.00 4880.1 48.26 296.4 89.10 4974.0 48.11 296.2 93.90 5071.3 48.14 297.0 97.30 5193.4 47.62 298.5 122.10 5256.0 47.24 297.8 62.60 5348.7 47.60 295.8 92.70 Vertical Depth fit) 1690.53 1781.63 1877.73 1969.82 2064.55 2157.32 2250.17 2344.86 2437.30 2528.77 2621.95 2712.53 2799.60 2886.16 2971.42 3056.07 3140.39 3217.70 3296.96 3377.85 3452.48 3527.08 3602.95 3678.34 3745.13 3809.71 3876.12 3938.59 4005.83 4068.81 4133.37 4194.10 4256.89 4321.28 4380.56 4443.17 4508.12 4590.01 4632.36 4695.08 Vertical Section (ft) -0.37 -0.95 -1.44 -0.78 2.43 8.49 18.09 31.97 48.20 67.24 91.54 120.08 151.86 186.38 222.41 260.24 301.74 344.78 393.41 447.82 501.59 557.66 618.25 683.81 747.74 812.09 877.28 941.59 1014.09 1081.59 1151.53 1218.67 1288.80 1360.63 1426.44 1495.60 1567.14 1656.25 1701.56 1768.92 Latitude (N/-S) (t~) -12.96 -13.31 -13.62 -13.06 -10.87 -6.82 -0.97 7.05 16.88 27.85 39.17 49.87 60.32 71.72 85.04 100.09 116.90 134.00 152.80 173.42 193.99 216.38 240.56 265.91 291.46 Departure Displac mcnt (E/-W) at Azimuth fit) (It) (deg) -3.70 -3.20 -2.79 -3.30 -5.98 -11.06 -19.28 -31.29 -45.22 -61.73 ,83.64 -110.18 -140.21 -172.81 -206.39 -241.31 -279.52 -319.26 -364.32 -414.87 -464.77 -516.49 -572.40 -633.16 -692.13 13.47 195.93 13.69 193.52 13.90 191.57 13.47 194.18 12.41 208.80 12.99 238.31 19.30 267.12 32.08 282.70 48.27 290.47 67.72 294.28 92.35 295.09 120.94 294.35 152.63 293.28 187.11 292.54 223.22 292.39 261.25 292.53 302.98 292.70 346.24 292.77 395.07 292.75 449.66 292.69 503.63 292.66 559.99 292.73 620.90 292.80 686.73 292.78 750.99 292.84 318.19 -751.18 815.79 292.96 345.42 -810.95 881.45 293.07 372.12 -869.96 946.20 293.16 401.55 -936.69 1019.13 293.20 428.73 -998.90 1087.02 293.23 -1063.28 -1124.87 -1188.90 -1254.38 -1314.21 457.13 485.07 515.20 546.43 575.48 1157.39 293.26 1225.00 293.33 1295.73 293.43 1368.23 293.54 1434.69 293.65 606.49 -1376.95 1504.60 293.77 638.93 -1441.73 1576.97 293.90 681.09 -1521.88 1667.34 294.11 702.85 -1562.53 1713.33 294.22 733.62 -1623.45 1781.51 294.32 Dog Leg Severity (deg/hO 0.30 0.24 0.27 1.51 1.96 2.12 2.68 2.60 1.21 2.90 3.46 3.01 2.68 1.38 1.86 1.20 3.44 2.92 2.44 2.57 1.48 1.41 2.35 2.55 3.59 0.69 0.38 3.28 0.45 0.02 0.75 0.91 0.65 0.22 0.84 0.23 0.61 1.01 1.02 1.64 Anadrill Schlumberger Page 2 3/17/98 Measured Station Station Depth Inclination Azimuth (ft) (deg) (deg) Station Interval (it) 5440.1 47.71 295.3 91.40 5537.7 47.41 295.5 97.60 5630.9 47.07 295.1 93.20 5722.2 46.86 295.3 91.30 5813.2 47.01 294.7 91.00 5911.3 47.25 294.5 98.10 6005.4 47.30 295.2 94.10 6099.1 48.05 295.8 93.70 6191.9 47.76 295.0 92.80 6288.0 47.75 295.2 96.10 6380.2 47.54 295.1 92.20 6473.3 47.48 295.0 93.10 6571.7 47.40 294.5 98.40 6663.2 48.71 295.5 91.50 6752.9 48.99 295.9 89.70 6849.2 49.42 295.8 96.30 6940.0 48.91 295.8 90.80 7032.3 48.20 295.2 92.30 7130.4 48.58 295.8 98.10 7224.5 48.44 295.5 94.10 7316.2 48.32 295.4 91.70 7406.3 48.23 295.3 90.10 7475.8 48.25 297.1 69.50 7515.2 48.28 297.1 39.40 7609.6 48.37 296.2 94.40 7706.4 48.69 297.4 96.80 7799,9 48.89 297.2 93.50 7891.8 48.72 296.1 91.90 7984.3 48.95 297.9 92.50 8077.8 48.92 297.0 93.50 8177.1 49.07 297.5 99.30 8266.2 49.17 297.0 89.10 8359.3 47.86 294.8 93.10 8454.1 48.11 296.1 94.70 8550.5 48.17 295.0 96.50 8641.9 47.13 294.3 91.40 8737.1 47.26 294.0 95.10 8831.6 47.25 293.7 94.60 8923.1 47.44 294.2 91.50 9016.8 47.50 294.5 93.70 Vertical Depth (ft) 4756.65 4822.51 4885.79 4948.10 5010.23 Vertical Section (it) 1835.80 1907.15 1974.94 2041.07 2106.99 Latitude (N/-S) (ft) Departure Displac ment (El-W) at Azimuth (It) (ft) (deg) 762.75 -1684.40 1849.05 294.36 793.65 -1749.46 1921.07 294.40 822.89 -1811.33 1989.49 294.43 851.30 -1871.71 2056.21 294.46 879.40 -1931.96 2122.69 294.47 5076.97 2178.33 909.33 -1997.34 2194.59 294.48 5140.82 2246.89 938.38 -2060.06 2263.72 294.49 5203.91 2315.49 968.20 -2122.59 2332.98 294.52 5266.12 2383.70 997.74 -2184.79 2401.83 294.55 5330.73 2454.21 1027.92 -2249.21 2472.97 294.56 5392.85 2521.74 1056.88 -2310.89 2541.10 294.58 5455.73 2589.80 1085.94 -2373.08 2609.75 294.59 5522.29 2661.70 1116.29 -2438.90 2682.23 294.59 5583.45 2729.17 1145.05 -2500.58 2750.28 294.60 5642.47 2796.02 1174.34 -2561.44 2817.81 294.63 2868.15 2936.13 3004.64 3077.27 3147.05 1206.13 1236.03 1265.82 1297.40 1327.91 5705.39 5764.76 5825.85 5891.00 5953.34 -2627.05 -2688.90 -2751.34 -2817.54 -2881.09 2890.70 294.66 2959.38 294.69 3028.56 294.71 3101.90 294.72 3172.38 294.75 6014.25 3214.94 1357.37 -2942.99 3240.93 294.76 6074.21 3281.56 1386.16 -3003.76 3308.17 294.77 6120.50 3332.80 1409.04 -3050.27 3359.99 294.79 6146.73 3361.79 1422.44 -3076.44 3389.37 294.81 6209.50 3431.40 1454.06 -3139.46 3459.84 294.85 6273.60 3502.98 1486.77 -3204.20 3532.33 294.89 6335.20 3572.29 1519.03 -3266.70 3602.61 294.94 6395.73 3640.56 1550.05 -3328.51 3671.73 294.97 6456.62 3709.24 1581.66 -3390.55 3741.32 295.01 6518.04 3778.67 1614.16 -3453.11 3811.75 295.05 3852.53 3918.92 3987.90 4057.58 4128.74 6583.20 6641.51 6703.18 6766.57 6830.97 -3519.73 -3579.62 -3642.34 -3705.87 -3770.71 1648.47 1679.31 1709.79 1740.02 1771.02 3886.63 295.10 3953.95 295.13 4023.68 295.15 4094.04 295.15 4165.90 295.16 6892.54 4195.77 1799.19 -3832.10 4233.45 295.15 6957.16 4265.07 1827.74 -3895.76 4303.21 295.13 7021.37 4334.11 1855.83 -3959.30 4372.66 295.11 7083.37 4400.98 1883.15 -4020.80 4439.94 295.10 7146.71 4469.54 1911.62 -4083.71 4508.99 295.08 Dog Leg Severity (deg/tff) 0.42 0.34 0.48 0.28 0.51 0.29 0.55 0.93 0.71 0.15 0.24 0.10 0.38 1.65 0.46 0.45 0.56 0.91 0.60 0.28 0.15 0.13 1.93 0.08 0.72 0.99 0.27 O.92 1.49 0.73 0.41 0.44 2.26 1.05 0.85 1.27 0.27 0.23 0.45 0.24 Anadrill Schlumberger Page 3 3/17/98 Measured Station Station Station Vertical Vertical Depth Inclination Azimuth Interval Depth Section (fi) (deg) (deg) (ft) (f~) (tl) 9104.2 47.52 294.5 87.40 7205.74 4533.51 9200.0 47.60 295.2 95.80 7270.39 4603.62 9294.3 47.46 294.6 94.30 7334.06 4672.60 9391.1 47.28 295.5 96.80 7399.62 4743.20 9485.3 46.97 294.5 94.20 7463.72 4811.64 9579.5 46.58 294.9 94.20 7528.23 4879.74 9672.3 46.26 295.2 92.80 7592.20 4946.39 9768.9 45.93 296.3 96.60 7659.19 5015.28 9866.6 45.49 296.0 97.70 7727.42 5084.42 9960.7 46.06 295.0 94.10 7793.05 5151.19 Latitude (N/-S) (ft) 1938.34 1968.05 1997.34 2027.49 2056.67 Departure Displac merit (E/-W) at Azimuth (fi) (ft) (deg) -4142.36 -4206.51 -4269.60 -4334.12 -4396.68 4573.43 295.08 4644.13 295.07 4713.69 295.07 4784.90 295.07 4853.94 295.07 2085.35 -4459.04 4922.58 295.06 2113.76 -4519.97 4989.80 295.06 2143.94 -4582.68 5059.39 295.07 2174.76 -4645.46 5129.32 295.09 2203.79 -4706.32 5196.75 295.09 10054.0 45.89 295.1 93.30 7857.89 5217.70 2232.19 -4767.10 5263.83 295.09 10145.3 46.50 293.4 91.30 7921.09 5283.13 2259.25 -4827.17 5329.71 295.08 10235.3 47.08 291.6 89.90 7982.65 5348.40 2284.32 -4887.71 5395.16 295.05 10333.7 48.43 290.8 98.40 8048.80 5421.08 2310.65 -4955,62 5467.84 295.00 10424.4 49.91 289.9 90.80 8108.17 5489.70 2334.54 -5020.03 5536.32 294.94 10519.5 50.86 289.3 95.10 8168.80 5562.91 10612.7 51.06 289.4 93.20 8227.51 5635.26 10708.0 52.92 288.2 95.30 8286.19 5710.32 10805.7 55.23 287.7 97.70 8343.51 5789.43 10895.7 56.13 285.3 90.00 8394.26 5863.74 10988.2 58.75 283.5 92.50 8444.04 5941.58 11086.2 61.03 281.9 98.00 8493.20 6026.04 -11157.2 62.62 281.8 71.00 8526.72 6088.33 Pr~ected Survey out ofshoe with good Inc. and Depth (1 11216.3 63.49 281.7 59.10 8553.50 6140.74 2359.11 2383.10 2407.28 2431.66 2452.76 -5089.05 -5157.35 -5228.43 -5303.69 -5374.95 5609.26 294.87 5681.32 294.80 5755.99 294.72 5834.56 294.63 5908.14 294.53 2472.13 -5450.46 5984.89 294.40 2490.75-5533.15 6067.92 294.23 2503.60 -5594.40 6129.06 294.11 216.3) 2514.33-5645.98 6180.53 294.00 -5721.00 -5740.29 -5773.98 -5797.36 -5852.37 11302.6 61.68 281.7 86.30 8593.24 6216.96 11325.2 60.08 282.9 22.60 8604.24 6236.62 11365.9 57.34 284.6 40.60 8625.32 6271.23 11394.7 56.50 285.6 28.90 8641.09 6295.43 11462.7 57.54 285.1 68.00 8678.11 6352.43 11556.6 60.16 285.8 93.90 8726.68 6432.73 11648.7 62.46 285.9 92.10 8770.89 6513.48 11742.7 63.35 284.5 94.00 8813.71 6597.10 11838.7 63.83 282.7 96.00 8856.41 6682.87 11928.5 63.50 283.6 89.80 8896.25 6763.12 2529.87 2534.07 2542.31 2548.61 2563.71 6255.40 293.86 6274.74 293.82 6308.90 293.76 6332.84 293.73 6389.28 293.66 12027.5 63.92 283.9 99.00 8940.10 6851.69 12115.8 64.93 284.6 88.30 8978.21 6931.21 12209.8 66.05 284.4 94.00 9017.21 7016.62 12306.3 67.80 285.4 96.50 9055.03 7105.30 12398.5 69.59 285.6 92.10 9088.49 7191.05 2585.13 -5929.82 6468.82 293.56 2607.19 -6007.53 6548.89 293.46 2629.13 -6088.29 6631.71 293.36 2649.34 -6171.85 6716.46 293.23 2667.65 -6250.22 6795.71 293.11 2688.75 -6336.44 6883.30 292.99 2708.35 -6413.63 6962.03 292.89 2729.77 -6496.44 7046.65 292.79 2752.60 -6582.23 7134.60 292.69 2775.53 -6664.91 7219.73 292.61 Dog Leg Severity (deg/la) 0.02 0.55 0.49 0.71 0.84 0.52 0.38 0.96 0.50 0.97 0.20 1.50 1.60 1.50 1.79 1.11 0.23 2.19 2.40 2.42 3.27 2.72 2.24 1.48 2.10 8.46 7.64 4,11 1.65 2.86 2.50 1.63 1.75 0.97 0.50 1.35 1.21 2.05 1.95 Anadrill Schlumberger Page 4 3/17/98 Measured Station Station Station Vertical Vertical Latitude Departure Displac ment Dog Leg Depth Inclination Azimuth Interval Depth Section (N/-S) (E/-W) at Azimuth Severity (fl) (deg) (deg) (fi) (fi) (fl) (fl) (fi) (fi) (deg) (deg/h0 12486.8 70.75 289.0 88.40 9118.49 7274.19 2800.26 -6744.28 7302.52 292.55 3.85 12582.6 72.13 293.0 95.80 9148.99 7364.82 2832.81 -6829.04 7393.28 292.53 4.21 12656.7 72.24 299.6 74.10 9171.68 7434.49 2864.05 -6892.25 7463.63 292.57 8.48 12702.1 69.32 300.5 45.40 9186.63 7476.33 2885.51 -6929.35 7506.13 292.61 6.70 12770.5 66.68 298.7 68.40 9212.25 7538.33 2916.84-6984.48 7569.08 292.67 4.57 12794.8 65.67 298.4 24.30 9222.07 7560.14 2927.46 -7004.01 7591.19 292.68 4.31 12869.5 64.89 296.8 74.70 9253.31 7626.94 2958.90-7064.13 7658.79 292.73 2.21 12961.3 63.53 294.1 91.80 9293.25 7708.79 2994.43-7138.75 7741.34 292.76 3.03 13037.0 64.39 294.3 75.70 9326.48 7776.34 3022.31 -7200.79 7809.34 292.77 1.16 13058.4 64.47 295.1 21.40 9335.72 7795.49 3030.37-7218.33 7828.63 292.77 3.39 13150.7 63.86 295.1 92.30 9375.94 7877.84 3065.61 -7293.56 7911.u,+ -'a-'.ou 0.66 13247.0 64.00 295.1 96.30 9418.26 7963.58 3102.31 -7371.89 7998.07 292.82 0.15 13341.5 64.33 295.0 94.40 9459.40 8047.81 3138.28 -7448.87 8082.97 292.85 0.36 13435.8 64.60 294.8 94.40 9500.09 8132.28 3174.15 -7526.13 8168.09 292.87 0.34 13525.2 64.70 294.3 63.90 9538.38 8212.42 3207.93 -7599.51 8248.84 292.89 ! '-"."'-'--' 13623.7 64.34 294.5 98.50 9580.76 8300.70 3244.66 -7680.48 8337.73 292.90 0.41 13715.3 63.56 294.6 91.60 9620.98 8382.37 3278.85 -~'~.34 -84i~ 13804.4 6-3.12 294.3 89.10 9660.96 8461.41 3311.81 -7827.83 8499.59 292.93 0.58 13905.2 62.36 294.7 100.80 9707.13 8550.35 3348.97-7909.36 8589.16 292.95 0.83 13996.0 62.01 295.1 90.80 9749.20 8630.24 3381.99-7982.72 8669.58 292.96 0.55 14094.2 61.19 294.9 98.10 9795.86 8715.79 3418.46 -8060.-2'-3 ~,-~:~ ~9 9-'--'_9 '-_'_~. '!4185.2 ~_.;_~?_.~.295.3 91.!0 9840.13 8794.71 3452.23 -8133.03 8835.39 293.00 0.71 14281.2 60.11 295.8 95.90 9887.53 8877.26 3488.19 -8208.24 891~.~; ?~:--~- ~' i4374.8 59.7i 295.8 93.70 9934.57 8957.48 3523.47 -8281.23 8999.65 293.05 0.43 14469.9 59.44 295.5 95.00 9982.62 9038.57 3558.93 -8355.08 9081.48 293.07 0.39 !~.~.~ 58.78 296.! 93.80 10030.78 9118.22 3593.96 -8427.55 9161.89 293.10 0.89 14633.0 58.17 296.6 69.40 10067.06 9176.67 ~uzu.22 _~,a ...... ^.~,~,, ..... ~.--, .......... 9~.