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Home My WebLink About185-275Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or 'are viewable by direct inspection of the file. __[ _~ _~. ~ r~ ~ Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: Poor Quality Originals: Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: I~ ORGANIZED BY: BEVERLY BREN NOTES; VINCENT SHERYL MARIA LOWELL DATE; Project Proofing PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds Other IS/ I.,,E] Staff Proof By: Date: Is~ SCANNED BY: BEVERLY BREN VINCENT SHERY~LOWELL DATE; RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: lei General Notes or Comments about this file: Quality Checked (done) IIIIIIIIIIIIllllil R~l~TScanned.wp¢l STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG AUG 1 72004 Alaska Oil & Gas Cons. Commission r---- ~ RECEIVED 1a. Well Status: D Oil D Gas D Plugged II Abandoned D Suspended DWAG 1b. Well Clas8ncnorilge 20AAC 25.105 20AAC25.110 II Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 6/19/2004 185-275 304-221 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 11/12/1985 50- 029-21485-00-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 11/28/1985 PBU L2-21 1726' NSL, 1058' EWL, SEC. 18, T11N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 1229' NSL, 3915' WEL, SEC. 13, T11N, R14E, UM 52' Prudhoe Bay Field / Lisburne Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1368' NSL, 4506' WEL, SEC. 13, T11N, R14E, UM 11502 + 9397 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 692749 y- 5963620 Zone- ASP4 11550 + 9429 Ft ADL 028307 TPI: x- 687790 y- 5962998 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 687196 y- 5963122 Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost DYes II No N/A MSL 1900' (Approx.) 21. Logs Run: LDT / CNL / NGT, LSS / Waveforms / GR, DLL / MSFL / GR, EPT / ML / GR, CET, GR / CCL, GCT 22. CASING, LINER AND CEMENTING RECORD CASING NO 1W ,L \, ,AMOUNT SIZE WT. PER FT. GRADe TOP; " TOP ~ \\', '" PULLED 20" 91.5# H-40 Surface 119' Surface 119' 30" 1810 # Poleset 13-3/8" 68# / 72# K-55 / L-80 Surface 3687' Surface 3623' 17-1/2" ~500 sx AS III, 600 sx Class 'G' 9-5/8" 47# L-80 Surface 1 0630' Surface 8810' 12-1/4" 1126 sx Class 'G', 300 sx AS I 7" 29# L-80 10423' 11540' 8665' 9422' 8-1/2" 1450 sx Class 'G' 23. Perforations open to Production (MD + TVD of T~ and '",Ar,~¡ !,fi,~;,!,;,'.", ¡','iii ii,',; ",' i '," Bottom Interval, Size and Number; if none, state none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 2-7/8",6.5#, L-80 10927' - 10952' 10930' MD TVD MD TVD 2-7/8",6.5#, L-80 11090'-11122' 11090' 25.. AcID, FRACTURE. CEMENT SQuEEZE. ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10945' Set CIBP 10753' Set Whipstock 10753' P&A with 34 Bbls Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL-BeL GAs-McF WATER-BeL CHOKE SIZE GAS-OIL RATIO TEST PERIOD + Flow Tubing Casing Pressure CAlCULATED + OIL-BeL GAs-McF WATER-BeL OIL GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None 'fIJDMS BFl AU618 ìffO.. ORIGINAL ()r Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE r---- ~ 28. GEOLOGIC MARKERS 29. FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Wahoo Zone 6 10732' 8881' None Wahoo Zone 5 10838' 8954' Wahoo Zone 4 10952' 9032' Wahoo Zone 3 11226' 9213' Wahoo Zone 2 11318' 9273' Wahoo Zone 1 11392' 9322' RECE\VED AUG 11'[004 C mm\s.\on 0'\ & Gas Cons. 0 A\as~8 I Anchofap 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title 185-275 304-221 Technical Assistant Date PBU L2-21 Well Number Permit No. I A roval No, INSTRUCTIONS Prepared By N8melNum~r: Drilling Enginesr : Terrie Hubble, 564-4628 Mark Johnson, 564-5666 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Altemating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEMS: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00), ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None", ITEM 29: List all test information, If none, state "None", Form 10-407 Revised 12/2003 nD'~'~lð' Submit Original Only ~ ~. Well: Field: API: Permit: L2-21 A Prudhoe Bay Unit 50-029-21485-01-00 204-104 Accept: Spud: Release: Rig: 06/23/04 07/04/04 07/20/04 Nordic #2 PRE-RIG WORK 06/01/04 RAN 2.2 CENT & 1.75 SAMP BLR. FOUND PARAFIN @ 654'. RIG UP PUMP TRUCK. BRUSH & FLUSH WI 50 BBLS CRUDE @ 120 DEG. DRIFT WI 2" GAUGE RING, TAG BTM @ 11062' CORRECTED ELM. PERFS @ 10,734 -11,170' (328' OPEN, 108' OF FILL). RAN CALIPER FROM 10928' SLM, GOOD DATA. 06/16/04 RUN 1 112" TOOLSTRING. LOCATE TUBING TAIL @ 10924, +25" CORA. RUN SBHPS. STOPS @ 8806,8893, 8972,9062, SS, TAG FILL @ 11091 CORR DEPTH. SET 27/8" X-LOCK (W/O KEYS) CATCHER @ 10684' SLM, ATTEMPT TO PULL STATION # 6- LOCATE, SIT DOWN, BUT WILL NOT LATCH. 06/17/04 PULLED LGLV (5/16,1470#, RK) FROM STA #6 @ 10210' SLM. PULLED LGLV (1/4, BK) FROM STA #3 GLV @ 5578' SLM. SET 1" DGLV (BK) IN STATION #3 GLM @ 5577' SLM, LRS LOADED IA W/650 BBL. ATTEMPTED TO SET 1.5" DGLV (RK) IN STA # 6 @ 10210' SLM (DROPPED VALVE). ATTEMPTING TO RETRIEVE DROPPED DGL V FROM C-SUB. NOTE: C-SUB STILL IN HOLE WI POSSIBLE DROPPED 1,5" DGL V (RK). 06/18/04 PULLED DROPPED 1,5" DGLV (RK) FROM C-SUB @ 10661' SLM. SET 1.5" DGLV (RK) IN STA # 6 @ 10206' SLM. PERFORMED MIT ON IA (PASSED, SEE DATA FOR DETAILS). 06/19/04 PULLED 1.5" DGLV (RK) FROM STA # 6 @ 10207'SLM. PULLED 2718 X-LOCK C-SUB FROM 10684' SLM, NOTE: STA#6 @ 10207' LEFT EMPTY FOR CTD. SET CIBP 10946', CUT TUBING 10927', PUNCHED TUBING HOLES 10354'-10356'. CORRELATED TO PERF RECORD 7-FEB-04. WELL SHUT IN, SMALL WASH ON SEVERING HEAD AFTER CUT. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 6/23/2004 6/24/2004 ".--...., ~ Page 1 .. BP EXPLORATION Operations Summary Report L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Task Code NPT 04:00 - 06:00 From - To Hours P 06:00 - 07:45 07:45 - 08:10 08:10 - 08:45 08:45 - 12:15 12:15 - 15:45 15:45 - 16:05 16:05 - 18:00 18:00 - 19:00 19:00 - 23:00 23:00 - 00:00 00:00 - 01 :30 01 :30 - 03:00 03:00 - 06:00 06:00 - 07:15 07:15 - 14:30 14:30 - 14:45 14:45 - 16:10 16:10 - 17:00 17:00 - 19:00 19:00 - 22:00 2.00 MOB 1.75 MOB P 0.42 MOB 0.58 MOB 3.50 RIGU P P P 3,50 KILL P 0.33 BOPSUF P 1.92 BOPSUF P 1.00 BOPSUF P 4,00 BOPSUF P 1.00 BOPSUF P 1.50 BOPSUF P 1.50 BOPSUF P 3,00 BOPSUF P 1.25 BOPSUF P 7.25 BOPSUF P 0,25 PULL 1.42 PULL 0,83 PULL P P P 2,00 PULL P 3.00 PULL P Phase PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations Perpare to move from DS18-33A to L-21. Accept rig at 0600 hrs on 6/23/04 Move from DS18 to L2 pad. Set mat boards down around wellhead, Set spill dikes prepare to move onto well. IAP=TP=O, OAP=50 psi. SSV, MV, SV closed. Safety meeting prior to moving over well. Move rig over well. Set rig down over well. Rig up hard line to flowback tank. Set cuttings box. Fill pits with KCL. Install integral flange on companion valve, and jumper hose to cellar manifold to kill well. Pump down the tubing, taking returns thru bottom GLM with an empty pocket, backside open to take returns. Kick on pumps pumping 4 bpm, getting no returns. All fluid going into the formation, Pump 120 bbls to flush tubing. Swap to pumping down the lA, taking returns from the tubing. On line at 6.5 bpm, 830 psi. After 300 bbls away, started getting slight retums from the tubing. Pump 800 bbls down the IA. Swap back down the tubing pump an additional 100 bbls. Safety meeting Re: Setting BPV and NO tree. Set BPV, NO production tree. Install blanking plug in tbg hanger neck, RU kill line to 9-5/8 x tbg anulus. Fill hole with 35 bbls. Noted leaking sssv line through hanger. Cannot easily 'plug' leak mechanically, Install lower crossover flange, Pack top of tbg hanger with gel/water paste, Continue to NU bops. Pump 30 bbls every hour down tbg ann, Install variable, blind, annular and mud cross components. NU riser components. Silicone seal same. Inspect riser boot seals. COntinue to pump 30 bbls per hour down tbg ann. Continue to torque all connections on BOP equipment. Begin loading 3-1/2' PH-6 drill pipe into pipe shed. Drift & strap same. Bring Camco spooler in through pipe shed and spot on rig floor. MU hydraulic control lines to BOP components, Function test BOPs. Continue to load drill pipe, Pull mousehole. Hook up 2' line from charge pump to IA. Pump 30 bbls to fill lA, Continue to pump 15 bbls every 30 minutes to keep IA full. Pressure test BOP stack, Perform body test, pressure held like a rock, The gel on the tubing hanger worked great. Continue with BOP test. All passed ok. Pull FMC blanking plug out of profile in tubing hanger, Pull BPV from profile in tubing hanger. Pump a tubing volume to clear tubing prior to pulling tubing hanger. Pull tubing hanger to floor and lay down. RU to LD tubing, Begin spooling sssv lines, Small flow of diesel from tbg annulus. Complete loading 3rd layer of PH6 work string in pipe shed to facilitate rolling tubing to pipe elevator. Hold PJSM with night crew to discuss job, Lay down 2-7/8' 8rd EUE tbg, SSSV lines pulling ok. Recovered 70 of 72 stainless control line bands, Install thread Printed: 7120/2004 12:59:45 PM ,,--..... ~ BP EXPLORATION Page 2 t8 Operations Summary Report Legal Well Name: L2-21 Common Well Name: L2-21 Spud Date: 6/23/2004 Event Name: REENTER+COMPLETE Start: 6/23/2004 End: 7/20/2004 Contractor Name: NORDIC CALISTA Rig Release: 7/20/2004 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 6/24/2004 19:00 - 22:00 3.00 PULL P DECOMP protectors. Verify pipe is dry before placing on sills out on pad. Add displacement every 15 joints and an additional 20-25 bbls seawater every hour. Able to get fluid to surface, 22:00 - 00:00 2,00 PULL P DECOMP At sssv. RU to fill tbg and displace diesel from back side. Pump 1.5 bpm in/1.1 0 bpm out, 30-40 psi pump pressure. Take diesel rtns outside. 