~ -~9 ~ ~7 Projected Survey at TD 14696.0 58.17 296.6 63.10 10100.34 9229.6i 3E,4.~.-.,,2 -~,-->;: ~,au-::~._~.6 zu'&i~ 0.0:2 Anadrill Schlumberger Page 5 3/17/98 Date: 15-Mar-98 Well Name: L1-31 Company: ARCO Alaska Inc. API Number: 5002922860 Location: North Slope, Alaska Field: Lisburne Rig: Pool Arctic Alaska #7 Anadrill Personnel Field Crew: Cell Managers: Cell Engineers: LWD Engineers: Michael Dammeyer Nat_han Rose Ray Whitmm Dan Guay Mark St. Amour Field Support: Alaska District Manager: Martin Varco Field Service Manager: Craig Brown SERVICES PROVIDED Service Dir~tional Survey Service (DSS) DWOB/DTOR (IWOB) Gamma Ray (GR) Compensated Dual Resistivity (CDR) Resistivity at the Bit/Imaging(RAB) Service Dates 06 Feb-98 - 15 Mar-98 10 Feb-98 - 15 Mar-98 06 Feb-98 - 15 Feb-98 15 Feb-98 - 22 Feb-98 01 Mar-98 -15 Mar-98 23 Feb-98 - 27 Feb-98 Depth lnterv~ 120' -14696' 5142' -14696' 120' - 7468' 7468' -11248' 12093' -14696' 11248' -11962' OPERATING STATISTICS Total MWD Pumping Hours: Total MWD Below Rotary Hours: Total MWD Footage: Total MWD Runs: Total LWD Pumping Hours: Total LWD Below Rotary Hours: Total LWD Footage CDR: RAB: Total LWD Runs: CDR: RAB: 551.5 791.9 14576.0 12 432.5 686.8 6383.0 714.0 7 2 JOB PERFORMANCE DIRECTIONAL Surveys (DSS) were provided over the entire well. Real-time inclination and azimuth readings were ~nonitored during kickoff and sliding intervals throughout the well. The final survey point was at 14633.0' with an inclination of 58.17 degrees and an azimuth of 296.6 degrees. This survey was projected to TD, giving the final bottom hole location: Measured Depth: 14696.00' True Vertical Depth: 10100.34' Latitude: 3644.22 N Departure: 8528.50 W Displacement at Azimuth: 9274.46' at 293.14 deg FORMATION EVALUATION Real-time GR was used for lithology identification; ~cally, to pick casing points for the surface and intermediate hole sections. M10 GR, CDR, and RAB tools were used at different times over the entire well. Real-time logs, DLIS files and ASCII data were faxed/mailed in a timely manner, and the dumped memory data was provided within hours after the tool was above the rotary table. DRILLING MECHANICS DWOB and DTOR were provided from surface casing down. The downhole measurements were monitored by the driller on the rig floor, as well as the Anadrill engineer on location DTOR was used to spot locking cones and bit condition. Engineering logs were faxed daily to the drilling engineer, with mud properties and lithology indicators. SHOCK Shock is monitored in the MWD, CDR, and RAB tools. It remained low most of the well; however, large shocks were monitored when the RAB tool failed. WASHOUT DETECTION Washouts can be seen from MWD turbine rpm, pump pressure, and flow. There were no washouts on L1-31. LESSONS LEARNED Always ensure the directional driller knows where the scribe line is on the mud motor. On ~_hi.q well, a Baker motor was run, and tool face was measured using the wrong scribe line. This caused several large dog legs. Overall, L1-31 went well. Anadrill appreciates the opportunity to provide ARCO Alaska, Inc. and Shared Services Drilling with MWD and LWD services. Sincerely, Craig Brown Field Service Manager Michael Dammeyer Field Cell Manager 9/3O/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11997 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Lisburne LIS Color Well Job # Log Description Date BI_ RF Sepia Tape Print L1-31 ~ '~?~.,~'~ 98177 USIT 980326 I 1 L1-31 98164 ICNT,AIT,SDN,DAS,FMI,MWD 980317 1 L1-31 98164 PEX-AIT 980317 I 1 L1-31 98164 PEX-DENS/NEUTRON 980317 I 1 L1-31 98164 PEX-NGT 980317 I 1 L1-31 98164 DSI/SONIC 980317 I 1 L1-31 98164 FMI 980317 1 1 L1-31 98164 RFT 980317 I 1 L1-31 98164 PEX-SSTVD 980317 I 1 L1-31 98164 CDR/RAB 980312 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. MEMORANDUM ~Alaska Oil TO: David JohnsOn, Chairman State of Alaska and Gas Conservation Commission DATE: February 12, 1998 THRU: Blair wondzell, P. I. Supervisor FROM: Lou Grimal ,c~,,.~ SUBJECT: Petroleum InCpector FILE NO: ADIJBKFE.DOC BOP Test, Pool #7 Arco, L 1-31 Lisburne Field PTD #98-OO 15 Wednesday, February 11, 1998; I witnessed the initial BOP test on Pool rig #7 drilling Arco well L1-31 in the Lisburne Field. I arrived to find the rig about ready to test but still hooking up the panic lines. I made a cursory tour of the rig and its surrounding area and found all to be in good shape. The test, once started went fairly well with all BOPE being tested with no failures observed. The gas detectors were tested and although all worked properly the methane detector on the rig floor needed a slight span adjustment. The rig crew did a good job testing the BOPE and I found David Guest (Driller) to be intent on performing a good test. The rig was in fair shape, showing evidence of regular maintenance and was situated to allow for easy access. SUMMARY: The initial BOPE test I witnessed on Pool rig #7 went well with no failures observed. 4 ½ test hours, NoFailure.. Attachments: ADIJBKFE.XLS CC; Dan Stoltz (Arco Drilling) NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: I nitia X Workover: Pool Rig No. Arco Alaska L 1--31 Set @ Weekly Other DATE: 7 PTD # 98-0015 Rig Ph.# 659-4815 Rep.: Les Peak Rig Rep.: John West Location: Sec. I T. 11N R. 14E Meridian 2/11/98 MISC. INSPECTIONS: Location Gen.: P Housekeeping: P (Gen) PTD On Location P Standing Order Posted P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Well Sign P Drl. Rig P Hazard Sec. P Quan. Test Press. P/F 1 250/2500 P I 250/5,000 P I 250/5,000 P f 250/5,000 P I 250/5,000 P 2 250/5,000 P 1 250/5,000 P N/A 250/5,000 N/A MUD SYSTEM: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P* P H2S Gas Detector P P FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 250/5,000 P 250/5,000 P 250/5, 000 P 250/5, 000 P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 250/5,000 P 38 250/5, 000 P 1 P Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained 3 Blind Switch Covers: Master: Nitgn. Btl's: 6 Bottles 2000 Average 3,000 I P 1,450 P minutes 40 sec. minutes 18 sec. Remote: Psig. Number of Failures: 0 ,Test Time: 4.5 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within N/A days. otify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS' worked good. "Good Test" Methane detector on rig floor needed span adjustment. Performed during test. Afl other equipment Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES Yes NO 24 HOUR NOTICE GIVEN YES Yes NO Waived By: Witnessed By: Louis R. Grimaldi F 1-021L (Rev. 12/94) Adljbkfe.xls TONY KNOWLE$, GOVERNOR AL&SKA OIL AND GAS CONSERVATI ON COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 4. 1998 Steve Shultz Engineering Supervisor ARCO Alaska. Inc. POBox 196612 Anchorage, AK 99519-6612 Rc~ Lisburne L 1-31 ARCO Alaska. Inc. Permit No: 98-0015 Sur. Loc.' 3080'NSL. 2755'WEL. Sec. 1. T11N. R14E. UM Btmholc Loc: 585'NSL. 1061'WEL. Sec. 34. T12N. R14E. UM Dear Shultz: Enclosed is thc approved application for permit to drill thc above referenced well. Thc permit to drill docs not cxcmpt you from obtaining additional permits rcquircd bx' law from other governmental agcncics, and docs not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Blowout prevention equipment (BOPE) must bc tcstcd in accordance v~'ith 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoc nmst be given so that a representative of thc Commission may witness thc test. Notice ma,,' be given bx' contacting thc Commission petroleum field inspector on thc North Slope pager at 659-3607. Chairman '~..~ _ BY ORDER OF TH OMMISSION dlf/ench)sures cc: Department o1' Fish & Game. t labilat Section w. o encl. Department of I~,m'ironmcntal Conservation w,o encl. STATE OF ALASKA ALA,::KA OIL AND GAS CONSERVATION~OMMISSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil; l']Re-Entry I-'lDeepenI []Service FI Development Gas I--I Single Zone FI Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan RTE = 53.7' Lisburne 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028300 ~ 4. Location of well at surface 7. Unit or Property Name !11. Type Bond (See 20 AAC 25.025) 3080' NSL, 2755' WEL, SEC. 1, T11N, R14E, UM Lisburne At top of productive interval 8. Well Number Number U-630610 313' NSL, 3347' WEL, SEC. 35, T12N, R14E, UM L1-31 At total depth 9. Approximate spud date Amount $200,000.00 585' NSL, 1061' WEL, SEC. 34, T12N, R14E, UM 02/05/98 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028303, 585'I No Close Approach 2560 14826' MD / 10175' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} KickOff Depth 1800' MD Maximum HoleAngle 48° Maximum surface 3465 psig, At total depth (TVD) 9350'/4400 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD 'F'VD MD TVD (include stage data) 30" 20" 133# H-40 BTC 80' 30' 30' 110' 110' 260 sx Arctic Set (Approx.) 16" 13-3/8" 68# , L-80 BTC-Mod 5133' 29' 29' 5162' 4553' 3225 sx PF 'E', 500 sx Class 'G' 12-1/4" 9-5/8" 40#~,'1; L-80 BTC-Mod 11295' 28' 28' 11323' 8593' 1000 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-Mod 3726' 11100' 8470' 14826' 10175' 320 sx Class 'G' 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 M D TVD Structural Conductor Surface I;~oerdr~cet?ioante R E C E i V E D Liner JAN 2 7 .!998 Perforation measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Brent Reeves, 564-5376 Prepared By Name/Number: Kathy Carnpoarnor, 564-5122 21. I hereby certify that the foregoing ~rrect to the best of my knowledgeSigned ~ //2 Steve Shultz _ , Title En~lineering Supervisor Date %' Commission Use Only Permit Number APl Number I Appro~va_.l Dat_e I See cover letter 4;{(~- 0 0/~' 50- ~ 2- C~ _ ,3,. ~ ~ ~ O ~ - ~7/ ~- ~ for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes []No Hydrogen Sulfide Measures l~Yes []No Directional Survey Required I~Yes []No Required Working Pressure for DOPE []2M; []3M; J~]5M; []10M; []15M Other: d~'iglrlai blgrl'30 IriS/ by order of Approved By David W. dohnst0n Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate 01/26/98 [Well Name: I L1-31 I Type of Well (producer or injector): I Producer Surface Location: 3080' FSL, 2755' FEL, SEC 1, T1 iN, R14E Target Location: 313' FSL, 3347' FEL, SEC 35, T12N, R14E Bottom Hole Location: 585' FSL, 1061' FEL, SEC 34, T12N, R14E I AFE Number: ] 2A0039 Rig: [ POOL 7 I Estimated Start Date: 1 2/5/98I I Days to complete 13s + 6 I MD: 114826' [TVD: 110175, brt [ I RTE: 153.7 IWell Design (conventional, slimhole, etc.): Conventional Big Bore Formation Markers: Formation Tops MD TVD Base of Permafrost 1753 1753 SV4 (T8) 3440 3354 SV3 (TS) 3969 3749 SV1 (T3) 4761 4284 13 3/8" Casing Point 5162 4553 13 3/8" csg shoe below SV1 & above K-15 K15 (Ugnu) 5451 4750 West Sak 6792 5653 K- 12 7711 6273 Sag River 10246 7984 Ivishak 10400 8083 Kavik 11174 8523 9 5/8" Casing Point 11323 8593 9-5/8" casing shoe Wahoo Z6 (top) 11456 8653 Wahoo Z5 11665 8747 ECP between Z4 and Z5 Wahoo Z4 11848 8830 Green Shale 12928 9317 ECP in Green Shale Alapah (E) 13062 9377 Base Alapah (B) 14826 10175 7" Liner Point/TD 14826 10175 7" liner shoe Casinq/Tubinq Program: Hole Size Csg/Tbg WffFt Grade Colin Length Top Btm O.D. MDfrVD MD/TVD 30" 20" 133# H40 BTC 80' 30/30' 110'/110' 16" 13 3/8" 68# L-80 BTC-Mod 5133' 29/29' 5162'/4553' 12-1/4" 9-5/8" 40# L-80 BTC-Mod 11295' 28/28' 11323'/8593' 8-1/2" 7" 26# L-80 BTC-Mod 3736' 11100'/8470' 14826'/10175' Tubing 3 V~" 9.3# L-80 BTC-Mod 11100' 26'/26' 11000'/8420' O1/26/98Revised 01/26/98 = Mud Program: Surface Mud Properties: Spud Density (ppg) ~unnel Vis I Yield Point 8.6-9.4 70 -120I 20-50 I 16" Hole to 5162' Fluid Loss 10 sec gel Ilo min gel 15 - 25 I 20 - 40 pH 9.0 - 9.5 10 -6cc Intermediate Mud Properties: LSND I 12-1/4" hole to 11323' Density (ppg) Plastic Vis Yield Point 10 sec gel 10 min gel 9.0- 10.2 40- 55 15 - 30 8 - 12 12- 20 I pH Fluid Loss 8.5 - 9.0 < 5cc Production Mud Properties: 3% KCL Density (ppg) Plastic Vis Yield Point 10.0- 10.6 8-15 15-25 8-1/2" sidetrack to TD 10 sec gel 10 min gel I 8-15 12-24 I pH [ HTHP 9.0-9.5 4-6cc O1/26/98Revised 01/26/98 Cement Data: Casing First Stage: Second Stage: Comments Sxs/Wt/Yield Sxs/Wt/Yield 13-3/8" Permafrost "E": 2525/12.0/2.17 Two stage job: surface casing 700/12.0/2.17 (assumes 300% First stage Permafrost "E" lead from to 5162'. excess in 2000'-4400' @ 50% excess followed ES cementer Class G: permafrost and by Class G tail from shoe to 4400' @ at 2000' 500/15.8/1.15 casing capacity to (750' MD column) @ 50% excess + MD. stage collar) 80' shoe. Second stage Permafrost "E" circulated to surface. 9-5/8" Class G: NA Cement volume based on 750' MD intermediate 1000/15.8/1.15 above Sag River plus 100% excess. casing to 11323' MD 7" Class G: Class G: First stage based on cementing 320/15.8/1.15 125/15.8/1.15 Alapah to 13000' with 50% excess. Second stage based on covering W5, W6 and liner lap with 50% excess. Logging Program: Open Hole Logs: ICased Hole Logs: NA 8 V2" MWD DIR to K-12 8 V2" LWD DIR/GR/RES/DEN/NEU from K-12 to TD. Log tops (GR/RES) on trip in hole. 8 V2" DPC-RFT and FMI (2 runs probable). LWD MAD pass on wiper trip GR/CET or USIT (May be requested prior to running tubing). Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: KOP: Maximum Hole Angle: Close Approach Well: 1800' MD and 10219' MD 48 o 63 o NA O1/26/98Revised 01/26/98 ' ~ ~ Drilling and Completion Scope 1. Move rig to L1-31. NU diverter, riser and towlines. Notify AOGCC 24 hours in advance to allow witnessing of diverter test. Directionally drill 16" surface hole to -5162' MD. Run and cement 13 3/8" casing w/2 stage job. Cement to surface. ND diverter and NU BOPE. Notify AOGCC 24 hours in advance to allow witnessing of BOP test. Drill 12-1/4" intermediate hole with LWD/MWD into Kavik at 11323' MD for 9-5/8" casing point.. Run and cement 9-5/8" L-80 casing. Drill 8-1/2" production hole through Lisbume to -14826' MD. Log well with DPC RFT and FMI. Run and cement 7" L-80 solid liner with ECPs. Plan is to cement Alapah and Upper Wahoo leaving lower Wahoo uncemented behind pipe. 10. Run cased hole logs as directed. 11. Run 3-1/2" L-80 production tubing with 7"x 3-1/2" packer, 3-1/2" SSSV, and 3-1/2"x 1-1/2" GLMs. 12. Secure well, RDMO. . 7. 8. 9. Drilling Hazards/Contingencies · H2S is produced in offset wells. L1 pad is not designated as an H2S pad. · Wellbore will penetrate Ivishak gas cap. BHP may be 3700 psi @ 8072' TVD (8.8 ppg EMW). · Some Ivishak light oil column may be present as well. · Lost circulation is possible in top of Lisburne due to production depletion. Upper Wahoo 3700 psi @ 8640' TVD (8.2 ppg EMW) · Lower Lisburne intervals may be near original reservoir pressure. Lower Wahoo 3900 psi @ 8800' TVD (8.5 ppg EMW) Alapah E 4400 psi @ 9350' TVD (9.1 ppg EMW) · Due to gas bearing strata, the potential of gas cut mud is very real. Wellbore must be closely observed for any flow and hole fill while tripping must be closely monitored. Disposal · Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to CC-2A for injection. Haul all Class I wastes to Pad 3 for disposal. In addition, haul all cuttings from drilling operations to CC- 2A for disposal, except any metal cuttings which will be sent to the North Slope Borough. TBR OI/26/98Revised SHARED SE ZCES-DRILLING ~ ~iiiiii i i I ~,?i Li-31 (P5) : <KB> 0 I' I ! VERTICAL SECTION VIEW ; 750-= .~ , Section at: 287.47 , i ~ TVD Sca]e' ~ inch : ~500 feet I I Oep Scale ' 1 inch : ~500 feet 1500 ....... ! Drawn ' 22 dan ~g98 ' .... B-: = .... ~ ................ ~,-~L~ ~t - ~ : 2250-~ i ......... ~ '~ /nadri ]l Sch].u~berger ........ J,, Marker Identification MD 8K8 SECTN INCL~ , ----t~-,s~,r-~l 8] KOP BUILD 11100 1800 18oo -o o.oq ' C] BUILD 1.~/t00 2000 2000 3 2.0~ 3750 ' ~ '.~m ~z~ D) BUILD 2/t00 2200 2200 ~6 5,00 ~ EJ BUILD 2,5/t00 8400 2398 40 9,oq " FJ END 2.5/100 BUILD 3943 3731 75~ 47.5~ 33~f~Ts~--~ ................. G) J3-3/8" CSG PT <11 > 5t62 a554 J6a3 a7,5~ V4500 ~~~ HI CURVE ~/100 ,0200 7g53 5329 ~7.5~ O ~,~q~-~ ............. ~1 9-5/a" cs~ PT <11> ~1324 8~94 624~ 63.~ J) END 2/t00 CURVE ~i324 8594 624~ . 53,~ K) TARGET ~*~*****~ 1~457 86~4 5250- L) TARGET ,~,~**~,~*~ t4827 i0~75 9298 63, ~si sA~ ~e~ M) TO / 7" CSG PT <Ii> 14827 10175 9296 63, 6000 ] i.-- '~'~-~r -~ ' ' ~ ..... ----- ..... ~ ........ I ; 6750-- - ....... J I I 7500 ............. ....................... - .... ...... ............ go00 -, ~ i -- 9750- - ~~... L~ ~o5oo ~.~_ .. =;= ........................ ~ I ~ A~ADRILL AK.z~.DPC j ,: ~ - ,~ooo ....... , - I ~N' ~" ........~_ ~2750 .......... i - i 135oo [ ..... 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 go00 s~c t i o E,,gg~ ~,~ tune 9750 36~ 600 SHARED SERVTCE'S DR]]LL.NG' II I I II iiii ii _ · I I J III · j lll·l m i i I I . iiiii . AnadrJ ] ] Schlumberger .. iiii ii Il II I I III II _r ! I i L (P5) PLAN VIEW II iii I iii I I CLOSURE ' 9296 feet at Azimuth 287,47 ~ I .... ' I DECLINATfON.: +28.402 [E) ISCALE ....... : ~ inch: 1200 feet i F- .......... "'~ ................ ~'- ............... " .,.~ .... ~ .... IDRAWN ....... : 22 Jan ~998 . · -' A,i',IADRIL. .~'J< " '"""~" I '"': ' L -" -' ''-. .~ ~' ilium I I _ I I- - ' Ma r~(en I dent i ficat i o~ ill N/S E/lC · , ,;~ ,~.~ A) ~<B 0 0 N 0 E ;~ ~ ~ ,,],- 8) KOP BUILD 1/]00 tBO0 0 N 0 E ,.¢, , ... C) BUILO ~.5/100 2000 ! N _R I~ . , - ....................... END 2.5/100 BE[LO 3943 ~ N 686 H ......................................................... r.l i3-3/8' CS6 PI <11> 5~62 703 N ~50i ~ . ,. ~] 6L¢IVE 2/t00 i0200 2280 l~ 4869 !~ r) 9-5/8' CS6 P~ <11> lJ~24 Z505 N 5755, J) END 2/i00 CURVE J1324 2505 ~f 5755 ~/ ..... L) TARBET ,mmxx~,,~,~ ~4B27 279i N 6867 H M) TD / 7" 6~ PT <11> i4827 279i N BB67 H ~~ ~~~~ T~e( Point) m ~k II , " " . I .... .. .. , , I , .... .................. [~.' ................. -.-~ ....... ~ ...................... ...... , ................ I .............. ' ................... . ..... ·, ~..u z a m~,~ ~ -~lSg ~¢111 fl C~I ..................................... <- HESf' EASf-> I ii II III · . I ii I I · ii 3> Z Auadrtll Schlu~berser Alaska Bistr~ct 1111 East 80th Avenua Anchorage, AK 99518 349-451[ F~x 344-2160 DIRECTIONAL HELL PLAN for SHARED SERVICES DRILLING well ......... : 11-31 Field ........ : Lisbur~e, L1-Pad Computat£o~..: Minimum Curvature Units ........ : FEET Eurfaee Lat..: 70,33762910 N Surfaca Legal Description Surface ...... : 3079 FSL 2755 Target ....... : 313 FSL 3347 8HL .......... : 585 FSL 1061 LOCATIONS - A~SKA ZoRe: 4 X-Coord Y-Coord 901 TI1N R14E UM 68863~.O2 59~5432.85 S35 T12N R14~ UM 682700.00 S34 T12N RI4E UM 679700.00 5978000.00 PROPOSED WEL~ PROFILE STATION ~ASUI{ED I~CL~ 1 ~ENT I FICAT~ON DEPTH AN~LE KB 0.00 0.00 BASE PERMAFI~0ST I753.70 0.00 ~P BUlbD 1/~00 1800.0~ 0.00 L900.00 1.00 ~UI~ 3.5/~00 2000.00 2.00 DIRECTION %~ERTICA3~-DEPTHS AZIMUTH TVD SI/B-SEA 0.00 0.00 -53.70 0.00 ~753.70 1700.00 215.10 ~800.00 k7~6.30 295.10 1899.99 1846.29 295.10 1999,96 1946.26 SSCTION ,DEPART 0-0O 0.00 -0.00 0.86 3.46 ~repared ..... : 22 Jan 1998 Vert aect az,: 287.47 KB elevation.: 5~.90 ft Magnetic Dcln: +28.~02 (E} Scale Factor.: 0.999940~2 Convergence..: +l.~%145553 ANADRILL AKA-DPC APPROVED FOR P£RMI'T'T!NG ONLY PLAN # COORDINATES-FROM ALASKA Zome 4, WELL~IKAD X Y 0.00 N 0.00 0.00 N 0.aa 0.00 N' 0.0O 0.37 lq' 0.79 1.48 N 3.16 688634.02 5975~32.65 688634-02 S975~32.65 688634.02 5975&32.85 688633.22 5975433.20 688630.82 5975434 25 TOOL FACE 651 65?. 655 655 651 100 :mm, m m mm O.D0 0 -00 0.00 1. OO 1. OO BUILD 2.5/100 2100.00 3.S0 295.10 2099.84 2046.1i 8,21 3.52 2200.00 5.00 295.10 2199.56 2145.86 35.56 6.66 2300.00 ~.00 295.10 2299.01 2245.31 25.92 11.09 2400.00 9.00 295.~0 2398.03 2344.3~ 5~.71 16.99 2500-00 1~.50 295.10 2496.~3 2442.7~ 57.3~ 24.$4 7.51 W 688626.43 5975436 18 14.22 ~ 688619.64 597543~ 15 23.68 ~ 688610.07 5975443 34 36.29 W 688~97.32 5~75448 93 52.40 W 688581,02 5975456.06 6St 1.~O 651 1.$0 HS 2,00 HS 2.00 HS 2.50 ]> Z ]> 2600.00 14.00 295.~0 2593.96 2540.26 79.22 33.90 N 92.38 W 688560.81 5975464~92 KS 2.50 2700.00 16.50 295.10 2690.43 2636.73 105.29 45.06. N 96.20 W 688536.72 5975475.~7 HS 2.90 2~ Jan 3998 Page 2 PROPOSED WBLL PROFILE STAT[ON [DKNTIFICATION MEASURED INCLN DIRECTION V~RT~CAG-DBPT~S EECTION DEPTH ANGLE AZIMI~T~ TVD SUB-SEA DEPART 2800.00 19.00 295.~0 2785.66 2731.96 2900.00 21.50 295-~0 2879.47 2825.77 169.8L 3000.00 2~.00 295.10 297~.68 2917.98 208.13 3~00.00 26.50 295.10 3062.[2 3008.42 250.~1 3200.00 29.00 295.~0 3150.61 3096.9L 296.56 CkDORDINATES-FROM ALASKA Zone 4 TOOL DL/ ~ELLHEA~ X Y FACE 100 $?.99 N 123,8~ W 6~8508.80 5975~87,70 KS 2.50 72.66 N 155.15 W 6854~7.10 5975501,58 HS 2.5~ 89.06 N 190,17 W 688441.68 5975517.10 KS 2.5~ 107.16 N 228,79 W 688402.62 59~553%.21 }tS 2.58 126.90 N 250.96 W 688359-97 5975552,89 ~S 2.50 78 (SV4) 3300.00 3L.50 295.10 3236.99 3183.29 3/6-49 3400.00 34.00 29S.10 3321.09 3265.39 400.LO 3439.57 34,99 295.10 3353.~0 3300.00 t22.31 3500.00 36,50 295.~0 3402.7~ 3349.04 457,30 3600.00 39.00 295.10 3481.8L 3~25-L1 S17.98 1{8.27 N 3L6.57 ~ 688313.83 5975573.10 aS 2.50 172.2L N 365.SG W 688264.29 597559~.80 HS 2.50 [B0,71 N 385.86 W 6882~3.76 5975603.79 HS 2.50 L95.69 N 417.82 W 688211.43 59756L7.95 HS ~.S0 221.6~ N 473.26 W 658155,36 597~642.5~ ~ 2.50 75 (EV3) 3700.00 4L.S0 295.L0 3558-L2 3504.42 582.01 3800.00 44-00 295.10 3631.55 3577.85 649.29 3900,0~ 46.50 295.L0 3701.95 3648.25 719.67 3942.88 47.57 295.10 3731.17 3677.~7 750.78 3968.86 47.57 295.10 3748.70 3695.00 769.78 73 {TT6/SVL) %76L.85 47.57 295.10 4283.70 ~230.00 ,13&9.94 13-3/8" CSG PT <11> 5162.05 47.57 295.10 4553.70 ~500.00 L642.72 UG~A (K-[S) 5451.08 47.57 29~.L0 4748.70 ¢695.00 L$5~.18 WEST SAK 6792.50 47.57 29~.L0 5653.70 5600.00 2835.56 C~[3 (K-12) 7711.%7 4?.57 295,L0 62~3,70 6220,~0 3507.89 249.05 N 531,77 W 688096.19 5975668.43 KS 2.50 277.$& N 593.24 W 688034.02 597569~.66 HS 2.50 307.96 N 657.55 W 687968.97 5975724,15 }IS 2,50 321.27 N 685.96 ~ 6879~0.23 5975736.74 ~S 2.50 329.40 N 703.33 ~ 687922.67 59757~4.~4 ~S 0.00 577.66 N 3233.40 W 687386.55 S975979-27 HS 0.00 702.95 N 1500.9[ W 687~15.99 5976097.78 H~ 0.00 793.&6 N ~694.12 W 6869~0.$~ 59761~3.37 H~ 0.00 ~2~3.39 N 2590.78 W 6860L3-70 5976580.6L Hg 0.00 1501.09 N 3205.07 W 685392.&0 5976852.75 KS 0.00 CURVE 2/100 10200-%8 47.57 295.10 7952.94 7599.24 5328.86 2280,3L N 4868-83 SAG RrVER SAND ~0246.32 ~8.1~ 294.12 7983.70 7930.00 S362.58 229~.46 N 4899.73 L0300.00 48-81 293.00 $0L9.29 7965.59 5402.$4 ~3~0.52 N 4936.ST IV[SKAK SA~D L0399,05 50.07 290.99 8083.70 8030.00 5477.54 2338-69 N 5006,33 1040~,00 50,08 290.97 8084,3L 8030.6L 5478.27 2338.95 N 5007.0~ 683709.66 S977589.83 52L 0.00 683678.42 5977603.19 525 2.00 6836{1./9 59776[8.32 5LL 2.00 653570,75 5977644.72 50L 2.00 683570.06 5977644.97 SOL 2.00 10SO0.O0 51.39 289,02 8147.60 8093.90 5555.61 2365.4L lq 5079.77 W 683496.67 5977669,$9 ~8~, 2.00 10600.00 52.73 287.14 8209.09 8L55.39 5634.47 2389.