6/25/2004 00:00 - 01 :00 1,00 PULL P DECOMP Continue to circulate diesel & crude from tbg annulus. 2.0 bpm in /1.4 bpm out rate at 250 psi pump pressure. 01:00 - 01:30 0,50 PULL P DECOMP Shut down pump. Monitor well for flow, Remove SSSV. RD spooler, 01 :30 - 06:00 4,50 PULL P DECOMP Continue to POOH with 2-7/8" completion, Fill hole with seawater as required 06:00 - 10:20 4.33 PULL P DECOMP 200 joints of 2-7/8" DOH at 06:00, continuing to pull tubing / completion jewelry, Another 127 joints to go, 10:20 - 11 :30 1.17 FISH P DECOMP All 2-7/8" tubing recovered down to the PBR seal stem, All seals recovered on seal stem, it looks good. Layout recovered GLM's, and last of 2-7/8" production tubing. 11:30 - 15:30 4.00 FISH P DECOMP Load last 100 joints of 3-1/2" PH6 and strap, Load 164-3/4" drillcollars and fishing BHA. 15:30 - 16:00 0.50 FISH P DECOMP Set wear bushing. 16:00 - 16:15 0.25 FISH P DECOMP Safety meeting pre making up fishing BHA. Found wrong size wear bushing in hole for packer we are fishing, Tool Service inspected all completion equipment for norm. None found. 16:15 - 17:15 1.00 FISH N HMAN DECOMP Contact FMC. Get a full bore wear bushing brought out to rig. Standby on hand & wear bushing. 17:15 - 17:30 0.25 FISH N HMAN DECOMP Retrieve first wear ring. Set new wear bushing, RILDS. 17:30 - 17:40 0.17 FISH P DECOMP Safety meeting re: BHA. 17:40 - 18:45 1.08 FISH P DECOMP RU floor to make up Fishing BHA #1 (spear, collars, jars, accel) 18:45 - 19:00 0.25 FISH P DECOMP Hold PJSM with night crew regarding plan forward & BHA handling. 19:00 - 22:00 3.00 FISH P DECOMP MU spear, 164-3/4" drill collars, jars & accel. 22:00 - 00:00 2.00 FISH P DECOMP PU 3-1/2" PH6 singles from pipe shed. Drift each joint while picking up. Fill hole every 1 hr with +/- 30 bbls seawater. 6/26/2004 00:00 - 02:00 2,00 FISH P DECOMP Kelly up at 50 stands. Tighten same. 02:00 - 02:30 0,50 FISH P DECOMP Circulate 2 dp volumes to ensure rust & scale are cleared. Stand back kelly. 02:30 - 06:00 3.50 FISH P DECOMP Continue to pick up 3-1/2" PH6 singles from pipe shed, with fishing BHA#1 (spear), Continue to fill hole every hour, taking +/- 30 bbls per fill. 06:00 - 09:00 3.00 FISH P DECOMP Continue to PU 3-1/2" PH6 workstring in singles from pipe shed. Dropping a drift thru every joint. 135 jts run, 175 jts to go. IAP=O, OAP=O, Pit vol=330 bbls, Filling the hole 30 bbls/hr by pumping accross the top. Pumping 1.5 DPV down the pipe every 50 joints to flush rust etc out. 09:00 - 11:00 2.00 FISH P DECOMP 200 Joints in, 112 to go, Fill the DP with 1.5x volume, 11 :00. 13:30 2.50 FISH P DECOMP 250 Joints in, 62 to go. Fill the DP with 1.5x volume. 13:30 - 14:00 0,50 FISH P DECOMP Pick up Kelly, 14:00 - 14:25 0.42 FISH P DECOMP Check weights. PU=147klbs, slack off=105 klbs, Circulation pressures are 1270 psi at 3 bpm, 645 psi at 2,0 bpm, Slack off and engage fish. PU to 210 klbs jar 2 licks. PU to 230 klbs jar 1 lick. PU to 250 klbs jar 1 lick. Stack 10 klbs, and PU with fish moving at 25 klbs over. Engaged fish at 10312' DPM. Printed: 7120/2004 12:59:45 PM r---- ~ BPEXPLORA TION Page 3 8a Operations Summary Report Legal Well Name: L2-21 Common Well Name: L2-21 Spud Date: 6/23/2004 Event Name: REENTER+COMPLETE Start: 6/23/2004 End: 7/20/2004 Contractor Name: NORDIC CALISTA Rig Release: 7/20/2004 Rig Name: NORDIC 2 Rig Number: N2 Date From - To Hours Task Code NPT Phase Description of Operations 6/26/2004 14:00 - 14:25 0.42 FISH P DECOMP Pulled up hole 20'. 14:25 - 18:30 4.08 FISH P DECOMP Circulate bottoms up prior to pulling fish to surface. 18:30 - 18:45 0.25 FISH P DECOMP Shut down pump. Monitor well for flow, Hold PJSM to review job assignments & sim ops while tripping out of hole. 18:45 - 00:00 5.25 FISH P DECOMP Stand back kelly. PU H-YT elevators. POOH. Having to pull very slow due to swabbing. (2-3 min per double). Load pipe shed with 4-1/2' IBT-M pipe. Drift and strap same for completion, Stage completion jewelry on location. 6/27/2004 00:00 - 06:00 6.00 FISH P DECOMP Continue to POOH with straddle fish, Well continues to swab. Pulling very slow. 06:00 - 06:45 0,75 FISH P DECOMP Crew change and PJSM prior to breaking down BHA. 06:45 - 07:30 0.75 FISH P DECOMP Stand back 8 stands of drill collars. lay down jars and bumper sub. 07:30-11:15 3.75 FISH P DECOMP Lay down fish, including; spear, 9-5/8' packer, 2-7/8' tubing, blast joints and chemical cut pup joint. All recovered ok. Found 2 missing control line bands on top of 9-5/8' packer. Found 9 perf holes in first full joint of 2-7/8' tubing below the packer. Found top 18" of the 4' chemical cut pump joint on bottom of the last blast joint. All rubber elements recovered off of packer. All is as expected. 11:15-14:30 3,25 CLEAN P DECOMP Make up BHA #2, 7' & 9-5/8' casing scrapers to clean casing for completion, 14:30 - 18:00 3,50 CLEAN P DECOMP Trip in hole with 3-1/2' PH-6 work string. 18:00 - 18:30 0.50 CLEAN P DECOMP Crew change out and PJSM to discuss operations, 18:30 - 22:30 4.00 CLEAN P DECOMP Continue to RIH with tandem csg scrapers on PH-6 workstring. Well still taking 30 bph. Switch to 2%KCL water. Seawater plant is tied up loading water for Nabors 7ES, 22:30 - 00:00 1.50 CLEAN P DECOMP Continue to RIH. Load additional 19 jts PH6 in pipe shed for BHA. Drift & strap same. 6/28/2004 00:00 - 00:30 0,50 CLEAN P DECOMP Reach TD of 10801' with 7' csg scraper, 10,373' with 9-5/8' scraper (25' in on jt #328). Did not see top of liner, or any sign of junk etc. 110K# dn wt, 00:30 - 02:00 1.50 CLEAN P DECOMP POOH. LD PH6 work string. 02:00 - 03:00 1,00 CLEAN N RREP DECOMP Rig tongs sprung a hydraulic leak. Replace hose, 03:00 - 04:00 1,00 CLEAN P DECOMP Unload singles from pipe shed, 04:00 - 06:00 2,00 CLEAN P DECOMP Continue to POOH and lay down singles. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew change and safety meeting with day tour prior to continuing to pull pipe out of the hole. Discuss operations forward, including Simops with pulling pipe, and rolling pipe out of pipe shed, Discuss 2 new individuals on rig today. Discuss the fact that anyone can shut down the job at any time, and should do so if they see any kind of safety issue that should be discussed. 06:30 - 11 :00 4.50 CLEAN P DECOMP Continue to POOH and lay down singles. 100 joints ooH at 06:30, Total run in string was 328. 228 to go, 11 :00 - 15:30 4.50 CLEAN P DECOMP 208 joints ooH at 11 :00, 120 to go. 15:30 - 15:50 0.33 CLEAN P DECOMP All PH-6 ooH. Hold rig evacuation drill. Simulated fire in the manifold building behind the rig, The well was secured, and all rig hands, including the derrick hand from the derrick, the fishing hand from the rig floor, and the vac truck driver from the back side of the rig were at the muster area in 2 minutes, Good response by all hands. 15:50 - 19:00 3,17 CLEAN P DECOMP Lay down fishing BHA; drill collars, scrapers, junk mill over Printed: 712012004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: r"' ~ Page 4 - BP EXPLORATION Operations Summary Report L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 6/28/2004 Date' From - To Hours Task Code NPT 15:50 - 19:00 19:00 - 23:00 23:00 - 23:15 23:15 - 00:00 6/29/2004 00:00 - 06:00 06:00 - 06:15 06:15 - 09:45 09:45 - 10:45 10:45 - 15:00 15:00 - 17:00 17:00 - 19:00 19:00 - 19:45 19:45 - 00:00 6/30/2004 00:00 - 03:00 03:00 - 03:45 03:45 - 04:15 04:15 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 12:30 12:30 - 14:30 14:30 - 16:30 16:30 - 20:00 20:00 - 23:00 3,17 CLEAN P 4,00 RuNcmfp 0.25 RuNcmfP 0.75 RuNcmfp 6.00 RuNcmfP 0.25 RuNcmfp 3,50 RuNcmfP 1.00 RUNcm p 4,25 RUNCO' p 2,00 RUNcm p 2,00 RUNCOI p 0.75 RUNcm p 4.25 RUNcm p 3,00 RUNCO',p 0.75 RUNCOlfp 0.50 BOPSUF P 4,25 BOPSUF P 1,00 BOPSUF P 1,00 BOPSUF P 2,00 BOPSUF P 2,00 BOPSUF P 2.00 BOPSUF P 3.50 BOPSUF P 3.00 BOPSUF N Phase DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP SFAL RUNCMP Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations completion in pipe shed. Load remaining 4-1/2" tbg into pipe shed (42 jts), Drift & strap same. Load completion jewelry into pipe shed, RU floor to run tbg. Hold PJSM with crew to discuss running completion. Discuss hazards, job assignments, running order. MU 4-1/2', L-80, IBT-M tbg completion with jewelry. Find average torque to mark on threads 0 first 7 jts, Use to mu rest of pipe. pipe. Continue to MU and run 4-1/2' , L-80, IBT-M tbg completion, Shut down for crew change, Continue to run 4-1/2" completion. On joint 137 at 06:00. Going to joint 250, At top of joint 198, Install HES CP2 TRSV, Bring HES control line spooler into rig. RU same. Attach control line and PT. All looks good. Continue running 4-1/2' tubing, Installing 1 stainless steel control line clamp per joint. MU FMC tubing hanger and TClllanding joint. Install sssv control line, Pressure test same to 5000 psi. Land tubing, Verify visually, RILDS. RD floor. Clear pipe shed. MU coil BOPS outside cellar. Mix corrosion inhibitor in vac truck and in pits. Continue filling hole every hour MIRU LRS w/ dead crude onboard to IA Safety mtg re: displ annulus PT LRS @ 2500 psi. Displ annulus w/ 435 bbls SW w/ 25 gal/100 bbl Corexit heated to 130F at 2.5/500 while taking avg 2.0 bpm retums thru tubing. Displ w/135 bbls dead crude for FP, SIIA w/250 psi. RDMO LRS Drop ball on rod and wait to fall. RU kill line to IA Tee, IA 90, OA 176, Pressure tubing to 4000 psi with 2.8 bbls and monitor IA 190, OA 177 for 30 min, Final pressures 3970 psi, IA 153, OA 178. Bleed tubing to 1650 psi. Pressure IA to 3485 psi w/ 8.1 bbls and tubing rose to 2180 psi and held, IA bled to 3390 in 30 min, OA 177. Bleed IA down to 500 psi and tubing bled to 1650 psi. Bleed tubing to zero LD landing jt. Close TRSSSV, RD spooling unit and load out Dry stick TWC ND riser and load out. ND 13-5/8' BOPE. Remove BOP components from cellar, Load out used completion equipment, excess 2-7/8 liner, misc items to stores. Place 7-1/16' BOPs in cellar. Secure and suspend from bridge crane. NU tubing head adapter flange with FMC hand. Install SSSV line connection, Test both, NU tree. Test tubing head adapter to 5000 psi. Test tree valves to 5000 psi. Ok. RU lubricator to 4-1/2' tre, DSM valve crew pull TWC from hanger. NU 7-1/16' BOPs. Install mousehole Fill stacklPT and leaked at Hydril to blind/shear flange, Retighten and retest several times w/o success, The lifting Printed: 712012004 12:59:45 PM /"'"' ~ BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Phase Task Code NPT 6/30/2004 3.00 BOPSUF N SFAL RUNCMP 20:00 - 23:00 7/1/2004 23:00 - 00:00 00:00 - 03:00 1,00 BOPSUF P 3,00 BOPSUF P RUNCMP RUNCMP 03:00 - 04:00 1.00 BOPSUF P RUNCMP 04:00 - 11:00 7,00 BOPSUF P RUNCMP 11:00-11:15 0.25 RUNcm p 1.00 RUNcm p 1,75 RUNcm p RUNCMP RUNCMP RUNCMP 11:15-12:15 12:15 - 14:00 14:00 - 16:00 2,00 RUNcm p RUNCMP Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Page 5 48 Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations plate is hindering makeup of nuts, The individual BOP components had just been annually inspected and new seal rings installed, Remove annular and inspect seal ring and groove, Remove R46 seal ring and install a RX46 (raised profile) seal ring (which are installed in all other BOP breaks). Retest to 4000 psi RU to PT tubing and IA. Reboot OS PC Pressure test tree cap to 4000 psi prior to repressure test tubing and IA Time Tubing P lAP CAP 0003 0 100 172 0025 0 88 172 valves-begin pump dn tbg 0027 3490 221 172 4385 Begin 30 min test after 2.3 bbls pumped Appears control line pressure is tracking-discuss wI FMC, PE's 0055 3450 222 225 4390 End of tubing test. Bleed off pressure 0106 0 192 225 4040 After tubing bled off and pressures stable Bled back less than 1 bbl-suspect flapper may have shut 0113 0 192 225 0 Intentionally bleed TRSSSVp to zero to chk CL integrity 0120 4000 237 225 35 After repress tubing to 4000 psi wI 0.9 bbls WO OSO to open TRSSSV 0207 3973 233 225 28 End of test-OSO needs 2500 psi over well press to open flapper-find higher rated gauge 0235 4003 228 225 off tbg press slow 0251 0 72 222 OSO left 4735 psi on CL Pressure tubing to 1500 psi 0303 1510 122 222 3500 psi 0308 1600 0311 1825 0313 2040 min test 0343 2040 0348 1534 0355 0 started SI master and swab. PJSM. Install test joint. Begin initial BOPE test wI AOGCC inspector on site, Rebuild leaking kill line valve, Spot SLB slickline unit. Hold PJSM with crews to discuss s-line rig up, procedures, hazards. RU slick line, Bring tools to floor. RIH. Recover ball& rod assembly. POOH. LO same, Well now taking 60 bph seawater. MU next tool string. RIH to recover RHC profile sub. POOH, 700 223 2250 236 3505 247 3445 250 250 227 222 226 TRSSSVp Comment 4027 Initial conditions 1850 After open tree 6500 Flapper opened, bleed 4735 Bled back 1.8 bbls. 4865 Begin pressure IA to 4980 After 1.6 bbls 4999 After 4,3 bbls 5475 After 7.7 bbls, Begin 30 5460 Bleed off IA to 200 psi 4855 Bleed off tubing to zero 4785 Back to where we Printed: 712012004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 7/1/2004 7/2/2004 r---- ----.., Page 6 .. BP EXPLORATION Operations Summary Report L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Task Code NPT 16:00 - 21 :45 From - To Hours 5.75 CLEAN P Date 21:45-22:15 22:15 - 22:30 22:30 - 00:00 00:00 - 02:30 02:30 - 03:35 03:35 - 04:45 04:45 - 06:30 06:30 - 08:00 08:00 - 09:00 09:00 - 09:45 09:45 - 12:30 12:30 - 14:45 14:45 - 15:15 15:15 - 17:15 17:15 - 18:00 18:00 - 18:15 18:15 - 19:15 19:15 - 20:15 20:15 - 20:55 20:55 - 23:15 0.50 CLEAN P 0.25 WHIP P 1.50 WHIP P 2,50 WHIP P 1.08 WHIP 1.17 WHIP N N 1.75 WHIP N 1,50 WHIP P 1.00 WHIP P 0.75 WHIP P 2,75 ZONISO P 2.25 ZONISO P 0.50 ZONISO P 2.00 ZONISO P 0.75 ZONISO P 0.25 ZONISO P 1.00 ZONISO P 1.00 ZONISO P 0,67 ZONISO P 2.33 ZONISO P Phase WEXIT WEXIT WEXIT WEXIT WEXIT DFAL WEXIT DFAL WEXIT DFAL WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations MU 3.625" dummy WS drift tool string. RIH to 10800', clean. POOH. Slow run due to fluid packed well bore and large 00. Fill across top at 33 bbls/hr LD dummy WS assy, RDMO SWS slickline Safety mtg re: MU WS assy on eline Load BTT Gen II WS and SWS eline tools to floor and RU. Check p~s tool orientation. Load 2 RA pips in WS, MU WS to running tools RIH wI WS on eline to 10800'. Log tie-in to PDC log and attempt to set WS wI top at 10753' wlo success POOH w/WS Found slo-burn fuse started the burn, but ignitor pellet did not finish. Chk WS, okay. Install another #10 slo-burn charge, MU to same WS RIH wI WS on eline to 10800'. Log tie-in, Set packer. Verify did not fall down hole, Log GRlCCL jewelry log from TOW to first GLM to determine ELM tbg tail etc. Pull out of hole with e-line tools RD SLB e-line equipment. Stab coil in to injector. Head up with dart catcher. RU to pump dart through e-free coil. Pump Baker 2-3/8" dart through reel. After 70 bbls, nver saw it hit dart catcher. Pump 2nd dart. First dart found, 2nd dart hit after 70 bbls. Replace dart catcher with small id xo, Dart hit after 53.9 bbls. MU coil connector, Pressure & pull test same, MU cementing nozzle on stinger. Get on well. Call for cementers. RIH. RU cementers. Hold PJSM while RIH, Discuss hazards, pump schedule, roles & respons, clean up, Tag WS and correct coil depth to 10757'. Flag pipe and PU 10'. Shut in well. Pump injectivity test: 245 psi WHP @ 1.0 bpm, Begin mixing cement. Fill lines with water. Pressure test lines to 4000 psi. OS load CT w/5 bbls neat, 20 bbls wI 15#/bbl agg, 9 bbls neat G cement at 15.8 ppg at 2.5/1.7/2000, IA 400, OA 275 Displace wI rig KCI. Park at 10743'. With 3,7 bbls above noz and 2.4/1.4/400 start PUH at 4'/min 53k and close choke, Red rate to 1,5/200 after 10 bbls cement out and WHP slowly rising to 150 psi. With 14 bbls left and no further incr in WHP, bleed off press to zero. Returns initially were about 1/1, but then declined to 1.010.31130 at 25'/min while fin displ the rest of cement while PUH in tubing, Last bbl out noz at 10350' (WCTOC) Total retums were 10 bbls, TT 5:00 @ 80 ml, CIP 1915 hrs. PUH to safety Park at 10000', Swap to 40 bbls 