$? N 5L54.74 ~ 68342L.11 5977692.16 4~L 2.00 L0700.O0 5~-10 285-33 8268.68 82L~.98 5714.74 24L2.3L 1{ 523L.83 ~ 683343.48 5977712.64 46L 2.00 ............. ., ........... . .......................................................... j .............. ._:.. D .................... i ............................... ' I ONLY' Z F '"O 3> Fr'l n1-31 2TAT~0~ ~fF~AgUREO INCL~ £DKNT~FICAT~ON DEFTI{ ANG~ 10800~00 55.50 L0900.O0 56.92 ~000.00 $8.36 ~00.00 5~.~3 KAVIK IZ17{.59 60.93 WAHOO Z~ (LZSBLTRRE} 11456.86 63.17 RASE ALAPAH ZONE B 14826.5/ 63.17 TARG~ ********#**** 1{826.5i 63.17 PROPOSED WELL PROFILE DIRECT/ON VERTICAL-DEPT~S AZZMU~R I%~D SUB-S~A 28~.57 8326.33 8272.63 28~.88 838~,94 8328,24 280.24 8435,~7 8385,77 278.65 $486.83 8633.13 277.50 8523.70 8~70.00 SECTION DEPART 5796.34 5879.L5 5963,D9 6048.04 6112,0L 279.51 8535.9? 8482.27 6~33.9L 275.61 8582.83 8529.13 6220.58 275.26 8593-70 8540.00 6261.43 275.26 8593.70 8540.00 6261.43 275.26 8653.70 8600.00 ~357,36 275.26 8653.70 8600.00 275.26 30174.90 10/2/.00 275.26 30174.70 1012~.00 275.26 30174.?0 10121.00 6357.36 9296.11 9296.11 9296.11 22 Jan /998 Page OOORDrNATES-FROM ALASKA Zone 4 TOOk DL/ WELJ_~EAD X Y FACE 100 2432.69 N 5310.96 W 683263.~? 5977731.02 45b 2-00 2450.98 N 5392.02 W 683182~3~ 5977~47,27 4{L 2.00 2467.L7 H 5474.92 W 683099.LL 59~7761.38 43L 2.00 2481,24 H 5559.55 W 683014.L5 5977773.31 43L 2.00 2490,35 H 5623.75 W 6829~9.74 59?7780.79 42L 2.00 2493.17 N 5645.82 W 682927.62 5977783.07 42L 2.00 ~582.95 N 5733.6~ W 6828~9.6L 5977790,63 43L 2.~0 2504.97 N 5754.$4 W 682818,34 5977792.11 H.q 2.00 2504.97 N 5754.84 W 682818.34 5997792.1L HS 2.00 2515,83 N 5872.95 W 682700.00 5997800.00 ~ O-0O 2515-83 N 5872.95 W 682700.00 5977800.00 HS 0.00 · 279~.25 N 886~.16 W 679700.00 5978000.00 0.00 2791.25 N 8869,16 W 679700.00 5998000.00 0.00 279[.2S N 8867.16 W 679700.00 S978000.00 O.00 ! ANADRILL AKA..DPC APP OVED FOP, PERM T"t'I NG ONLY' Z> Z 3> (Anadr£Ll (c)~8 L13iP5 3.2b.5 4:14 PM P) cD DATE 0" -"--"-A 7"-:'--'~ ........ H 132690 __~,: ' / · ,~ ~,,,._,..-7-~ VENDOR A! .A~I-':-.A~T 14 OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET ~ .... -~ lO0 O0 hANDLINg INST' s/h kath9 camp~-oz:or- x 51~_2 I THE &TI'ACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~ ~/ 0 / c,[ c~/ INIT CLASS WELL NAME GEOL AREA PROGRAM: exp [] dev ~[,redrll [] serv [] wellbore seg L3 ann. disposal para req [] UNIT# / f/ ~¢ ,~"'~) ON/OFF SHORE ¢'.~ ~, ADMINISTRATION DATE ,,~ 2. Lease number appropriate ................... 3. Unique well name and number .................. ~ N 4. Well located in a defined pool .................. (,~ N 5. Well located proper distance from drilling unit boundary .... ~ N 6. Well located proper distance from other wells .......... '~.) N 7. Sufficient acreage available in drilling unit ............ N 8. If deviated, is wellbore plat included ............... (~ N 9. Operator only affected party ................... i~N 10. Operator has appropriate bond in force ............. (.~N 11. Permit can be issued without conservation order ........ (~ N 12. Permit can be issued without administrative approval ...... ~ N 13. Can permit be approved before 15-day wait ........... (~) N ENGINEERING APPR D/~,TE 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... t~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N A 17. CMT vol adequate to tie-in long string to surf csg ........ ~Y..,.(._~ ) 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... Y N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... ~ ......... N 26. BOPE press rating appropriate; test to ~ ~ psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N _~ '~'" 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. (~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... ~ Y N 31. Data presented on potential overpressure zo~i Y N 32. Seismic analysis of sh~ ........... Y N 33. Seabed coney (if off-shore) ............. Y N DATE 34. C name/phone for weekly .progress reports ....... Y N ~ ~ r),~,,J~ ~ lexp,oratory only] REMARKS GEOL~(~%: RPC ~ ENGINEERING: COMMISSION: BE~ ~'~DWJ_ ~ JDH ~ RNC -'" co Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * * * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : L1-31 FIELD NAME : LISBURNE BOROUGH : NORTH SLOPE STATE : ALASKA API~ER : 500292286000 REFERENCE NO : 98164 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : L1-31 FIELD NAME : LISBURNE BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292286000 REFERENCE NO : 98164 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30''~' PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 3 ORIGIN : FLIC REEL NAME : 98164 CONTINUATION # : PREVIOUS REEL : CO~k4ENT : ARCO ALASKA, L1-31, LISBURNE, API #50-029-22860-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/04/ 3 ORIGIN : FLIC TAPE NAME : 98164 CONTINUATION # : 1 PREVIOUS TAPE : COGENT : ARCO ALASKA, L1-31, LISBURNE, API #50-029-22860-00 TAPE HEADER LISBURNE OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERA TOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NIJMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN1 98164 V. LOMAX M. BROWN TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING L1-31 500292286000 ARCO ALASKA, INC. SCHLU~fBERGER WELL SERVICES 2-APR-98 RUN 2 RUN 3 1 llN 14E 3080 2755 53.80 53.80 13.20 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 12.250 11224.0 LIS Tape Verif~c'ation Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30~ 3RD STRING PRODUCTION STRING REMARKS: CONTAINED HEREIN IS THE MODIFIED LDWG EDIT PERMORM~D ON LWD AND WIRELINE OPEN HOLE DATA AQUIRED ON ARCO ALASKA'S L1-31 WELL. THE AIT G~RAY IS THE PRIMARY DEPTH CONTROL. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE N-JMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: 0.5000 FILE SU~94ARY LDWG TOOL CODE START DEPTH STOP DEPTH GR 14632.0 11032.0 CNT 14635.0 11032.0 SDN 14656.0 11226.0 AIT 14670.0 11232.0 SGR 14628.0 11042.0 FMI 14644.0 11240.0 DAS 14610.0 10672.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH DAS FMI 88888.0 88889.5 88889.5 14638.0 14639.5 14630.0 14632.0 14624.0 14626.5 14616.5 14618.0 14610.5 14609.5 14602.0 14601.0 14601.5 14603.0 14592.5 14592.5 14586.5 14588.0 14582.5 14584.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30 PAGE: 14580.0 14577.5 14573.5 14567.5 14565.5 14562.0 14556.0 14550.0 14546.0 14543.5 14541.5 14528.5 14513.5 14508.5 14507.0 14504.5 14502 5 14501 5 14491 0 14480 0 14470 5 14466 0 14465 0 14462 0 14459 0 14455 5 14455 0 14440 5 14433 5 14431 0 14419 5 14415 5 14402 5 14394 5 14388 0 14386.5 14376.0 14369 0 14364 0 14361 5 14350 0 14341 5 14322 0 14321.5 14315.5 14311.5 14308.0 14295.5 14293.0 14292.0 14283.5 14279.5 14276.5 14270.5 14266.5 14578.0 14543.5 14508.0 14503.0 14464.5 14455.5 14350.0 14321.0 14294.0 14285.0 14279.5 14581.5 14578.5 14574.5 14571.0 14566.5 14563.0 14556.5 14550.5 14547.5 14543.5 14530.0 14517.5 14514.0 14509.0 14504.0 14491.0 14478.5 14472.0 14468.5 14464.5 14460.0 14456.0 14441.5 14436.5 14433.5 14420.0 14415.0 14404.0 14395.5 14389.5 14386.5 14376.0 14371.5 14366.0 14362.0 14342.5 14323.5 14317.5 14315.0 14310.0 14298.5 14294.5 14279.0 14274.0 14269.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:3~ ...... PAGE: 14259.0 14256.5 14253.0 14245.5 14234.5 14232.0 14219.0 14210.0 14199.5 14196.5 14192.0 14186.0 14180.5 14166.5 14153.0 14137.0 14116.0 14111.0 14108.0 14105.5 14102.5 14100.0 14097.0 14094.5 14086.5 14081.0 14080.0 14078.5 14075.0 14070.5 14066.5 14060.0 14055 5 14054 0 14051 0 14043 0 14037 5 14034 0 14029 0 14028 0 14024 0 14018 0 14011 5 14004 5 13997.5 13995.0 13992.5 13986.0 13985.0 13982.0 13981.5 13960.0 13952.0 13946.0 13945.5 14257.5 14234.5 14196.0 14186.5 14151.5 14099.5 14094.0 14081.0 14066.0 14055.5 14035.0 14028.5 13994.5 13984.5 13981.5 13946.5 14261.5 14256.5 14248.0 14234.0 14223.0 14212.0 14202.0 14196.0 14183.5 14170.0 14141.0 14120.5 14116.0 14110.5 14109.0 14106.0 14099.5 14089.0 14084.0 14081.0 14077.5 14072.5 14059.5 14056.0 14053.5 14043.5 14039.0 14029.0 14025.0 14020.0 14011.5 14005.5 13999.0 13994.5 13986.5 13983.0 13961.5 13953.0 13946.5 · . LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30 PAGE: 13940.0 13937.0 13931.0 13928.0 13923.0 13920.0 13918.5 13911.5 13901.0 13895.0 13894.0 13883.5 13880.5 13874.5 13870.0 13868.0 13866.5 13861 0 13849 5 13843 5 13831 0 13825 0 13824 0 13811.5 13800.0 13786.0 13779.0 13776.0 13763.5 13756.0 13732.0 13726.0 13720.5 13712.5 13693.0 13688.0 13681.0 13677.0 13675.5 13668.0 13653 0 13651 0 13643 0 13638 0 13632 5 13624 5 13620 5 13618 0 13610 5 13608 0 13598 0 13590.5 13582.0 13578.5 13574.0 13929.0 13920.0 13867.5 13824.0 13800.5 13775.5 13755.0 13682.0 13676.5 13653.5 13650.5 13619.0 13608.5 13591.5 13583.0 13940.0 13938.0 13931.0 13925.0 13919.5 13913.0 13900.5 13896.0 13893.5 13883.5 13880.5 13875.5 13869.5 13867.5 13861.0 13850.0 13844.0 13834.0 13827.5 13812.0 13786.0 13778.5 13767 0 13758 0 13731 0 13728 0 13720 5 13713 5 13695 5 13688 5 13680.5 13669.5 13652.0 13649.0 13644.5 13636.5 13631.5 13 624.5 13617.5 13611.5 13600.0 13592.0 13579.5 13574.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30'~'~ PAGE: 13572.5 13568.0 13567.5 13551.0 13547.0 13545.0 13543.5 13533.0 13529.0 13518.5 13512.0 13511.5 13492.5 13489.0 13487.0 13481.0 13476.0 13474.5 13470.5 13468.0 13454.5 13454.0 13446.0 13443.5 13440.5 13432 5 13411 5 13410 5 13407 0 13403 0 13402 5 13399 5 13393 0 13392 0 13381 0 13377 0 13375 0 13373.0 13366.0 13355.5 13352.5 13343.5 13342.5 13334.5 13318.0 13307.5 13299.5 13293.5 13287.0 13283.5 13279.0 13278.0 13262.0 13248.5 13246.0 13574.0 13568.5 13544.5 13512.0 13493.5 13475.5 13469.5 13454.0 13443.0 13441.0 13413.0 13408.0 13403.0 13392.5 13374.0 13355.0 13344.0 13277.5 13248.5 13569.5 13552.5 13547.5 13544.5 13534.5 13529.5 13520.5 13512.5 13489.5 13487.0 13482.0 13476.0 13470.5 13455.0 13446.0 13434.5 13413.0 13410.0 13404.0 13399.5 13392.0 13380.0 13377.0 13373.5 13365.0 13351.5 13342.5 13335.0 13318.0 13309.5 13299.5 13293.5 13285.0 13282.0 13276.5 13261.0 13245.0 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30~ PAGE: 13241.5 13239.5 13237.0 13235.0 13231.0 13226.0 13217.0 13204.5 13203.5 13201.0 13199.0 13195.5 13190.5 13189.0 13186.0 13184.0 13174.5 13165.5 13143.0 13141.5 13133.0 13128.0 13111.5 13104.5 13101.5 13099.0 13098.0 13094.5 13090.0 13083.0 13080.0 13071 5 13064 0 13059 5 13058 0 13048 5 13046 0 13041 5 13034 0 13024 5 13023 5 13013 5 13009 0 13005.5 12999.5 12977.5 12976.0 12966.0 12965.0 12961.0 12959.0 12955.0 12947.0 12946.0 12940.0 13235.0 13205.0 13189.5 13099.0 13060.0 13047.5 13042.0 13024.5 12977.0 12966.0 12960.5 12946.0 13242.0 13239.0 13237.0 13229.0 13226.5 13215.0 13204.0 13200.5 13197.5 13193.5 13189.5 13184.5 13182.0 13173.5 13164.5 13140.5 13140.0 13130.0 13125.5 13110.5 13102.0 13097.5 13095 0 13092 5 13087 0 13080 5 13077 0 13070 0 13062.0 13056.5 13047.5 13033.5 13025.0 13013.5 13009.5 13005.5 12999.0 12977.5 12965.0 12961.0 12955.5 12946.5 12941.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09'.3~0~ PAGE: 12931.0 12922.0 12917.0 12906.5 12901.0 12896.0 12893.0 12883.0 12882 0 12881 0 12864 0 12853 5 12845 5 12843 5 12843 0 12840 0 12831 0 12827 5 12819 0 12814 0 12809 5 12803 0 12797 5 12796 5 12788 0 12782 0 12775 0 12770 5 12770 0 12764 0 12754 0 12752 5 12749 0 12746.0 12737.5 12734.0 12732.5 12726.5 12705.5 12656.5 12650.0 12644.0 12637.5 12631.0 12619.0 12608.0 12592.0 12583.5 12568.5 12564.5 12547.0 12544.0 12538.0 12537.0 12534.0 12882.0 12854.5 12843.5 12827.0 12798.0 12771.0 12754.5 12732.5 12592.0 12543.5 12537.5 12933.0 12924.0 12919.0 12909.0 12903.0 12897.5 12893.5 12884.5 12881.0 12866.0 12853.5 12845.5 12842.5 12839.5 12831.5 12819.0 12813.5 12809.5 12802.0 12798.0 12788.5 12785.0 12776.0 12771.0 12762.5 12754.5 12751.0 12745.5 12738.5 12734.0 12726.0 12706.0 12657.5 12649.5 12644.5 12639.0 12630.5 12618.0 12605.5 12585.0 12568.5 12565.5 12548.0 12535.0 12532.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30 PAGE: 12530.0 12529.0 12525.5 12515.5 12494.0 12487.5 12481.0 12472.5 12463.5 12461 . 5 12457.5 12454.0 12450.0 12443.5 12441.5 12436.0 12434.0 12428.0 12423 0 12422 0 12414 5 12413 5 12407 5 12406 5 12401 5 12397 0 12396 0 12392.5 12392.0 12384.5 12376.5 12376.0 12359.0 12348.5 12345.0 12344.5 12339.0 12329.0 12322.5 12530.5 12487.0 12463.0 12422.5 12412.0 12407.0 12398.0 12393.5 12377.5 12346.0 12323.0 12529.0 12527.5 12513.5 12496.0 12490.0 12482.0 12472.5 12463.0 12458.5 12456.5 12451.0 12445.5 12443.5 12437.5 12434.5 12427.5 12423.0 12413.0 12406.0 12400.5 12398.0 12393.5 12385.5 12377.0 12360.5 12350.5 12345.5 12340.5 12330.5 12323.5 ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 188 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30 PAGE: 10 TYPE REPR CODE VALUE 7 65 8 68 O. 5 9 65 FT 11 66 5 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NtCvfl~~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/F 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 DEV FMS DEG 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 HAZI FMS DEG 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNT LB 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 GR AIT GAPI 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 DEV CNT DEG 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 SP CNT MV 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PU-L 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNT PU-L 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 NPOR CNT PU 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 PEF CNT BN/E 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0PE~I1022723 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CALl CNT IN 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AOIO AIT OH~iM1022723 O0 000 O0 0 1 1 1 4 68 0000000000 A020 AIT OHMM1022723 O0 000 O0 0 1 1 1 4 68 0000000000 A030 AIT OH~M1022723 O0 000 O0 0 1 1 1 4 68 0000000000 A060 AIT 0tfl~I1022723 O0 000 O0 0 1 1 1 4 68 0000000000 A090 AIT 0H~941022723 O0 000 O0 0 i 1 1 4 68 0000000000 ATiO AIT 0H~941022723 O0 000 O0 0 1 1 1 4 68 0000000000 AT20 AIT 0H~4~1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AT30 AIT 0Pff4~1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AT60 AIT OH~4M1022723 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30 PAGE: 11 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 1 1 4 68 0000000000 AT90 AIT 0P~7~1022723 AFiO AIT OH~M1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AF20 AIT 0H~4~1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AF30 AIT 0H~1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AF60 AIT 0H~1022723 O0 000 O0 0 1 1 1 4 68 0000000000 AF90 AIT OH~f1022723 O0 000 O0 0 1 1 1 4 68 0000000000 CGR SGR GAPI 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 POTA SGR PCT 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 SGR SGR GAPI 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 THOR SGR PPM 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 URANSGR PPM 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 PR DAS 1022723 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. C24.FMS TENS.CNT GR.AIT DEV. CNT NPOR.CNT SCRA.DAS AO30.AIT AT20.AIT AFiO.AIT AF90.AIT THOR.SGR 14672 000 -999 250 2740 000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 DEPT. 10672.000 C24.FMS -999.250 TENS.CNT -999.250 GR.AIT 15.400 DEV. CNT -999.250 NPOR.CNT -999.250 SCRA.DAS 2.662 AO30.AIT -999.250 AT20.AIT -999.250 AFiO.AIT -999.250 AF90.AIT -999.250 THOR.SGR -999.250 DT.DAS -999.250 DTSH. DAS -999.250 Cl3.FMS DEV. FMS -999.250 HAZI.FMS -999.250 RB1.FMS CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT SP. CNT -35.375 NPHI.CNT -999.250 CPHI.CNT PEF. CNT -999.250 RHOB.SDN -999.250 MSFL.SDN CALi. CNT -999.250 AOIO.AIT -999.250 AO20.AIT AO60.AIT -999.250 Aogo.AIT -999.250 ATIO.AIT AT30.AIT -999.250 AT60.AIT -999.250 AT90.AiT AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT CGR.SGR -999.250 POTA.SGR -999.250 SGR.SGR URAN. SGR -999.250 PR.DAS -999.250 DT. DAS 54.069 DTSH. DAS 143.905 Cl3.FMS DEV. FMS -999.250 HAZI.FMS -999.250 RB1.FMS CNTC. CNT -999.250 CFTC. CNT -999.250 CRAT. CNT NRAT. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT SP. CNT -999.250 NPHI.CNT -999.250 CPHI.CNT PEF. CNT -999.250 RHOB.SDN -999.250 MSFL.SDN CAL1.CNT -999.250 AOIO.AIT -999.250 AO20.AIT AO60.AIT -999.250 AOgO.AIT -999.250 ATiO.AIT AT30.AIT -999.250 AT60.AIT -999.250 ATgO.AIT AF20.AIT -999.250 AF30.AIT -999.250 AF60.AIT CGR.SGR -999.250 POTA.SGR -999.250 SGR.SGR URAN. SGR -999.250 PR.DAS 0.418 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30~ PAGE: 12 **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE FILE HEADER FILE NUMBER: 2 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0. 5000 FILE SUA94ARY LDWG TOOL CODE $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 14695.0 301 . 0 .......... EQUIVALENT UNSHIFTEDDEPTH .......... BASELINE DEPTH MWD 88888,0 88889.5 14608.0 14609.5 14577,5 14578.5 14515.5 14517.5 14507.5 14509.0 14488,5 14486.5 14481.5 14479.0 14466.5 14464.5 14457.0 14456.0 14415.0 14415.0 14403.0 14404.0 14394.0 14395.5 14389.0 14389.0 14363.5 14365.0 14357,0 14359.5 14294.0 14294.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 14279.0 14275.5 14261.5 14196.0 14120.5 14110.0 14098.0 14092.5 14076.5 14056.0 14040.0 14026.0 14022.5 13968.0 13945.5 13925.5 13914.5 13901.0 13894 5 13835 5 13829 5 13783 5 13759 0 13729 0 13712 0 13682 5 13670 5 13657 0 13647 5 13639 0 13626 0 13613 0 13593.0 13581.0 13577.0 13546.0 13531.0 13509.0 13473.0 13450.5 13397.0 13349.0 13343.5 13325.5 13314.0 13311.0 13305.5 13288.5 13279.0 13273.5 13259.5 13247.5 13237.5 13229.0 13200.0 14279.0 14276.0 14261.5 14195.5 14120.5 14109.0 14097.5 14092.5 14077.5 14056.0 14039.5 14025.0 14019.5 13970.0 13946.5 13925.0 13913.0 13901.0 13894.0 13834.5 13827.5 13782.5 13757.5 13728.0 13712.0 13683.0 13669.5 13656.5 13646.0 13636.5 13625.0 13611.5 13592.0 13579.5 13575.0 13544.5 13530.0 13512.5 13476.0 13454.0 13399.5 13352.0 13347.0 13329.0 13318.0 13315.5 13309.5 13293.0 13282.0 13277.5 13263.0 13251.5 13241.5 13233.5 13204.0 3-APR-1998 09:30 ..... PAGE: 13 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13172.5 13130.5 13111.0 13101.5 13098.0 13086.0 13080.0 13057.0 13049.5 13041.5 13026.5 13018.5 13013.0 12984.5 12979.5 12975 5 12968 5 12948 0 12944 0 12924 0 12894 5 12889 5 12851 0 12846.5 12834.0 12821.5 12815.0 12798.5 12775.0 12756.0 12700.5 12672,0 12663.0 12647.0 12620.5 12579,5 12567,5 12545.5 12538.0 12530.0 12513,0 12469.0 12465.0 12459.0 12434.5 12429.5 12423.0 12402.0 12397 5 12380 0 12363 0 12346 5 12328 0 12325 5 12315 5 13173.5 13132.0 13111.0 13102.0 13098.0 13086.5 13077.0 13056.5 13047.5 13039.0 13025.5 13019.0 13013.0 12985.0 12977.5 12974.5 12967.0 12947.0 12942.5 12924.5 12893.5 12887,5 12848.0 12843.0 12831.5 12819.5 12813.5 12798.0 12776.0 12754.5 12700.0 12669.5 12659.5 12644.5 12617.0 12578.0 12565 5 12544 0 12537 0 12529 5 12512 0 12467 0 12463 5 12456.5 12433.0 12429.5 12422.5 12400.5 12398.0 12377.0 12360.5 12345.0 12327.5 12323.5 12314.5 3-APR-1998 09:30 PAGE: 14 LIS Tape Verification Listing Schlumberger Alaska Computing Center 12288.5 12280.0 12249.0 12245.5 12223.0 12212.5 12199.5 12181.5 12163.0 12158.5 12152.0 12144.0 12141.0 12119.0 12115.0 12085.0 12076.5 12067.5 12052.5 12039.0 12034 5 12012 5 11994 5 11981 5 11914 5 11887 5 11876 5 11843 0 11816 0 11808 5 11795 0 11792 0 11791.0 11765.0 11748.5 11728.0 11721.0 11704.5 11690.5 11662.5 11644.0 11620.0 11610.5 11602.0 11580.5 11564.5 11558.0 11556.0 11535.5 11530.5 11517.5 11510.5 11501.5 11447.0 11442.0 12288.5 12279.0 12250.0 12245.5 12223.5 12214.0 12200.5 12183.0 12163.5 12158 5 12151 5 12144 5 12138 5 12115 5 12112 5 12082 0 12072 5 12066 0 12051 5 12038.5 12035.0 12012.5 11995.0 11982.5 11916.0 11883.5 11873.0 11839.0 11806.5 11800.0 11787.5 11785.0 11783.5 11761.0 11744.0 11723.0 11715.0 11699.5 11686.0 11658.5 11639.5 11614.5 11605.5 11599.0 11576.5 11559.0 11555.0 11552.0 11529.0 11524.5 11512.5 11506.0 11497.5 11443.5 11436.5 3-APR-1998 09:30'-~ PAGE: 15 LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30~'~ PAGE: 16 11429.0 11423.5 11415.5 11407.0 11403.5 11402.5 11392.0 11386.0 11371.5 11315.5 11304.0 11288.5 11270 5 11264 0 11225 0 11208 0 11180 5 11163 5 11144 0 11124 0 11119 5 11112 0 11096 0 11073 5 11048.5 11032.0 5142.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: 11422 5 11417 5 11413 5 11405 5 11399 5 11398 0 11390 5 11383.0 11367.5 11312.5 11300.5 11284.5 11268.0 11260.5 11222.0 11207.5 11179.0 11161.5 11139.0 11117.5 11112.0 11106.0 11087.5 11063.5 11043.0 11028.5 5142.0 100.0 BIT RUN NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE CLIPPED AND DECIMATED LOGGING WHILE DRILLING DATA SHIFTED TO THE AIT GAF~iA RAY. $ 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 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 3-APR-1998 09:30~-~~ PAGE: 17 TYPE REPR CODE VALUE 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 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) DEPT FT 1022723 O0 000 O0 0 2 1 1 4 68 0000000000 GR MWD GAPI 1022723 O0 000 O0 0 2 1 1 4 68 0000000000 ROP MWD FPHR 1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RA MWD 0H~41022723 O0 000 O0 0 2 1 1 4 68 0000000000 RP MWD 0H~4~1022723 O0 000 O0 0 2 1 1 4 68 0000000000 FET MWD HR 1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RBS1MWD OH~IM1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RBS2 MWD 0H~4~1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RBS3 M~ OH~IM 1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RING MWD OH~iM1022723 O0 000 O0 0 2 1 1 4 68 0000000000 RBITMWD OH~k41022723 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 14696.500 GR.MWD -999.250 ROP.MWD 6.960 RA.MWD RP.MWD -999.250 FET.MWD -999.250 RBS1.MWD -999.250 RBS2.MWD RBS3.MWD -999.250 RING.MWD -999.250 RBIT.MWD -999.250 DEPT. 301.000 GR.MWD -999.250 ROP.MWD 172.380 RA.MWD RP.MWD -999.250 FET.MWD -999.250 RBS1.MWD -999.250 RBS2.MWD RBS3.MWD -999.250 RING.MWD -999.250 RBIT.MWD -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 3-APR-1998 09:3~ PAGE: 18 **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 98/04/ 3 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/04/ 3 ORIGIN : FLIC TAPE NAME : 98164 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA, L1-31, LISBURNE, API #50-029-22860-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/04/ 3 ORIGIN : FLIC REEL NAME : 98164 CONTINUATION # : PREVIOUS REEL : CO~4~ENT . ARCO ALASKA, L1-31, LISBURNE, API #50-029-22860-00 * ALASKA COMPUTING CENTER * . ............................ . ....... SCHLUMBERGER ....... RECEIVED COMPANY NAME WELL NAME FIELD NAME BOROUGH STATE API NUMBER REFERENCE NO JAN 2 7 1999 .~:o .~_~=~ =,Al~ka Oil & Gas Cons. Comm~ion ~-= M~or~ LISB~ NOR~ SLOPE ~AS~ 500292286000 98637 LIS Tape Verifi~on Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:O1 .