1.5# bio water and circ 0.3010.22/40 while wo cement to settle SI choke and apply 100 psi wI 1.4 bbls which bled to 50 psi in two minutes and held for 15 min. Increase to 150 psi WHP wI 0,9 bbls and bled to 60 psi in 10 min and to 40 psi in 20 min. Bleed off 30 psi and open choke Fire in motor room drill Fin circ biozan to nozzle 2,612,611560 while RIH to WCTOC, Printed: 712012004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 71212004 713/2004 7/4/2004 r" --.... Page 7 .. BP EXPLORATION Operations Summary Report L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 20:55 - 23:15 From - To Hours 2.33 ZONISO P 23:15 - 23:35 23:35 - 00:00 00:00 - 00:30 00:30 - 02:15 02:15 - 03:15 03:15 - 06:00 06:00 - 10:00 10:00 - 14:00 14:00 - 15:00 15:00 - 15:15 15:15 - 17:15 17:15 - 18:15 18:15 - 18:30 18:30 - 19:45 19:45 - 19:55 19:55 - 22:25 22:25 - 23:30 23:30 - 00:00 00:00 - 02:15 02:15 - 03:00 03:00 - 03:30 03:30 - 05:00 05:00 - 05:50 05:50 - 06:00 06:00 - 06:50 06:50 - 07:45 Task Code NPT 0,33 ZONISO P 0.42 STWHIP P 0.50 STWHIP P 1.75 STWHIP P 1.00 STWHIP P 2.75 STWHIP P 4.00 STWHIP P 4,00 STWHIP P 1.00 STWHIP P 0,25 STWHIP P 2.00 STWHIP P 1.00 STWHIP P 0,25 DRILL 1,25 DRILL P P 0.17 DRILL 2.50 DRILL P P 1.08 DRILL P 0.50 DRILL 2.25 DRILL 0.75 DRILL 0.50 DRILL P P P P 1.50 DRILL 0,83 DRILL N P DPRB PROD1 PROD1 0.17 DRILL 0.83 DRILL 0.92 DRILL Phase WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 N P P SFAL PROD1 PROD1 PROD1 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations Jet and dilute cement to 10700' (top perf at 10734') 2.8/2.8/1850. Jet remainder of bio water then KCI 3.25/2450 while POOH jetting across jewelry. Dump 80 bbls of dirty water wI max density of 8.7 ppg LD cement stinger. Jet stack wI swizzle stick Cut off CTC, Install BTT CTC. PT 35k, 3500 psi MU milling BHA RIH wI BHA #3 (3,80' window mill, 3.80' SA) 10680' start motor 2,7/2.7/1450. RIH looking for cement at 10700' (ELMD). RIH at 60'/hr after 50 psi incr in diff at 10733' CTD (prior corr was -18'), PVT 310 Wt chk at 10745' 42k 2,7/2,7/1450 Drill cement wI 100 psi diff 60'/hr from 10745' to 10768,6' and stall-assume pinch point. PUH 43k. RIH to first motor work at 10768.2' 2,7/1340 (adding biozan), Corrto 10757.6' and flag Mill window from 10757.6' 2,7/1340 per BTT instructions at 0.1'/5 min PVT 310 Mill window to 10764.5 '2,7/1340 per BTT instructions at 0.1'/5 min PVT 308 ROP has slowed, should be mostly in formation. Mill window to 10769 '2.7/1850 per BTT instructions at 0,1 '/5 min PVT 308. ROP has slowed, should be mostly in formation. Motor work 600-800 psi. Mill window to 10765.5' 2.7/1340 per BTT instructions at 0.1 '/5 min PVT 308. ROP increased at 10769'. Mill formation to 10775.4', Back ream window to dress same. Run through dry. Looks smooth, TOW: 10757,6', BOW 10765,5'. POOH to swap reels & BHA, Paint EOP flag at 10547'. Continue to circ out of hole. At surface get off well. LD milling BHA. 3 miles of caribou. . . Safety mtg re: N2 blowdown PT DS N2 lines. Blowdown reel wI N2 and bleed off Cut off CTC Safety mtg re: pull CT back Install internal grapple and PT. Pull CT back to reel and secure, Open bombay doors and load out e-free CT, Load in E-CT. Install intemal grapple and PT. Pull CT to injector and stab Install temporary CTC and stab onto lub, Fill CT wI KCI and reverse slack back Cut off 140' CT to find eline Prep eline and test. Install Kendall CTC MU drilling BHA RIH wI BHA #4 (2.7 deg/M09X) pumping thru EDC 1,75/750 Tag up on TRSSSV at 2211' CTD (CL shows 3800 psi, should be open), Orienting didn't work either WO DSO to cycle TRSSSV Work for 10 min and get thru SSSV-assume big bend motor and square shoulder bit are catching profile, Continue RIH Park at 6000' to replace packoff Continue to RIH. Log initial gr tie in from 10655' to 10737', Correlate with WS Printed: 712012004 12:59:45 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ,-..... ~ BP EXPLORATION Operations Summary Report L2-21 L2-21 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 6/23/2004 Rig Release: 7/20/2004 Rig Number: N2 7/4/2004 06:50 - 07:45 From - To Hours Task Code NPT Phase p Date Page 8 - Spud Date: 6/23/2004 End: 7/20/2004 Description of Operations 0.92 DRILL PROD1 setting record/jewelry log (7/2/04), which was tied into orginal Litho-Density log from parent well. -18' correction. 42K# up, 18K# dn wi. ( STATE OF ALASKA f ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 VJ6/f- k'¡iOIl-(~c4- (/)cIj b//Ò/ cJ- 1. Type of Request: 1m Abandon 0 Suspend 0 Operation Shutdown 0 Perforate 0 Waiver 0 Alter Casing 0 Repair Well 1m Plug Perforations 0 Stimulate 0 Time Extension 0 Change Approved Program 0 Pull Tubing 0 Perforate New Pool 0 Re-Enter Suspended Well 0 Annular Disposal 0 Other 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 4. Current Well Class: iii Development / D Exploratory D Stratigraphic Test D Service 5. Permit To Drill Number 185-275 / 6. API Number: / 50- 029-21485-00-00 99519-6612 52' 9. Well Name and Number: PBU L2-21 / 8. Property Designation: 10. Field / Pool(s): ADL 028307 Prudhoe Bay Field / Lisburne Pool ,I?RES~NT,vYE~L,CONDrnON$UMMARY' " Tot"",a, "I" D""ep", t,h, TV", D, , (ft" ),: l,E,ff, ",e",ct,i,V, ,e" ,',D, e"p,t,h"",M, D, (ft),:,I,Eff, ect,i,v, e Depth TVD (ft): Plugs (m, e" 'a, "s, ,Ured): 9429 11502 9397 11110 LE;)ngth' , ' , "Siz~ " " ,MD ,', Burst' 11- Total Depth MD (ft): 11550 Gàsing , Structural Conductor Surface Intermediate Production Liner Junk (measured): None , CóUaþsê 119' 20" 119' 119' 1490 470 3687' 13-3/8" 3687' 3623' 3450 1950 10630' 9-5/8" 10630' 8810' 6870 4760 1117' 7" 10423' - 11540' 8665' - 9422' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: 10734' -11170' 8882' - 9177' 2-7/8",6.5# Packers and SSSV Type: 7" x 2-7/8" Brown 'I-B' packer; 7" x 2-7/8" Brown 'I-B' packer; 9-5/8" x 2-7/8" 'HB' packer; 2-7/8" Cameo 'Tl;lnO_1 A' ~~~\I Tubing Grade: Tubing MD (ft): L-80 10952' & 11090' - 11122' Packers and SSSV MD (ft): 11090'; 10930'; 10342'; 2178' 12. Attachments: iii Description Summary of Proposal D BOP Sketch D Detailed Operations Program 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name T ed~ta g Title CT Drilling Engineer ~i~~,~tu~~,~Z4."", """""""" ",~hone, "" ~6~~694 , '"."",.',i'i.,'".,".'<i'.'.,i,'.'..".,"".'.., .',.."','.'/i,"'.i,i,\/,i\'i'" "i',','.\, " " ,çgmlj'l.$'~ic)h>(J,'$"O"'ý: " 13. Well Class after proposed work: I D Exploratory iii Development D Service June 16, 2004 Date: 15. Well Status after proposed work: DOil DGas DWAG DGINJ D Plugged DWINJ ( all Abandoned D WDSPL Contact Ted Stagg, 564-4694 Conditions of approval: Notify Commission so that a representative may witness :.. k L Prepared By Name/Number: ~~~Š::!'r:t:~.)!'!'~. Terrie Hubble, 564-4628 ", " I SU~dry Number: ,36Jj. ;)-;)-1 D Plug Integrity D BOP Test D Mechanical Integrity Test r~I~1 [- ('" E ~ \)'Ffm D "'( t: ~.I ....., ~ ~4:::' ,',,0$ 40 ( r e ð vcÙ,d ~) y ~ ¡ Jdvt'<: ~ J~d ~ 2iJ~ ~ 2-/ Æ- , p! f I D Location Clearance Other: Af f ro (j ~/J Ç-o l'I-1/"- I 0'-. T-tst- ßo~E t:}r;oo " '1 ~efl JU~ \ 4 Iouflaska Oil & Gas Cons. BY ORDER OF COMMISSIONER THE COMMISSION Date ~ét:iæt~ ORIGINAL ( ( ..~bp "i;~" To: Winton Aubert Sr. Petroleum Engineer Alaska Oil & Gas Conservation Commission From: Danny Kara CTD Engineer Date: June 7,2004 Re: CTD Tubing Swap and Sidetrack of Lisburne Well L2-21 Lisburne Well L2-21 is scheduled for a through-tubing sidetrack with coiled tubing. Prior to CTD sidetracking, /' the perfs below 10965' will be permanen;!y isolated with a cast iron bridge plug. The 2-7/8" production tubing will be replaced with 4-1/2" L-80 tubing. The sidetrack, L2-21A, will kick off from a window milled off a /" mechanical whipstock. The whipstock will be cemented in place, simultaneously abandoning the 10734' -' 10920' perforations. The following describes work planned to prepare L2-21 for sidetracking and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed tubing swap and sidetrack is attached for reference. 1. MIT inner annulus to 3000 psi. / 2. Caliper 2-7/8" production tubing 3. Install cast iron bridge plug at ~ 1 0,940' ELM. 4. Jet cut 2-7/8" tubing in pup joint at ~ 10,927' ELM. 5. Circulate well over to kill weight fluid . 6. RU Nordic 2 with II" BOPE. Test stack. / 7. Pull 2-7/8" L-80 tubing. / / 8. RIH to retrieve packer/blast joints down to jet cut. / 9. Complete well with 4-1/2" 12.6# L-80 IBT-M tubing with new packer. 10. PT completion. RD II" BOPE. NU tree and 7-1/16" CTD BOPE. Test. / 11. Install whipstock at 10735' ELM. . 