~i PAGE: * * * * REEL HEADER * * * * SERVICE NAME : EDIT DATE : 99/01/18 ORIGIN : FLIC REEL NAME : 98637 CONTINUATION # : PREVIOUS REEL : COGENT : ARCO ALASKA INC, L1-31, LISBURNE, API #50-029-22860-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 99/01/18 ORIGIN : FLIC TAPE NAME : 98637 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, L1-31, LISBURNE, API #50-029-22860-00 TAPE HEADER LISBURNE OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL : ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING RUN 1 98637 D KIRKBY BROWN L1-31 500292286000 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 18-JAN-99 RUN 2 RUN 3 3O8O 2755 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 7.000 13073.0 1 llN 14E 53.80 53.80 13.20 LIS Tape Verific~ion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01 3RD STRING PRODUCTION STRING REMARKS: THIS TAPE CONTAINS THE LDWG FORMATTED OPEN HOLE PEX, HALS, AND CMR DATA AQUIRED ON ARCO ALASKA'S L1-31 WELL. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE · FLIC VERSION · 0 O1 CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUFk4ARY LDWG TOOL CODE SDN CNT DLL CMR $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 13390.0 13072.0 13374.0 13072.0 13402.0 13072.0 13341.0 13072.0 BASELINE DEPTH 88888.0 13371.5 13367.0 13361.5 13355.0 13352.0 13341.5 13334.5 13327.5 13318.5 13315.0 13308.5 13302.5 13299.0 13290.5 13287.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT DLL CMR 88888.5 13372.0 13368.0 13362.0 13354.5 13352.0 13342.5 13335.0 13328.5 13318.0 13315.5 13309.5 23302.5 13299.0 13290.0 13285.0 LIS Tape Verifi~cation' '~J Listing Schlumberger Alaska Computing Center 13283.0 13277.5 13272.5 13270.5 13266.0 13263.0 13260.0 13251 . 5 13246.0 13241.0 13239.0 13228.0 13225.0 13220.5 13215.5 13211.0 13208.0 13204.0 13199 5 13193 0 13184 5 13181 5 13179 5 13173 0 13171 0 13164 5 13143 5 13136 0 13122 0 13109 5 13104.5 13102.5 13098.0 13092.5 13089.5 13086.5 13077.5 13075.0 13072.0 13066.5 13062.0 13057.0 13050.0 13047.5 13039.0 13032.0 13023.0 13015.0 13012.5 13008 0 12999 0 12995 5 12992 5 12991 0 12989 0 13282.0 13277.0 13274.5 13271.5 13267.0 13262.5 13260.5 13251.5 13246.5 13241.5 13239.0 13228.5 13226.5 13221.5 13214.5 13211.5 13208.0 13204.5 13200.5 13193.5 13184.5 13182.0 13180.0 13174.0 13171.0 13164.5 13142.0 13134.5 13122.0 13110.5 13105.0 13102.0 13098.0 13092.5 13089.5 13087 0 13077 0 13075 0 13072 0 13067 0 13062 0 13056 5 13049 5 13047 5 13039.0 13034.0 13025.5 13016.0 13013.0 13007.5 12999.0 12995.5 12992.5 12990.5 12989.5 18-JAN-1999 16:01 PAGE: LIS Tape VerifiJ~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01 PAGE: 12985.0 12985.0 12980.0 12980.0 12977.0 12977.5 12974.5 12974.5 100.0 100.0 $ MERGED DATA SOURCE LDWG TOOL CODE RUN NO. $ REMARKS: PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE EDITED OPEN HOLE DATA. THE SDN GR IS SHIFTED TO THE AIT OR AQUIRED BY SWS ON 17-MAR-98, CARRYING ALL CURVES WITH THE GR SHIFTS. ALL THE DATA IS CLIPPED AT FIRST READING AND AT CASING. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 140 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 7 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 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 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 GR SDN GAPI 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verif~c~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: 01'- ~ PAGE: 5 NAME SERV trNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) TENS SDN LB 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 TEND SDN LB 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 MRES SDN 0H~46037495 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMSDN DEGF 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 DEV SDN DEG 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNT CPS 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNT CPS 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNT CPS 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNT CPS 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNT 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNT 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNT PUqL 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 TNPH CNT PU-L 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CALl SDN IN 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 DRHO SDN G/C3 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 PEF SDN BN/E 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 RHOB SDN G/C3 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 MSFL SDN 0H~I6037495 O0 000 O0 0 1 1 1 4 68 0000000000 MINVSDN 0H~94 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 ~!NORSDN OHFk4 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 LLD DLL 0t~v~I6037495 O0 000 O0 0 1 1 1 4 68 0000000000 LLS DLL 0t~v~I6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CFF4 CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 BFV CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CFF5 CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CFF6 CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CFF7 CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CMFF CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 KSDR CFIR ~iD 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 KTIM CMR FiD 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 T2LM CMR 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 TCMR CMR PU-L 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 CMRP CMR PU-L 6037495 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.000 GR.SDN -999.250 TENS.SDN 1569.000 TEND.SDN 611.928 MRES.SDN -999.250 MTEM. SDN -999.250 DEV. SDN -999.250 CNTC. CNT -999.250 CFTC. CNT -999.250 FCNT. CNT -999.250 NCNT. CNT -999 250 CRAT. CNT -999.250 NRAT. CNT -999.250 NPHI.CNT -999.250 TNPH. CNT -999 250 CAL1.SDN -999.250 DRHO.SDN -999.250 PEF. SDN -999.250 RHOB.SDN -999 250 MSFL.SDN -999.250 MINV. SDN -999.250 ~!NOR.SDN -999.250 LLD.DLL -999 250 LLS.DLL -999.250 CFF4.CMR -999.250 BFV. C~4R -999.250 CFFS.CPiR -999 250 CFF6.CMR -999.250 CFF7.CMR -999.250 CMFF. CMR -999.250 KSDR.CTIR -999 250 KTIM. CI~R -999.250 T2LM. CMR -999.250 TCMR.CAIR -999.250 CMRP. CMR o -999 250 LIS Tape Verifi-c~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01 ...... PAGE: DEPT. 13072.000 GR.SDN MRES.SDN 0.013 MTEM. SDN CFTC. CNT 1005.732 FCNT. CNT NRAT. CNT 1.924 NPHI.CNT DRHO.SDN 0.185 PEF. SDN MINV. SDN 0.479 MNOR.SDN CFF4.CMR -999.250 BFV. CMR CFFT.CMR -999.250 CMFF. C~4~ T2LM. CMR -999.250 TC~R.CNiR 25.420 TENS. SDN 186.354 DEV. SDN 930.205 NCNT. CNT 12.727 TNPH. CNT 9.075 RHOB.SDN 0.459 LLD.DLL -999.250 CFFS.CMR -999.250 KSDR.C~N -999.250 C~ikP. C~i~ 1818.000 TEND.SDN 63.258 CNTC. CNT 1706.796 CRAT. CNT 11.023 CAL1.SDN 2.917 MSFL.SDN 13.109 LLS.DLL -999.250 CFF6.CNi~ -999.250 KTIM. C~N -999.250 540.414 1796.155 1.886 8.800 1.902 13.555 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUN2VARY LDWG TOOL CODE SDN CNT BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 13072.0 12974.0 13072.0 12974.0 BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... SDN CNT LIS Tape Verifi~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01 ...... PAGE: 88888.0 13371.5 13367.0 13361.5 13355.0 13352.0 13341.5 13334.5 13327.5 13318.5 13315.0 13308.5 13302.5 13299.0 13290.5 13287.0 13283.0 13277.5 13272.5 13270.5 13266.0 13263.0 13260.0 13251.5 13246.0 13241.0 13239.0 13228.0 13225.0 13220.5 13215.5 13211.0 13208.0 13204.0 13199.5 13193.0 13184.5 13181.5 13179.5 13173.0 13171.0 13164.5 13143.5 13136.0 13122.0 13109.5 13104.5 13102.5 13098.0 13092.5 13089.5 13086.5 13077.5 13075.0 88888.5 13372.0 13368.0 13362.0 13354.5 13352.0 13342.5 13335.0 13328.5 13318.0 13315 5 13309 5 13302 5 13299 0 13290 0 13285 0 13282 0 13277.0 13274.5 13271.5 13267.0 13262.5 13260.5 13251.5 13246.5 13241.5 13239.0 13228.5 13226.5 13221.5 13214.5 13211.5 13208.0 13204.5 13200.5 13193 5 13184 5 13182 0 13180 0 13174 0 13171 0 13164 5 13142 0 13134 5 13122 0 13110 5 13105 0 13102.0 13098.0 13092.5 13089.5 13087.0 13077.0 13075.0 LIS Tape Verif~c~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: 01.~ ~' PAGE 13072.0 13066.5 13062.0 13057.0 13050.0 13047.5 13039.0 13032.0 13023.0 13015.0 13012.5 13008.0 12999.0 12995.5 12992 5 12991 0 12989 0 12985 0 12980 0 12977 0 12974.5 100.0 $ 13072.0 13067.0 13062. 0 13056.5 13049 5 13047 5 13039 0 13034 0 13025 5 13016 0 13013. 0 13007.5 12999.0 12995.5 12992.5 12990.5 12989.5 12985.0 12980.0 12977.5 12974.5 100.0 REMARKS: THIS FILE CONTAINS THE EDITED CASED HOLE DATA. THE SDN GR IS SHIFTED TO THE SWS AIT GR AQUIRED ON 17-MAR-98, CARRYING ALL CURVES WITH THE GR SHIFTS. THE DATA IS CLIPPED AT FIRST READING AND AT LAST READING. $ LIS FORMAT DATA ** DATA FO~T SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01~ ~ PAGE: TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CH_AN ** 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 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 TENS SDN LB 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 HTEN SDN LB 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 MTEM SDN DEGF 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH SDN GAPI 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNT CPS 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNT CPS 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 RCFT CNT CPS 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 RCNT CNT CPS 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNT 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNT 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNT PU-L 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH CNT PU-L 6037495 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 13072.000 TENS.SDN 1818.000 HTEN. SDN 540.414 MTEM. SDN GRCH. SDN 25.420 CNTC. CNT 1796.155 CFTC. CNT 1005.732 RCFT. CNT RCNT. CNT 1706.796 CRAT. CNT 1.886 ~T. CNT 1.924 NPHI.CNT TNPH. CNT 11.023 DEPT. 12974.000 TENS.SDN 1788.000 HTEN. SDN 607.552 MTE~I. SDN GRCH. SDN 35.449 CNTC. CNT 1623.825 CFTC. CNT 759.601 RCFT. CNT RCNT. CNT 1659.084 CRAT. CNT 2.170 NRAT. CNT 2.096 NPHI.CNT TNPH. CNT 16.325 186. 354 930.205 12. 727 184.123 717. 839 19. 653 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE · 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verific~tion Listing Schlumberger Alaska Computing Center 18-JAJV-1999 16:01 PAGE: 10 **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING ~BER: PASS NUMBER: DEPTH INCREMENT: FILE SUFk4ARY FILE HEADER FILE ArUMBER 3 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit ru2~ presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 13412.5 13072.0 ~ 13412.5 13072.0 HALS 13412.5 13072.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GANk4A RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 03 -0CT~98 8Cl -205 100 03 -0CT-98 500 03 -0CT-98 14696.0 12972.0 13412.0 TOOL NUMBER HGR HCNT HRDD ~4RT 8.500 13073.0 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 18-JA~V-1999 16:0~ .... PAGE: 11 LOGGERS CASING DEPTH (FT) : 13072.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 59.0 MUD PH: 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) : 190.0 RESISTIVITY (OHN~f) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 0. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : ~ffJD CAKE AT (MT): O. 098 MUD CAKE AT (BHT): 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL).. MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LI~!ESTONE 2.71 TOOL STANDOFF (IN): 1.0 REMARKS.. Depth correlated to Schlumberger's Neutron/Density of 17-Mar-98. Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE MAIN PASSS DATA AQUIRED AT O. 5 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 108 4 66 1 LIS Tape Veri~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01~ PAGE: 12 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 9 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 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 GR PEX GAPI 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 TENS PEX LB 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 HTEN PEX LB 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 MRES PEX OH~4 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 MTEM PEX DEGF 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 DEVI PEX DEG 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC PEX CPS 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC PEX CPS 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 RCFT PEX CPS 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 RCNT PEX CPS 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 TNRA PEX 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 RTNR PEX 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 TNPH PEX PU 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI PEX PU-L 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 NPOR PEX PU 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CFF4 CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 BFV CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CFF5 CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CFF6 CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CFF7 CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CMFF CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 KSDR CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 KTIM CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 T2LMCMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 TCMR CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 CMRP CMR 6037495 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** LIS Tape Verif~cation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~ PAGE: 13 DEPT. 13413 . 000 GR. PFJ~ MRES. PEX -999.250 MTE~.PEX CFTC. PEX -999. 250 RCFT. PEX RTNR. PEX -999. 250 TNPH. PEX CFF4 . CMR -999. 250 BFV. ~ CFF7. CMR -999. 250 CMFF. CMR T2LM. CMR -999. 250 TCMR. CFiR DEPT. 12814.500 GR.PEX MRES. PEX -999.250 MTEM. PEX CFTC. PEX -999.250 RCFT. PEX RTNR.PEX -999.250 TNPH. PEX CFF4.CMR -999.250 BFV. CAZR CFF7.CMR -999.250 CMFF. C~iR T2LM. CMR -999.250 TC~R.~ -999.250 TENS. PEX -999.250 DEVI.PEX -999.250 RCNT. PEX -999.250 NPHI.PEX -999.250 CFFS.C~ZR -999.250 KSDR. CfqR -999.250 C?4RP. ClViR -999.250 TENS.PEX -999.250 DEVI.PEX -999.250 RCNT. PEX -999.250 NPHI.PEX -999.250 CFFS.CMR -999.250 KSDR.C~iR -999.250 C?/iRP. ClviR -999.250 HTEN. PEX -999.250 CNTC. PEX -999.250 T1VRA.PEX -999.250 NPOR.PEX -999.250 CFF6.C?4R -999.250 KTIM. CMR -999.250 -999.250 HTEN. PEX -999.250 CNTC. PEX -999.250 TNRA.PEX -999.250 NPOR.PEX -999.250 CFF6. C~iR -999.250 KTIM. CFiR -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: O. 1667 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01~l PAGE: 14 FILE SU~94ARY VENDOR TOOL CODE START DEPTH PEX 13412.5 CMR 13412.5 HALS 13412.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAlVfiVIA R~Y CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TEMPERATURE (DEGF) RESISTIVITY (0H~94) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) MUD AT BOTTOM HOLE TEMPERATURE (BHT) MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT): MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 13072.0 13072.0 13072.0 03 - OCT- 98 8Cl -205 100 03-0CT-98 500 03 -0CT-98 14696.0 12972.0 13412.0 TOOL NUMBER HGR HC~ HALS-B HRDD CMRT 8.500 13073.0 13072.0 BRINE 9.50 59.0 7.4 6.0 190.0 O. 053 70.0 O. 053 70.0 O. 098 70.0 THERMAL LIME S T ONE 2.71 LIS Tape Verif~a'tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: Oi~-~ PAGE: 15 TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-Mar-98. Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE MAIN PASS DATA AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** * * SET TYPE - 64EB * * TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 15 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 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 LLD HALS Oh?4M6037495 O0 000 O0 0 4 1 1 4 68 0000000000 LLS HALS OH~4M 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HDRA PEX G/C3 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:O1~j PAGE: 16 NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) PEFZ PEX 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 RHOZ PEX G/C3 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HMIN PEX OHN~4 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 H~!NO PEX OH2V~l6037495 O0 000 O0 0 4 1 1 4 68 0000000000 RXOZ PEX OH~I 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 RX08 PEX 0I~4~ 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HCNT PEX CPS 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HCFT PEX CPS 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HGR PEX GAPI 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 RHFT PEX CPS 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 RHNT PEX CPS 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HTNP PEX PU 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 HNPO PEX PU 6037495 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.500 LLD.HALS 0.222 LLS.HA-LS 0.889 HDRA.PEX PEFZ.PEX -999.250 RHOZ.PEX -999.250 P~4IN. PEX 0.297 H~NO. PEX RXOZ.PEX 1.795 RXO8.PEX 1.806 HCNT. PEX 3260.589 HCFT. PEX HGR.PEX 63.862 RHFT. PEX 1739.375 RHNT. PEX 3158.247 HTNP. PEX HNPO. PEX 10.478 DEPT. 13072.000 LLD.HALS 13.109 LLS.HALS 13.555 HDRA.PEX PEFZ.PEX 9.075 RHOZ.PEX 2.917 H~IN. PEX 0.479 HI~IO. PEX RXOZ.PEX 1.902 RXO8.PEX 1.386 HCNT. PEX 1796.814 HCFT. PEX HGR.PEX 11.816 RHFT. PEX 937.458 RHNT. PEX 1716.993 HTNP. PEX HNPO. PEX 11.119 -999.250 0.390 1901.912 10.719 0.185 0.459 1005.780 11.030 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:O1~-~ PAGE: 17 * * * * FILE HEADER * * * * FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW OPEN HOLE MAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. RUN NUMBER: 1 TOOL STRINGNUMBER: 1 PASS NUMBER: 1 DEPTH INCREMENT: 0.0833 FILE SUFk4ARY VENDOR TOOL CODE START DEPTH PEX 13412.5 CMR 13412.5 HALS 13412.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 13072.0 13072.0 13072.0 03-0CT-98 8Cl-205 100 03-0CT-98 500 03-0CT-98 14696.0 12972.0 13412.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : TOOL NUMBER HGR HCNT HRDD CMRT 8.500 13073.0 LIS Tape Verif~'tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~~ PAGE: 18 LOGGERS CASING DEPTH (FT) : 13072.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) ~ 59.0 MUD PH : 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) ~ 190.0 RESISTIVITY (OHF~I) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT) ~ O. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 098 MUD CAKE AT (BHT): 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-Mar-98. Tools ran drill pipe conveyed with 4 tool turners. T~o 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the 'correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE MAIN PASS DATA AQUIRED AT O. 0833 ' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: 0_~-~ PAGE: 19 TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 6037495 O0 000 O0 0 5 1 1 4 68 0000000000 HCAL PEX IN 6037495 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.500 HCAL.PEX 3.817 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT . 006 SERVICE · FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 18-JA2~-1999 16:O1~- ~ PAGE: 20 FILE HEADER FILE NUMBER 6 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUN~4A~Y VENDOR TOOL CODE START DEPTH PEX 13072.0 HALS 13072.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): STOP DEPTH 12814.5 12814.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~fl~A RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENS I TY CMR MAGNETIC RESONANCE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3) '. MAXIMUM RECORDED TEMPERATURE (DEGF): RESISTIVITY (OH~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): 03-0CT-98 8Cl-205 100 03-0CT-98 500 03-0CT-98 14696.0 12972.0 13412.0 TOOL NUMBER HGR HCNT HALS-B HRDD CMRT 8.500 13073.0 13072.0 BRIAYE 9.50 59.0 7.4 6.0 190.0 O. 053 70.0 O. 053 70.0 O. 098 70.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~ PAGE: 21 MUD CAKE AT (BHT) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-M Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and do~n log data pres. ented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE REPE~T DATA AQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 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 18-JAN-1999 16:01~ PAGE: 22 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUI~B NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 6037495 O0 000 O0 TENS PEX LB 6037495 O0 000 O0 CNTC PEX CPS 6037495 O0 000 O0 CFTC PEX CPS 6037495 O0 000 O0 TNRA PEX 6037495 O0 000 O0 GR PEX GAPI 6037495 O0 000 O0 RTNR PEX 6037495 O0 000 O0 RCFT PEX CPS 6037495 O0 000 O0 RCNT PEX CPS 6037495 O0 000 O0 DEVI PEX DEG 6037495 O0 000 O0 HTEN PEX LB 6037495 O0 000 O0 MRES PEX OI~ff46037495 O0 000 O0 MTEM PEX DEGF 6037495 O0 000 O0 NPHI PEX PU-L 6037495 O0 000 O0 TNPH PEX PU 6037495 O0 000 O0 NPOR PEX PU 6037495 O0 000 O0 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 13412. 500 TENS. PEX 1434. 000 CNTC. PEX 5244 . 372 CFTC. PEX TNRA.PEX 0.810 GR.PEX 40. 733 RTNR.PEX 1.574 RCFT. PEX RCNT. PEX 3095. 193 DEVI. PEX -999. 250 HTEN. PEX -2771 . 130 ~ES. PEX MTEM. PEX 187.841 NPHI. PEX 1.881 TNPH. PEX -0.622 NPOR. PEX DEPT. 12989.500 TENS.PEX 1072.000 CNTC. PEX 4654.504 CFTC. PEX TNRA.PEX 1.044 GR.PEX 15.966 RTN-R.PEX 1.075 RCFT.PEX RCNT. PEX 4495.074 DEVI.PEX 63.914 HTEN. PEX 462.926 I~ES.PEX MTEM. PEX 185.663 NPHI.PEX 4.986 TNPH. PEX 1.920 NPOR.PEX 6855.114 1955.222 0.014 -0.784 4617. 480 4182. 706 O. 025 1. 807 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE · FLIC VERSION · O01CO1 DATE · 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0i~=--" PAGE: 23 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE · 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : RUN NUMBER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SOY~iARY FILE HEADER FILE NUMBER 7 RAW OPEN HOLE REPEAT PASSES Curves and log header data for each pass, tool string, and run in separate files. 1 1 2 0.1667 VENDOR TOOL CODE START DEPTH STOP DEPTH PEX 13072.0 12814.5 HALS 13072.0 12814.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) '. TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) '. TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR G~ RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS 03-0CT-98 8C1-205 100 03-0CT-98 500 03-0CT-98 14696.0 12972.0 13412.0 TOOL NUMBER ........... HGR HCNT HALS-B HRDD C~RT 8.500 13073.0 13072.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:O1~r ~ PAGE '. 24 MUD TYPE: BRINE MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 59.0 MUD PH : 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) : 190.0 RESISTIVITY (OHFk4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 098 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MA TRIX: LIMESTONE MATRIX DENSITY: 2.71 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : 1. 