12. Pump' cement to secure whipstock and isolate straddle perforations from 10734' -10920'. /' 13. CO!1ti~e forward with CTD win, d,O, w milling and",open hole drilling, as detailed in the Permit to Dnll. ¡ I L ¡ /,~ .' ''''''''''-\"" 2. S 60 s ~ l.;1¡ï, ,,/"'''',)1 We would like to begin the prep work operations bYlf~ne ,,16: 2004. Please let me know if I can provide you with additfel:Jfíformation. /' ~.;.,t:5irÞ-~ Dan Kara CTD Drilling Engineer cc: Well File Terrie Hubble TREE = WRLH6A. D = ACTlJ6. TOR = KB. a.EV = SF. a.EV = KOP= Wax Angle = Datum tv[) = Datum TVD = --_? FWC AXELSON 52' L2-21 2775' 50 @ 11200' 10691' 88OO'SS Ct - - CL - 113-318" CSG, 72#, L-80. 10= 12.347" H 3687' ~ L Minimum ID = 2.25911 @ 10694' AVABPL NIPPLE L z ITOPOF7" LNR H 10423' 1 I 1 9-5/8" CSG, 47#, L-80. ID = 8.681" 1-1 1 0629' ~ ... d ~' .... z 1 2-7/8" TBG-PC, 6.5#, L-80, .00579 bpf, ID = 2.441" 1-1 10952' 1 // J \ ÆRFORA TON SUfvIv1ARY REF LOG: LDT/Cf\l. ON 11/29/85 ANGLE AT TOP PERF: 46 @ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTffiV AL Opn/Sqz DA TE 4" 4 10734- 10814 0 04/14/86 4" 4 10842 - 10920 0 04114/86 2-1/8" 6 10965 - 10975 0 02107/04 2" 4 10968 - 11075 0 10/09/87 2-1/8" 6 11006-11016 0 02107/04 2-1/8" 6 11042 - 11062 0 02107/04 4" 4 11122 - 11170 0 04/14/86 I 1 R3TD H 11502' 1 1 7" Lf\R. 29#, L-80, .0371 bpf, D = 6.184" H 11550' 1 ~ QA. TE REV BY COfvlv18'JTS 11/28/85 ORIGINAL COM PLETION 11¡Q5,Q1 RNI1P CORRB:;TONS 06/16,03 Ctv1QI1LP MAX ANGLE OORRECfION 02¡Q7¡Q4 MJA/KK ACPERFS 02121,04 MDCI1LP PFS SllM l1JBES SHOT DA TE REV BY ( SAFETY NOTES: CAT I-SSSV, H2S 75 (PPM) 2178' H2-7/8" CAWCOTRDP-1A SSSV,ID == 2.312" 1 a;8\.1ICA L MANDRELS ISTI MD INDI ŒVI TYÆ I VLV I LATCH I PORTI 1 2234 2234 0 KBWG DV BK-2 ¿ GAS LFT M\t-DRELS .. ST MD NO ŒV TYÆ VLV LATCH 2 2804 2801 11 MG-FM-IO DV BK-2 3 5615 5063 42 MG-FM-IO DOWE BK-2 4 7863 6743 40 MG-FM-IO DV BK-2 5 9458 7973 43 MG-FM-IO DV BK-2 6 10244 8538 44 MG-FM-IO DOWE RK PRODUCllON MANDRa.S ISTI MD INDI ŒVI TYÆ I VLV ILATCHI PORTI 7 10641 8817 43 MG-FM-IO DV BK-2 DA.TEI 11/85 PORT DA. TE 11/11191 1/4 11/11191 11/85 11/85 5/16 11/11191 OA.TE 11/85 z 1 10342' H 9-518" X 2-7/8" BROWN f-B A<R I I 10694' 1-12-718" AV A BA... NIP W/O SL V, 10 = 2.259" 1 10728' 1-12-718" BROWN BLAST JOINTS 1 10930' 1-17' X 2-7/8" BROWN I-B A<R 1 / 110965'-10975'I-1PFS SllM l1JBE SHOT 02121/04 I 1 10952' 1-12-718" l1JBING TAIL W/ WLEG 1 1 10949' H a.rvo TT LOGGED 07/27/86 1 111006-11016' HPFS SllM l1JBE SHOT 02121/04 1 111042-11 057'..,PFS SllM l1JBE SHOT 02121/04 1 1 11090' l-i 7' X 2- 7/8" BROWN I-B A<R I 1 11110' H2-718"CAMDNIP,W/A...UG I ANDSANDCOVffiING PLUG 1 11122' H2-7/8" CAWCOTLBINGTAIL I I 11122' 1-1 a.M) TT LOGGED 04/15/86 I COMWENTS LlSBURNEUNrT WELL: l2-21 PffiMT~: 1852750 API~: 50-029-21 485-00 SEC 18, T11 N, R15E. 4503.47' ÆL & 390828' FNL BP Exploration (Alas ka) " I ( ( L2-21A Proposed Sidetrack Completion I Uppermost perfs to be cement squeezed after setting whipstock ~/ TO-12,167' """"",""',' ., ""',.~""""""',. 3 3/16" Slotted Liner I 00000000000001 ':,::;;'::!,''';''\\;::;:i!?,:¡! ')::\',:\,: I 0 q 2-7 ¡:',;:;,::",~':',i:,,'::,::;~ 1 10930' 1-17" x 2-7/8" BROWN ~B A<R I >< /' 1 10952' 1-12-7/8" TUBING TAIL W/ WLEG 1 I '\ I 10949' 1-1 aMD TT LOGGED 07/27/86 1 110965'.10975'1-1 PFS STIM TUBE SHOT 02/21/04 I 1 11006-11016'I-IPFS STIM TUBE SHOT 02/21/04 1 I 11042-11057'I-IPFS STIM TUBE SHOT 02/21/04 I 8 113-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 3687' r--JI L I TOP OF 7" LNR 1-1 10423' 1 ~ ~ Z I 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10629' 1 ~ 4 1/2" tailpipe - 10,640' 4 1/2" x 7" whipstock @ 10,755' Cut CIBP to isolate existing perfkoq,4.0 12-7/8" TBG-I~, 6.5#, L-80, .00579 bpf, ID = 2.441" 1-1 10952' I ÆRFORA TION SUMMARY REF LOG: LDT/CNL ON 11/29/85 ANGLEATTOPÆRF: 46 @ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 4 10734 - 10814 0 04/14/86 4" 4 10842 - 10920 0 04/14/86 2-1/8" 6 1 0965 - 1 0975 0 02/07/04 2" 4 10968 - 11075 0 10/09/87 2-1/8" 6 11006 - 11016 0 02/07/04 2-1/8" 6 11042 - 11062 0 02/07/04 4" 4 11122-11170 0 04/14/86 I I PSTD 1-1 11502' I 1 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 11550' 1 DA TE REV BY COMMENTS 11/28/85 ORIGINAL COM PLETION 11/05/01 RN/TP CORRECTIONS 06/16/03 CMOrrLP MAX ANGLE CORRECTION 02/07/04 MJA/KK ADPERFS 02/21/04 MDC'TLP PFS STIM TUBES SHOT DA TE REV BY COMMENTS SAFETY NOTES: CAT I-SSSV. H2S 75 (PPM) 2178' 1-14 1/2" TRSSSV, 10 = 3.812" ~ 4 GLM'S 4 1/2" X 9 5/8" Packer -10,360' / /~ ~ I 11090' 1-17" x 2-7/8" BROWN ~B PKR I 1 11110' Jî2-7/8"CAM D NIP, W/PLUG I AND SAND COVERING PLUG I 11122' IlaMDTTLOGGEDO'1/15/86 I 11122' 2--7/0" Ot\MOO TUOING TAIL LISBURNEUNrr WaL: L2-21 ÆRMrr No: 1852750 API No: 50-029-21485-00 SEC 18, T11N, R15E, 4503.47' Fa & 3908.28' F BP Exploration (Alaska) ~ ,-....", -"" ... ,<-- C" ,..---"õ ~,-., ¡'n,"""i?\"'¡"'¡r'" \... ;: ¡ f' \! ,¡ . ;:" r: i \ \ " ! :.:. '\¡I'I~-'\iI'll CìJ) L ,.Fl.). II L¡ ((:,¡ rr;¡ ill] U~ r", n I", ,-~~.\ nr f--:: ¡i.li! ..r,\fl.u!V/ií.\ fill ,\ t!¡i \',-!!Ì in; LA~ l1 LJ:;J tiD U ~ Lf11 ¡ i FRANK H. MURKOWSKI, GOVERNOR I / I ! ALAS KA 0 IL AND GAS CONSERVATION COMMISSION j 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. 0, Box 196612 Anchorage, AK 99519-6612 r\f5 -;).7S Dear Mr. Williams: The Alaska Oil and Gas Conservation Commission ("Commission") received well safety valve system (SVS) test reports from BP Exploration (Alaska) Inc. at Prudhoe Bay Unit Lisburne sites as follows: Location PBU Ll PBU L2 PBU L3 Date of SVS Test April 23, 2004 April 26, 2004 April 27, 2004 Failure Rate 30.0% 16,7% 50,0% Copies of the SVS Test Reports are attached. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part 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 performance is achieved, the safety valve systems associated with wells located on PBU Ll, L2, and L3 must be tested every 90 days. When testing is schedul, must notify the Commission Field Inspector at 907-659-2714 to provide an opportunity to \\!'t th SVS test. Sincerely, 2J~ J . Norman, Chair C<Y'mmissioner Daniel T. Seamount, Jr. Commissioner 3 Attachments cc: AOGCC Inspectors (via emai1) ~ "'-"\ Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Submitted By: Ron Marquez Date: 04/26/2004 Operator Rep: Rob Endebroc1 UnitlFieldlPad: Greater Pt McIntyre/Lisburne/L2 AOGCC Rep: None Separator psi: LPS HPS 448 _1Il~1.- _1- PJlII .'a IfÐJ%Hll1ltl$1I1Ila 8Iflù- Well Permit Separ Set LIP Test Test Test Date Tested and or Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed Retest or SI GAS, CYCLE, SI L2-06 1830470 448 350 280 P P P OIL L2-l0 1870850 11/9/1996 SI L2-l4A 2032140 448 350 250 P 4 P 4/27/2004 OIL L2-l6 1870970 5/16/1995 SI L2-20 1851340 6/29/1995 SI L2-21 1852750 448 350 320 P P P OIL L2-24 1850900 3/28/1995 SI L2-25 1860060 3/23/1996 SI L2-26 1851040 11/8/1996 SI L2-28 1850350 8/4/2000 SI L2-29 1852970 2/24/1994 SI L2-30 1850090 8/4/2000 SI L2-32 1871370 6/9/2003 SI L2-33 1860220 3/28/1995 SI Wells: 3 Components: 6 Failures: 1 Failure Rate: -- Remarks: Page 1 of 1 SVS PBU LIS L2 04-26-04.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !:- 1, Operations Performed: AbandonD Alter Casing D Change Approved Program D 2. Operator Name: SuspendD RepairWeliD Pull TubingD Operation Shutdown D Plug PerforationsD Perforate New Pool D 4, Current Well Class: Perforate ŒI WaiverD Stimulate ŒI Time ExtensionO Re-enter Suspended Well 0 5. Permit to Drill Number: 185-2750 OtherD BP Exploration (Alaska), Inc. Development Œ] Stratigraphic D 9. Well Name and Number: L2-21 10, Field/Pool(s): Prudhoe Bay Field 1 Lisburne Oil Pool ExploratoryD ServiceD 6, API Number 50-029-21485-00-00 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7, KB Elevation (ft): 52.00 8, Property Designation: ADL-o028307 11, Present Well Condition Summary: Total Depth measured 11550 feet 11110 9429.1 feet 11110 feet true vertical Plugs (measured) Junk (measured) None Effective Depth measured true vertical 9137.4 feet Length Size TVD Burst Collapse 470 7020 7500 13890 4760 2670 MD Casing Conductor Liner Liner Liner Production Surface Perforation depth: Measured depth: 10734 -10814,10842 -10920,10965 -10975,11005.5 -11016,11040.5 -11041.5,11042 -11062,11062.5 -11063.5 11070.5 -11071.5,11072.5 -11073.5,11074.5 -11075.5 True vertical depth: 8881.95 - 8937.51,8956.86 - 9010.19,9040.66 - 9047.41,9067.92 - 9074.96,9091.34 - 9092,9092.34 - 9105.65 9105.98 - 9106.64,9111.29 - 9111.95,9112.62 - 9113.28,9113.94 - 9114.61 Tubing (size, grade, and measured depth): 2-7/8" 6.5# L-80 @ 36 10930 4-1/2" 12.6# L-80 @ 10930 10940 2-7/8" 6.5# L-80 @ 10940 10952 Packers & SSSV (type & measured depth): 2-7/8" BOT HB Packer @ 10342 2-7/8" Camco TRDP-1A SSV @ 2178 4" Brown 1-B Packer @ 10930 4" Brown 1-B Packer @ 11090 40 119 40.0 - 119.0 10423 - 11550 8665.0 - 9429.1 11090 - 11100 9124.2 - 9130.8 11100 - 11122 9130.8 - 9145.3 38 - 10629 38.0 - 8809,1 39 - 3687 39.0 - 3622.6 1490 8160 8430 13450 6870 4930 20" 91.5# H-40 7" 29# L-80 4-1/2" 12.6# L-80 2-7/8" 6.16# L.80 9-5/8" 47# L-80 13-3/8" 72# L-80 79 1127 10 22 10591 3648 ..QAI\ 3 1 20U . - , ¡ " -, .. 