0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-M Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT DATA AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.166 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~'~ PAGE: 25 TYPE REPR CODE VALUE 9 65 FT 11 66 15 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 ELE~ CODE (HEX) DEPT FT 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 LLD HALS OHMM 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 LLS HALS 0H~94 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 HDRA PEX G/C3 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 PEFZ PEX 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 RHOZ PEX G/C3 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 H~4IN PEX OH~E4 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 H~NO PEX 0H~94 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 RXOZ PEX OHffff4 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 RX08 PEX OH~ff46037495 O0 000 O0 0 7 1 1 4 68 0000000000 HCNT PEX CPS 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 HCFT PEX CPS 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 HGR PEX GAPI 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 RHFT PEX CPS 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 RHNT PEX CPS 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 HTNP PEX PU 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 HNPO PEX PU 6037495 O0 000 O0 0 7 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.500 LLD.HALS 4461.922 LLS.HALS 179.304 HDRA.PEX PEFZ.PEX -999.250 RHOZ.PEX -999.250 I@4IN. PEX 0.168 I~4NO. PEX RXOZ.PEX 1.755 RXO8.PEX 1.775 HCNT. PEX 5221.454 HCFT. PEX HGR.PEX 42.572 RHFT. PEX 1997.307 RHNT. PEX 3117.054 HTNP. PEX HNPO. PEX -0.775 DEPT. 12989.834 LLD.HALS 563.703 LLS.HALS 125.707 HDRA.PEX PEFZ.PEX 4.750 RHOZ.PEX 2.573 I~4IN. PEX 1.109 H~NO. PEX RXOZ.PEX 3.221 RXO8.PEX 3.221 HCNT. PEX 4654.504 HCFT. PEX HGR.PEX 15.966 RHFT. PEX 4182.706 RHNT. PEX 4495.074 HTNP. PEX HNPO. PEX 1.807 -999.250 0.234 6734.368 -0.520 -0. 036 O. 696 4617. 480 1. 920 ** END OF DATA ** LIS Tape Verific'ation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: Ol-- PAGE: 26 **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .008 SERVICE · FLIC VERSION · O01CO1 DATE · 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 8 RAW OPEN HOLE REPEAT PASSES Curves a~d log header data for each pass, tool string, and run in separate files. RUN NUMBER: 1 TOOL STRING NUMBER: 1 PASS NUMBER: 2 DEPTH INCREMENT: 0.0833 FILE SUlVk4ARY VENDOR TOOL CODE START DEPTH PEX 13072.0 HALS 13072.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) LOGGING SPEED (FPHR) : STOP DEPTH .......... 12814.5 12814.5 03 -0CT-98 8Cl -205 100 03-0CT-98 500 03 -0CT-98 14696.0 12972.0 13412.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GA~4~A RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG TOOL ~ER HGR HCNT HALS-B LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: oi~-~ '~ PAGE: 27 SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : HRDD C~T 8.500 13073.0 13072.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 59.0 MUD PH: 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) : 190.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 098 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MATRIX: LIMESTONE MATRIX DENSITY: 2.71 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-M Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass through and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and do~zn log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW OPEN HOLE REPEAT DATA AQUIRED AT O. 0833 ' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~ ...... PAGE: 28 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 8 4 66 1 5 66 6 73 7 65 8 68 0.083 9 65 FT 11 66 128 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 6037495 O0 000 O0 0 8 1 1 4 68 0000000000 HCAL PEX IN 6037495 O0 000 O0 0 8 1 1 4 68 0000000000 ** DATA ** DEPT. 13412.500 HCAL.PEX 3.817 DEPT. 12989.584 HCAL.PEX 3.817 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .008 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0i PAGE: 29 **** FILE HEADER **** FILE NAME : EDIT .009 SERVICE : FLIC VERSION · O01CO1 DATE · 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 9 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH PEX 13072.0 $ LOG HEADER DATA STOP DEPTH .......... 12814.5 DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNT COMPENSATED NEUTRON HALS AZIMUTHAL LATEROLOG SDN DENSITY CMR MAGNETIC RESONANCE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): 03-0CT-98 8Cl-205 100 03-0CT-98 500 03-0CT-98 14696.0 12972.0 13412.0 TOOL NUMBER HGR HCNT HRDD CNi~T 8.500 13073.0 13072.0 BRINE 9.50 59.0 LIS Tape VerifiCation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0~ ..... ' PAGE: 30 MUD PH : 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) : 190.0 RESISTIVITY (OHIO4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 098 MUD CAKE AT (BHT): 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): THERMAL LIMESTONE 2.71 TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of i7-M Tools ran drill pipe conveyed with 4 tool turners. Two 1" standoffs ran on HALS. Encountered a bridge at 13412'. Tools could not pass thro and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW CASED HOLE MAIN PASS DATA AQUIRED AT 0.5' SAMPLE RATE. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: Oi~ PAGE: 31 TYPE REPR CODE VALUE 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 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 TENS PEX LB 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 CNTC PEX CPS 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 CFTC PEX CPS 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 TNRA PEX 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 GR PEX GAPI 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 RTNR PEX 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 RCFT PEX CPS 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 RCNT PEX CPS 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 DEVI PEX DEG 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 HTEN PEX LB 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 MRES PEX OHNff46037495 O0 000 O0 0 9 1 1 4 68 0000000000 MTEM PEX DEGF 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 NPHI PEX PU-L 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 TNPH PEX PU 6037495 O0 000 O0 0 9 I 1 4 68 0000000000 NPOR PEX PU 6037495 O0 000 O0 0 9 1 1 4 68 0000000000 ** DATA ** DEPT. 13072.000 TENS.PEX 1818.000 CNTC.PEX 1796.155 CFTC. PEX TNRA.PEX 1.886 GR.PEX 25.420 RTNR.PEX 1.924 RCFT. PEX RCNT. PEX 1706.796 DEVI.PEX 63.258 HTEN. PEX 540.414 I~i~ES.PEX MTEM. PEX 186.354 NPHI.PEX 12.727 TNPH. PEX 11.023 NPOR.PEX DEPT. 12814.500 TENS.PEX 1739.000 CNTC. P~ 1577.940 CFTC. PEX TNRA.PEX 2.298 GR.PEX 47.023 RTNR.PEX 3.307 RCFT. PEX RCNT. PEX 1412.771 DEVI.PEX 63.627 HTEN. PEX 615.810 NZRES.PEX MTEM. PEX 183.337 NPHI.PEX 21.583 TNPH. PEX 18.133 NPOR.PEX 1005.732 930.205 0.013 11.250 698.184 444.090 0.018 16.440 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:0i PAGE: 32 **** FILE TRAILER **** FILE NAME : EDIT .009 SERVICE · FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION · O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 10 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.1667 FILE SU~ff4ARY VENDOR TOOL CODE START DEPTH STOP DEPTH 13072.0 12814.5 PEX $ LOG HEADER DATA DATE LOGGED: 03-0CT~98 SOFT~VARE VERSION: 8Cl-205 TIME CIRCULATION ENDED: 100 03-0CT-98 TIME LOGGER ON BOTTOM: 500 03-0CT-98 TD DRILLER (FT) : 14696.0 TD LOGGER (FT) : TOP LOG INTERVAL (FT) : 12972.0 BOTTOM LOG INTERVAL (FT): 13412.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GR GA~A RAY HGR CNT COMPENSATED NEUTRON HCNT HALS AZIMUTHAL LATEROLOG HALS-B SDN DENSITY HRDD CMR MAGNETIC RESONANCE CMRT $ · LIS Tape Verif'i~'ation Listing Schlumberger Alaska Computing Center 18-JAN-1999 16:01-~ PAGE: 33 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 8.500 13073.0 13072.0 BOREHOLE CONDITIONS MUD TYPE: BRINE MUD DENSITY (LB/G): 9.50 MUD VISCOSITY (S) : 59.0 MUD PH: 7.4 FLUID LOSS (C3): 6.0 MAXIMUM RECORDED TEMPERATURE (DEGF) : 190.0 RESISTIVITY (OH2~M) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): O. 053 MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): O. 053 MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): O. 098 MUD CAKE AT (BHT) : 70.0 70.0 70.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): THERMAL MA TR IX: LIMES TONE MATRIX DENSITY: 2.71 HOLE CORRECTION (IN) : TOOL STANDOFF (IN): 1.0 REMARKS: Depth correlated to Schlumberger's Neutron/Density of 17-M Tools ran drill pipe conveyed ~zith 4 tool turners. Two i" standoffs ran on HALS. Encountered a bridge at 13412 '. Tools could not pass thro and data was gathered from the bridge to the shoe. No eccentralizers were run due to 7" liner restrictions. GPIT indicated tools remained on the correct axis for the duration of the log. Up and down log data presented for PEX. PEX ran without speed correction. THIS FILE CONTAINS THE RAW CASED HOLE MAIN PASS DATA AQUIRED AT 0.1667' SAMPLE RATE. $ LIS FORMAT DATA LIS Tape Verif£~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: Oi PAGE: 34 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.166 9 65 FT 11 66 15 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 6037495 O0 000 O0 0 i0 i 1 4 68 0000000000 LLD HALS OHMM 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 LLS HALS OH~4~ 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HDRA PEX G/C3 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 PEFZ PEX 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 RHOZ PEX G/C3 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HMIN PEX OH~k46037495 O0 000 O0 0 10 1 1 4 68 0000000000 HMNO PEX OH~k4 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 RXOZ PEX 0P2~4 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 RX08 PEX OH~M 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HCNT PEX CPS 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HCFT PEX CPS 6037495 O0 000 O0 0 10 1 ! 4 68 0000000000 HGR PEX GAPI 6037495 O0 000 O0 0 !0 1 1 4 68 0000000000 RHFT PEX CPS 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 RHNT PEX CPS 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HTNP PEX PU 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 HNPO PEX PU 6037495 O0 000 O0 0 10 1 1 4 68 0000000000 ** DATA ** DEPT. 13072.000 LLD.HALS 13.109 LLS.HALS 13.555 PiDRA.PEX PEFZ.PEX 9.075 RHOZ.PEX 2.917 HI~IN. PEX 0.479 P~NO.PEX RXOZ.PEX 1.902 RXO8.PEX 1.386 HCNT. PEX 1796.814 HCFT. PEX HGR.PEX 11.816 RHFT. PEX 937.458 RHNT. PEX 1716.993 HTNP. PEX 0.185 0.459 1005.780 11.030 LIS Tape Veri~i~'~tion Listing Schlumberger Alaska Computing Center 18-JAN-1999 16: O~~ PAGE: 35 HNPO. PEX 11.119 DEPT. 12814.834 LLD.HALS PEFZ.PEX 10.000 RHOZ.PEX RXOZ.PEX 0.144 RXO8.PEX HGR.PEX 49.792 RHFT. PEX HNPO. PEX 21.428 0.100 LLS.HALS 4.629 t~MIN. PEX 0.144 HCNT. PEX 459.041 RHNT. PEX O . 1 O0 HDRA. PEX 0.137 I~INO . PEX 1489. 724 HCFT. PEX 1363. 228 HTNP. PEX 1. 688 0.116 637. 863 19. 271 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .010 SERVICE : FLIC VERSION : O01CO1 DATE : 99/01/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 99/01/18 ORIGIN : FLIC TAPE NAME : 98637 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT : ARCO ALASKA INC, L1-31, LISBURNE, API #50-029-22860-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 99/01/18 ORIGIN : FLIC REEL NAME : 98637 CONTINUATION # : PREVIOUS REEL : COI~4ENT · ARCO ALASKA INC, L1-31, LISBURNE, API #50-029-22860-00