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: APROa28 RBDMS 8FL Representative Dailv Average Production or Iniection Data Gas-Mef Water-Bbl Casing Pressure 0.8 15 1400 - 13 Tubing Pressure 530 539 Oil-Bbl 367 Prior to well operation: Subsequent to operation: 38 1600 357 0.8 15, Well Class after proposed work: ExploratoryD 14. Attachments: DevelopmentŒ ServiceD 16. Well Status after proposed work: Operational Shutdown 0 OilŒ] GasD WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or NIA if C.O. Exempt: N/A Copies of Logs and Surveys run - Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron 21~ C~fk Production Technical Assistant Title Phone 564-4657 ORIGINAL Date 3/29/04 Signature Form 10-404 Revised 12/2003 L2-21 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 02/05/04 **** WEll SHUT IN UPON ARRIVAl*** TAGGED PARAFFIN @ TBG HANGER ABLE TO DRIFT TO 102' SlM, WI 1 3/4" SB HB&R PUMP 60 BBlS DIESEL DOWN TUBING RIH WI SMAll Bl BRUSH 1.75 GR SD @ 11' SlM BREAK FREE @ 1460' SlM SD @ 11076' SLM POOH BRUSH & FLUSH WI ( NEW) 2718 BL BRUSH 1,99 CENT 2.23 GR BREAK THROUGH @ 1250' SLM RIH TO 4000' SLM POOH HB&R PUMPED 109 BBLS DIESEL TOTAL DWN, TUBING DRIFT WI 8' 2118 STEM SB -158" OAl CONT. ON 02-06-04 WSR 02/05/04 TIIIO = 175011000/250 ASSIST SLlCKLINE WITH BRUSH I BROACH OPERATION. PUMP 109 BBlS OF 180* F. DIESEL DOWN THE TUBING. TIIIO = VAC/1500/450. 02/06/04 CONT, FROM 02-05-04 WSR TAGGED TD @ 11098' SLM W/2 1/8 STEM SB (158" OAL) ( SAND IN SB - 72' OF FILL - TARGET DEPTH = 11062' ) RDMO (LEFT WELL SHUT IN) 02/10104 Perforate 10965'-10975' 4 SPF 02/17/04 T/I/O=1540/1540/300. TEMP=SI. TBG Fl @ 10680' OR 53 BBlS (FOR E-LlNE). 02/20104 PUMPED 15 BBlS OF CRUDE DOWN THE TUBING @ 180* TO WARM UP WEll BORE. 02/20104 RAN THREE PROPELLANT FRACTURING STIMULATING (PFS) GUNS TO STIMULATE RECENTLY PERFORATED ZONE 4 INTERVALS. WELL SHUT-IN ON ARRIVAL. PUMPED 15 BBL CRUDE PRIOR RIH. FIRST PFS 10 FT GUN FOR 10965'-10975, SECOND PFS 10 FT GUN FOR 11006' -11016', THIRD PFS 15 FT GUN FOR 11042' -11057'. DIFFICULTY PULLING INTO TAIL WITH FINAL GUN, RAN UP AND DOWN INTERVAL TO KNOCK OFF DEBRIS, TIE-IN TO CAMCO GRICCL LOG DATED 27-JUL Y-1986. TD TAGGED AT 11089'. FLUIDS PUMPED BBLS 111 15 126 Diesel Crude TOTAL Page 1 "- TREE = WELLHEA 0 = ACTUA.TOR= KB. Ei.EV = BF. Ei.EV = KOP= I'vttx Angle = Datum M:> = Datum TVD = --_? FWC AXELSON . 52; 2775\ 50 @ 11200' 10691' 88oo'SS 113-3/8" CSG, 72#, L-80, 10 = 12.347" H 3687' ~ Minimu m ID = 2,259" @ 10694' AV A BPL NIPPLE TOPOF7" LNR H 10423' 9-5/8"CSG,47#,L-80,ID=8.681" H 10629' ~ 2-7/8"TBG-PC,6.5#, L-80, .00579 bpf,ID=2.441" H 10952' ÆRFORA. TON SUMv1ARY REF LOG: LDT/Cf\l ON 11/29/85 ANGLE AT TOP PERF: 46 @ 10734' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DAlE 4" 4 10734-10814 0 04/14/86 4" 4 10842 - 10920 0 04/14/86 2-1/8" 6 10965-10975 0 02107/04 2" 4 10968 - 11075 0 10/09/87 2-1/8" 6 11006-11016 0 02107/04 2-1/8" 6 11042-11062 0 02107/04 4" 411122-11170 0 04/14/86 L2 - 21 SAFETY NOTES: CAT I-SSSV, H2S 75 (PPM) . 2178' H2-7/8"CAWCOTRDP-1A SSSV,ID =2.312" I - CL - Q-iEMIO\ L MANDRELS ISTI MD I1VDI DEVI TYÆ I VLV LATCH! PORT 1 2234 2234 0 KBtIIG DV BK-2 .. GAS LFT Ml\NDRELS a ST MD 1VD DEV TYÆ VLV LATCH 2 2804 2801 11 MC-FM-iO DV BK-2 3 5615 5063 42 MC-FM-iO OOrÆ BK-2 4 7863 6743 40 MC-FM-iO DV BK-2 5 9458 7973 43 MC-FM-iO DV BK-2 6 10244 8538 44 MC-FM-iO OOrÆ RK PRODUCTION MANDREi.S IST MD 1VD DEV TYÆ VLV ILATCH PORT 7 10641 8817 43 MC-FM-iO DV BK-2 D<\lEl 11/85 D<\lEl 11/85 L PORT D<\ lE 11/11/91 1/4 11/11/91 11/85 11/85 5/16 11/11/91 L z ... Z ---f 10342' H9-5/8" X2-7/8"BROWN I-B A<R I ~ I 10694' H2-7/8" AVA BR... NPW/OSLV,ID=2.259" I []~I 10728' H2-7/8" BROWN BLAST JOINTS ::8: 10930' HrX2-7/8"BROWNI-BA<R 10965'-10975'HpFS STIM TUBE SHOT 02121/04 I I \ 10952' H2-7/8"TUBINGTAILW/WLEG I 10949' H Ei.M:> IT LOGGED 07/27/86 I 11006-11016' HPFS STIM TUBE SHOT 02121/04 I 11042.11057' HPFS STIM TUBE SHOT 02121/04 I 11090' Hr X2-7/8"BROWN I-B A<R 1 11110' H2-7/8"o\MDNlP,W/R...UG I lAND SAND COV ERING PLUG I 11122' H2-7/8" O\WCOTLBINGTAIL I 1 11122' H Ei.M:> TT LOGGED 04/15/86 Q§]-1 11502' I ~ 17"LNR,29#,L-80,.0371 bpf,D=6.184" H 11550' ~ D<\TE 11/28/85 11105101 06/16103 02107104 02f21104 COMv1ENTS ORIGINAL COM PLETION RNIlP CORRECTONS CMJ/1LP MAX ANGLE CORRECTION MJA/KK AŒ'ERFS MDC/1LP PFS STIM TUBES SHOT RBI BY DAlE REV BY COMrÆNTS LISBURNE UNIT WELL: L2-21 PERMT f\b: 1852750 API f\b: 50-029-21485-00 SEC 18, T11 N, R15E, 4503.47' FEL & 3908.28' FNL BP Exploration (Alaska) DATE: 3-2F~-RR FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: CH Final s ~ L2-10 Collar Log 9-29-87 Run I 5" WAI ~ L2-10 Collar Log 12-11-87 Run i 5" WAI ~ L2-10 Injection Profile 3-16-88 Run 1 5" Sch ~ L2-16 Collar Log I1-23-87 Run I 5" WAI ~:Collar Log 10-9-87 Run I 5" DA '~ L3~12 Production Profi'le 3-2-88 run 2 5" Camco ~ L5-12 Collar Log 10-15-87 'Run, I 5" DA ~ L5-29 Collar Log 10-2-87 Run I 5" WAI RECE MAR Aiasl(a u~ & Gas Cons. Commissio~ PL~SE SIGN AND RETURN TO~~MBERT ,RCO NC. ANCHORAGE, AK. 99510 CENTRAL FILES PLANO , D & M STANDARD EXXON STATE OF ALASKA TRANSMITTIAL # ~ STATE OF ALASKA "' AL!'' KA OIL AND GAS CONSERVATION CU&,..,,,:IlSSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging ~ Perforate EX Pull tubing Alter Casing ~ Other ~ Aoid±ze 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska Inc. RKB 52' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay. Lisburne Well number f,2-21 Approval number 4. Location of well at surface 7. 1726' FSL, 1058' FWL,Sec. 18. TllN, R15E, UM At top of productive interval 8. 7-537 9. APl number 50-- 029-21485 10. Pool Lisburne Oil Pool 1190' FSL, 862' FWL, Sec. 6, TllN, R15E, UM Ateffective depth 1270' FSL, 1377' FWL, Sec. 6, TllN, R15E, UM Attotaldepth 1320' FSL, 1320' FWL, Sec. 13,TllN, R14E, UM 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3687' Intermediate Production 10600' Liner 1117' Perforation depth: measured 10734 ' -10814 ' , 11550' feet feet 9444' 11502 9411 Size feet feet 20" 13-3/8" 9-5/8" 7" 10842'-10920', 11122'-11170' true vertical 8955'-9009' 9149'-9182' 8880'-8936', Plugs (measured) NONE Junk (measured) NONE Cemented Measured depth 1810 # Poleset 2500 sx AS III & 600 sx class G 1126 sx class G 450 sx class G 119' 3687' 10630' 10432-11540 9-5/8" BOT @ 10342' & 7" BOT @ 10930' Tubing (size, grade and measured depth) 2-7/8" L-80 11000' Packers and SSSV (type and measured depth) True Vertical depth 119' 3515' 8809' 8665-9437 SSSV: Camco TRDP-1A, 2.312" ~-~2¢17-8~-,~,~ D Et,. IVE 12. Stimulation or cement squeeze summary ,Alaska 0il & Gas Cons. C0mn'iission 13. Intervals treated (measured) Wahoo 4 Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 251 177 0 254 380 0 Casing Pressure Tubing Pressure 75 389 75 372 Prior to well operation Subsequent to operation Copies of Logs and Surveys Run [] 14. Attachments Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Technical Aide Date 11/3/87 Signed ¢~f~ ~),.~T'~ b ~"~-~-- Form 10-404 Rev. 12-1-85 Submit in Duplicate(~ SEQUENCE OF EVENTS FOR L2-21 DATE 10-13-87 TIME 0800 COMMENTS LIMITED ENTRY PERFORATED WAHOO ZONE 4 FROM 10968'- 11075' WITH 23 PERFORATIONS 10-14-87 O80O 1100 RIG UP BJ HUGHES FOR ACID STIM. PRESSURE TEST SURFACE LINES TO 5,5OO PSI 1152 START PUMPING DIESEL PAD 1200 START PUMPING ACID STAGE AT 1.6 BPM AT 4020 PSI 1232 SAW PRESSURE BREAK AND INCR- EASED RATE TO 5 BPM 1242 START DIESEL FLUSH 1303 FINISH PUMPING STIMULATION 10-16-87 1410 O9OO RIG DOWN BJ HUGHES AND SECURE WELL PULL BPI AND RUN IN WITH BPC RECEIVED Alaska Oil & Gas Cons. Commission Anchorage REPO STATE OF ALASKA ' 'SKAOILAND GAS CONSERVATION Q'~ ~MISSION , OF SUNDRY WELLOPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging '- Perforate .'~ Pull tubing Alter Casing ~ Other ,_-X A¢idize 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska Inc. RKB 52' Feet 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay. Lisburne 4. Location of well at surface 7. 1726' FSL, 1058' FWL,Sec. 18. TllN, R15E, UM At top of productive interval 1190' FSL, 862' FWL, Sec. 6, TllN, R15E, UM At effective depth 1270' FSL, 1377' FWL, Sec. 6, TllN, R15E, UM At total depth 1320' FSL, 1320' FWL, Sec. 13,TllN, R14E, UM Well number T,2-21 Approval number 7-537 9. APl number 50-- 029-21485 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3687' Intermediate Production 10600' Liner 1117' 11550 ' feet feet 9444 ' 11502 9411 Size 20" 13-3/8" feet feet Plugs (measured) NONE Junk (measured) Cemented 9-5/8" 7" Measured depth True Vertical depth Perforation depth: measured 10734 ' -10814 ' , 10842 ' -10920' true vertical 8880' -8936 ' , 8955' -9009 ' , Tubing (size, grade and measured depth) 2-7/8", L-80, 11000' Packers and SSSV (type and measured depth) , 11122'-11170' 9149'-9182" 1810 # Poleset 2500 sx AS III & 600 sx class G 1126 sx class G 450 sx class G 119' 3687' 10630' 10432-11540 119' 3515' 8809' 8665-9437 12. Stimulation or cement squeeze summary intervals treated (measured) Wahoo 4 Treatment description including volumes used and final pressure 9-5/8" BOT @ 10342' & 7" BOT @ 10930' SSSV: Camco TRDP-1A, 2.312" @ 2178' RECEIVED Alaska 0il & Gas Cons, 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data. OiI-Bbl Gas-Mcf Water-Bbt 251 177 0 254 380 0 Anch0ra~e Casing Pressure Tubing Pressure 75 389 75 372 14. Attachments Daily Report of Well Operations Copies of Logs and Surveys Run L.7 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Technical Aide Date 11/3/87 Form 10-404 Rev. 12-1-85 Submit in Duplicate SEQUENCE OF EVENTS FOR L2-21 10-13-87 O8OO ~MENTS LIMITED ENTRY PERFORATED WAHOO ZONE 4 FROM 10968'- 11075' WITH 23 PERFORATIONS 10-14-87 0800 1100 RIG UP BJ HUGHES FOR ACID STIM. PRESSURE TEST SURFACE LINES TO 5,500 PSI 1152 START PUMPING DIESEL PAD 1200 START PUMPING ACID STAGE AT 1.6 BPM AT 4020 PSI 1232 SAW PRESSURE BREAK AND INCR- EASED RATE TO 5 BPM 1242 START DIESEL FLUSH 1303 FINISH PUMPING STIMULATION 10-16-87 1410 090O RIG DOWN BJ HUGHES AND SECURE WELL PULL BPI AND RUN IN WITH BPC RECE[VI:i ~'\" Alaska Anchorage ARCO DATE: 10-.26-.87 FROM: PAM LAMBERT ENCLOSED IS THE FOLLOWING DATA FOR LISBURNE: Cfi Finals L5-5 £:CL/GE/TE~IF/Dlff Temp/HP Survey 10-16-87 Run 1 5" L5-21 Packer Settin§ Lcg 10-16-87 Run i 5" Sc~K'~ Sch~ ska 011 & Gas Cons, Commission Anchorage RECEIVED BY: PLEASE SIGN AND RETURN TO: PAM LAMBERT ARCO ALASKA INC. 700 G STREET ATe 477 ANCHORAGE, AK. 99510 CENTRAL FILES PLANe' , D & M STANDARD EXXON ~"'STATE OF' ALASKA ~,"' ~' TRANSMITTIAL # 330 STATE OF ALASKA;~' ALJ,_..,A OIL AND GAS CONSERVATION CO~, ..... ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing ~ / '~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate E:~ Other [~ Ac-idJ~/~,, 2. Name of Operator 5. Datum elevation (DF or KB) ARCO AI~ASKA, INC RKB 52 fee 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, Alaska 99510 Prudhoe Bay/Lisburne 4. Location of well at surface 1726' FSL, 1058' FgTL, Sec. At top. o~ productive ir~terval 1190' FSL, 862' ~WL, Sec, At effective depth 1270' FSL, 1377' FWL, Sec. 6, TllN, R15E, UM At total depth 1320' FSL, 1320" FWL, Sec. 13., TllN, R14E., ~fM 18, TllN, R15E. ~f 6, TllN, R15E, UM 7. Well number L2-21 8. Permit number 9. APl number 50--029.-21485 10. POOl Lisburne 0il Pool 11. Present well condition summary Total depth: measured true vertical 11550' feet 9444' feet Plugs (measured) NONE Effective depth: measured ~1'1502' feet Junk (measured) NONE true vertical 9411 ' feet Casing Length Size Cemented Measured depth True Vertical depth Structural 80~ 20" 1810¢~ POLESET 119' 119' Conductor 3687~ 13-,3/8" 2500 sx AS TII & 3687' 3515! Surface 600 sx claSs G Intermediate 10600' 9-.5/8" 1126 sx class G 10630' 8809' Production Liner 1117,' . Perforation depth: measured 10734'-10814', 10842'-.,10920', 11122'.~11170' true vertical 8880'-.8936', 8955'-9009', 9149 ',-,9182' Tubing (size, grade and measured depth) 7" 450 sx class G 10423~11540' 8665-9437' pa2c-k%/rs8"ahd~-S8S0¢ 11000' approx. (type and measured depth) Packers: 9-5/8" BOT @ 10342' & 7" BOT @ 10930' SSSV..'. CAMCO TRDP.-.1A, 2~3¢.2~,~1~',, 12.Attachments Description summary of proposal ~ Detailed operationLC'~p~a~~1' [(:Ll~ sketch [] 13. Estimated date for commencing operation August 19, 1987 AUG ! 7 1987 14. If proposal was verbally approved Name of approver Naska Oil & Gas Cons. Commission Anchorage Date approved 15. I he~,~ertify that the foregoing is true and correct to the best of my knowledg, e Signed~ ~/'~~.~~ Title ~.~~, ' Commission Use Only Dat Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance i~ii ., ;.. :' ~'',''' :" !' IApproval No. "~ ,- ..~"-3 7 Commissioner by order of the commission Date 4~", /7~'/ Submit in tri¢licate~. Form 10-403 Rev 12-1-85 · 2, 3, , 5o o 0 0 L2-21 Zone 4 Perforation and Stimulation AFE 803553 Pump hot diesel treatment. RU perf unit and shoot Zone 4 with 2-1/8" hollow carrier guns: 10,968' - 10,974' MD 6' 11,006' - 11,012' MD 6' 11,041' - 11,045' MD 4' 11,050' - 11,063' MD 13' 11,071' - 11,075' MD 4' 4 holes 4 holes 3 holes 9 holes 3 holes Total 33' 23 holes Depths are referenced to LDT/CNL 11/29/85. RD perf unit. RU slickline and set "BPI" isolation sleeve in open 'BPL' at 10,694' ELMD. RD slickline. RU acid pumper and perform treatment according to attached acid pumpimg schedule. Shutdown and record SITP for 15 minutes minimum. RD acid pumper. Open well to tanks and test for 24-48 hours. RU slickline and replace "BPI" with "BPC" commingling sleeve. Pull plug from isolation packer at 11,090' ELMD. RD slickline. Turnover for commingled production of Zones 4, 5, and 6. RECEIVED AUG 1 7 ]987 Alaska Oil & Gas Cons. Commi~slon Anchorage JAW 8/14/87-2 L2-24 Acid Pumping Schedule AFE 803553 1000 Gal Gelled 15% HC1 200 Gal Gelled 15% HC1 w/1 ppg Unibeads, 50% wide range, 50% buttons 1000 Gal Gelled 15% HCl 200 Gal Gelled 15% HCl w/1 ppg Unibeads, 50% wide range, 50% buttons 3500 Gal Gelled 15% HC1 3500 Gal Diesel w/400 SCF/BBL nitrogen 9400 Gal Load Treating pressure should be limited to 4500 psi. Expected rate at 4500 psi is 10 bpm or less. Acid Additives chelating agent non-ionic surfactant corrosion inhibitor scale inhibitor acid friction reducer anti-sludge agent non-emulsifier Dowell Halliburton B.J. Titan 100#/1000 gal 20#/1000 gal 20#/1000 gal L41 FDP-5387 Ferrotrol 210 0.5% F75N 0.4% 0.1% NE-20 & LoSurf 300 0.8% NE-24 0.2% 0.2% 0.2% A250 HAI 75 CI-15 0.1% L47 15 gal/1000 gal J-429 0.5% W-54 0.1% 0.1% FDP-377 X-9 15 gal/1000 gal SGA-HT 0.2% AS 5 mi Im 15 gal/1000 gal FRW 13 RECE'IVED AUG i ? 1987 Alaska Oil & Oas Cons. Commissio~ Ancl~orage JAW 8/14/87-2 ARCO Alaska, Inc~ Post Office :,ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 JUNE 187 1989 Mr. L. C. Smith - Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage~ Alaska 99501-3192 Dear Mr. Smith Attached is the Report of Sundry Well Operations for Sundry Approval ?-116 on Lisburne well L2-21. B. T. Kawakami Lisburne Operations Coordinator .,I.ji.,d 2 3 1987 Alaska 0ii & Gas Cons. C:ommissbn Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA I~. ALA( A OIL AND GAS CONSERVATION CO ,..,SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~_, Stimulate~ Plugging ~ Perforate - Pull tubing Alter Casing --_ Other ~_~ 2. Name of Operat~rRc0 ALASKA, INC. 5. ~m~l.~vation (DF or KB) Feet 3. Address P.O.B. 100360, ANCHORAGE, AK. 995 i 0 6. ~rituOc[hP(~oeDe~Ya~,a~L~isburne 4. Location of well at surface 7. Well number L2-21 1726' FSL, 1058' FWL, Sec. 18~ TtiN., R15E, UM At top of productive interval 1190' FSL, 862' FWL. Sec. 6., TiiN, R15E,UM At effective depth 1270' FSL, 137'7' FWL, Sec. 6, Tlliq~ R15E, UM At total depth 1320' FSL~ 1320' FWL, Sec· 13, TllN, RlZ+E,UM (APF (AF 8. Approval number?- 116 ) 9. APl number 029-21 P)50-- 10. Pool L_ISBURNE OIL POOL 11. Present well condition summary Total depth: measured true vertical 1550' feet Plugs (measured) NONE 9444' feet Effective depth: measured 11502' true vertical 9Al 1 ' feet Junk (measured) NONE feet Casing Length Size Structural 80 ' 20" Conductor 368? ' 13-3/8" Surface Intermediate 10600' 9-5/8" Production 1 1 17' 7" Liner Cemented Measureddepth ~ueVerticaldepth 1810# POLESET 119' 119' 2500 sx AS III & 3687' 3515' 600 sx class G 1126 sx class G 10630' 8809' ~+50 Perforation depth: measured 10734.'-10814' , 10842'-10920' true vertical 8880'-8936' , 8955'-9009' ~ Tubing (size, grade and measured depth) 2-7/8"~ Lao~ 1.1000' approx. Packers: Packers and SSSV (type and measured depth) 10930 ' sx class G 10423-115~,~.;~~,~,"' ~?~.,~437' , i i i 22' - i 11 ?o' J 2 198 ? A chom e 9-5/8" BOT @ 103A2' & 7" BOT @ SSSV: CAMCO TRDP-1A~ 2.312" 8 2178' 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 218 12z+6 1 150 q. 50 247 1595 I 200 450 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ o~ .... ¢),_~Z LISBURNE OP. COORD. 06/18/89 Signed Title Date Form 10-404 Rev. 12-1-85 Submit in Duplicate '~N,O.~5 IV (Z3d,'JOl$ (IN~ '~NIq~QI'I$ /M NUZ£U~ 9~i gL ~i,dW31i~ '$~H e£e~ i~ NOIiO~O~d NO 993M a,,e~se~ .O~ae ~Vd Ol a39I~d $900£ ONISOO9 iN3Wi¥3~ $~H ~ /3A~n$ 3~n$$3~d/3~nig~3dW31/Ag~ YWW¥O '~£~ 3NiOO! '9VO eee~ asa eee~ isuz~ aNY ¢ZOV '9353I~ nvO e~ 'qoa ~ 'q¥O cee: :INgW/~3~/ ~I3~ '3(lr1~3 dOe~ 9~18 CC :£N3Wm¥3~i 910 /OH 03Wq~Od..~3d · (~dO0 :6LS) (IdOW 989L (IN~.(~dO(! .L6~ (I3£$3.L Lg'-lJe-t, '(~00 t, Oelr) <IdOW 9Z~t (]NV (~dOe.£t,e! (/3J.~3J. · $~H O0tr~ 1~ NI-/rlH$ 'IN3WIV3BJ. 910 £OH (I3W)9Od~3d ,/8- ~O-b · (~JOO OL6lr) (IdOW 6£~) (]NV QdO(I Lg~ i9 A3A)JFi$ 3~rll¥,33dW3L/3~$$3~ld ONIlqOqd NV~9 L$-£~-~: 'OW ,~,1,~1, £~ 39ddlN ,O, NI OAgd 135 '39ddlN G31,~Od WO.~3 ,d3e, ¢399~d ~D-C~--F. 'q3~3!(1 JOBt, Sq~8 ~L '3N39AX .-lOCi "19311 NI J',LI$O,:J3Q X~M Ol :J:'~<'; G'.jgI~.:~ l.?),] ',.~3~.t, 99Fld Ol (~ldW31~¥ LISBURNE ENGrI~ERING Date: 5-19-87 From: Pam Lambert Enclosed are the following: CH Finals for Lisburne Wells L2-33 Temp Fluid Density Flowmeter Log 5-8-87 Run 1 5" Camco L3-8 Waterhold Up Temp Flowmeter Log 5-4-87 Run 1 5" Camco L3-24 Flopetrol Prod Logging 4-30-87 Run 1 5" Sch L3-30 Post Temp GR Log 5-2-87 RUn 1 5" Camco 5" L3-30 Collar Log & Perforating Record 5-7-87 Run 1 Sch L3-30 Major Acid Treatment Temp GR 5-11-87 Run 1 5" Camco L3-30 Mini Breakdown Treatment Temp GR 5-11-87 Run 1 5" Camco %eceived by: Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M EXXON 'STATE STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 237 (ItI~(INY~S XOXX:~ qoS f ~o i qgnozq] i ~o I s]aeE 98-9-I 6~-[7 zo~ a]!sodmoD S~R :~uIaolIO; eql eze pesolou~ LISB~ EN~IN~EI~IN~ Date: 4-23-87 From: Pam Lambert Enclosed are the following: CH Final for L2-21 J~M~J Pump-In Temp GR Log 4-4-87 Run 1 5" Camco n and return to~ Para Lambert ARCO'AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STATE EXXON STANDARD FILE ROOM CENTRAL FILES TRANSMITTAL # 217 qoS ,,'g I un~ 18-6-[ §uI~o% 'poa~ IOz3~doI~ 8[-[~ oo~D ,,~ I un~ ~8-[[-[ ~a~zns azn:~zad~a~ I~-Z~ siiaM auznqs!% zo~ sIeuIR HD :~uImolIO~ ~q~ ~z~ pasolouM /8-9-~ :a~wG A~CO AI~. INC. Date: 5-7-87 From: Para Lamber Enclosed are the following:~ C~or Lisburne Wells L2-21 Post Acid GR Temperature Log 4-10-87 Run 1 Camco~' L2-21 GR Temperature Log 4-18-87 Run 1 Camco .... L3-24 Diff Temp/GR (Post Major Stim) 4-19-87 Run 1 GO L3-24 Diff Temp/GR (Post Minor Stim) 4-19-87 Run 1 GO L3-24 Collar/Perf Log 4-11-87 Run 1 GO L3-24 Diff Temp/GR Static Base Log 4-17-87 Run 1 GO L3-30 Diff Temp/GR Post Stim 4-18-87 Run 1 GO Received.,,by: ,j. ~" '/~~. Pleasi$igP/and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M FILE ROOM EXXON STANDARD CENTRAL FILES 232 TRANSMITTAL # ARCO Alaska, Inc.j" Post Office ~..,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 23, 1987 Mr. L. Co Smith - Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Dear Mr. Smith Attached is the Application for Sundry Approvals for the program which ARCO Alaska, Inc. proposes to conduct on Lisburne well L2-21. B. T. Kawakami Lisburne Operations Coordinator Alaska 0ii &,: Ga,s Cons. C0mrnJssi0~ Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany " STATE OF ALASKA ALASK~~ ..,IL AND GAS CONSERVATION COMM~' 'ION APPLICA( .ON FOR SUNDRY AI ' ROVALS I Type of Request: Abandon '- Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing .~ Time extension 7' Change approved program ~ Plugging E3 Stimulatex~ Pull tubing [] Amend order E3 Perforate [] Other 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 4. Location of well at surface 1726' FSL, 1058' FWL, Sec. 18, TllN, R15E, UM At top of productive interval 1190' FSL, 862' FWL. Sec. 6, TllN, R15E, UM At effective depth 1270' FSL, 1377' FWL, Sec. 6, TllN, R15E, UM At total depth 1320' FSL, 1320' FWL, Sec. 13, TllN, R14E, UM (APP) (APP 11. Present well condition summa~ Total depth: measured J~ 1550 ' true vertical 9444 ' feet Plugs (measured) feet 5. Datum elevation (DF or KB) RKB 52 6. Unit or Pro,oertv,oame, Pru~oe ~a~-/L~sDurne 7. Well number L2-21 feet 8. Permit number 85-275 9. APInumber ~-- 029-21485 lO. Pool LISBURNE OIL POOL NONE Effective depth: measured 11502 ' feet true vertical 9411 ' feet Junk (measured) NONE Casing Length Size Structural 80 ' 20" Conductor 3687' 13-3/8" Surface 10600' 9-5/8" Intermediate Production 1117 ' 7" Liner Perforation depth: measured 10734'-10814', truevertical 8880'-8936', Cemented Measureddepth 1810# POLESET 119' 2500 sx AS III & 3687' 600 sx class G 1126 sx class G 10630' 450 sx class G 10423-11540' Wue ~rticaldepth 119' 3515' 8809' 8665-9437' 10842'-10920', 11122'-11170' 8955'-9009', 9149'-9182' (all approx) ~bing(size, gradeand measureddepth) 2-7/8", L80, 11000' approx. PackersandSSSV(typeandmeasureddepth) Packers: 9-5/8" BOT @ 10342' 10930' SSSV: CAMCO TRDP-1A, & 7" BOT @ 2.312" @ 2178' 12.Attachments Description summary of proposal [~x Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation March 2, 1987 14. If proposal was verbally approved Name of approver I~{~l~p~3Ced~as C.,o~}$. Co~ssio~ 15. I hereby certify the foregoinl is true an~.cprre.ct to the best of my knowledge' . o Signed "Title LISBURNE OP. COORD. Date 2/23/87 Commission Use Only Conditions of approval Notify commission so representative may witness ! Approval No. ..~ / .., [] Plug integrity [] BOP Test ~ Location clearance~ / ~ //~ ,.,, ...... :::' c2- ' ~,,~,~ .~, ~, .............. by order of Approved by!,,?,.!' !~.i'.:":,,:;,',,'i'/i ~".:~:~ :~,i.,~,,i~:~;,,;~, Commissioner the commission Date.~-c.~.~'-~' ~c.~ Form 10-403 Rev 12-1-85 Submit in triplicate L2-21 ~....~DIAL P~OCKA~ 1. Run flow~ns temperature los. 2. Shut-in for 4 days. Run static baseline temperature/samma ray loss. Run pump-in temperature los. 3. Pump 25 bbl HCL perforation wash. If well tests less than 600 BOPD, skip Step 4. Produce for approximately 1 week and run flowins temperature los. 5. Run pump-in temperature lo8. 6. Pump 200 bbl 15% HCL with 3 oil soluble resin diverter stases at 2 bpm. 0verflush with 238 bbl diesel tasged with low level radioactive tracer. Run temperature decay/samma ray loss. 7. Produce for approximately 1 week and run flowing temperature survey. J. A. Walker ]11 [ I1] ~]lllll[ . .,,, [ ~ A~¢O ALASKA iNC. LISBURNE ENGINEERING Date: 2-9-87 From: Pam Lambert Enclosed are the following: OH Finals for Lisburne Wells "- L1-2 Mudlog 9-2-85 NL Baroid ~Ll-14 Mudlog 7-13-85 Westlog '"~=_-L2-3 Mudlog 11-4-85 NL Baroid ~ L2-21 Mudlog 11-26-85 NL Baroid ~L2-25 Mudlog 1-30-86 NL Baroid ~L2-33 Mudlog 2-28-86 NL Baroid ~- L3-2 Mudlog 9-9-86 Westlog ~L3-5 Mudlog 9-18-85 Westlog ~ L3-11 Mudlog 10-25-85 Westlog ~ L3-22 Mudlog 11-18-86 Westlog ~ L3-19 Mudlog 12-19-85 Westlog ~" L3-30 Mudlog 12-31-86 Westlog "~ L5-4 Mudlog 1-20-87 Westlog '"'"~.LGI-2 Mudlog 8-7-86 Westlog LGI-6 Mudlog 6-20-86 Westlog ~LGI-8 Mudlog 5-19-86 Westlog ~---LG~i~i~: 7-19-86 Westlog Please sign and return to~ Pam Lambert ARCO AK INC. 700 G Street ATO 477 Anchorage, AK. 99510 D&M STA E EXXON STANDARD FILE ROOM TRANSMITTAL # 167 CENTRAL FILES . !91 7 ('-) Gas Cons. commission AnchomgO KL STATE OF ALASKA I~' ALAS ' OIL AND GAS CONSERVATION COM ,,ION REPORT OF SUNDRY WELL OPERATIONS Operations performed: Operation shutdown [] Stimulate'~ Plugging [] Alter Casing ~71 Other"~ 2. Name of Operator ARCO ALASKA, INC. 3. Address P.O.B. 100360, ANCHORAGE, AK. 99510 4. Location of well at surface of procFu~:tive ~n]erval 1190' FSL, 862' FWL At effective depth 1270' FSL, 1377' FWL At total depth 1380' FSL; 13PO' FWL 11. Present well condition summary Total depth' measured true vertical Sec. 18, TllN, R15E, UM Sec. 6, TllN, R15E,UM (AP[ Sec. 6, TllN, R15E, UM (AF Sec. 13; T11N; ~14F;IIM 11550' feet Plugs(measured) 9444' feet Perforate [] Pull tubing 5. Datum elevation (DF or KB) RKB 52 Feet 6. Unit or Property name Prudhoe Bay/Lisburne 7. Well number 8. Approval number 9. APl number 0P9-21485 50-- P) 10. Pool I TRR~P~J~ O_TL POOL NONE Effective depth: measured true vertical Casing Length Structural 80' Conductor 368'7 ' Surface 11502' 9411' Size 20" 13-3/8" Intermediate 10600' 9-5/8" Production 111,7' Liner Perforation depth: measured 7II feet Junk (measured) NONE feet Cemented Measured depth 1810# POLESET 119' 2500 sx AS III & 368'7' 600 sx class G 1126 sx class G 10630' ~ueVerticaldepth 3515' 8809' 450 sx class G 10423-11540' 8665-943'7' 10734'-10814', 10842'-10920' truevertical 8880'-8936', 8955'-9009', ~bing(size, gradeand measureddepth) 8-?/8", L80, llO00' approx. PackersandSSSV(typeand measureddepth) Packers: 10930' , 11122'-11170' 9149'-9188' (all approx) 9-5/8" BOT @ 10342' & ,7" BOT @ SSSV: CAMCO TRDP-1A, 2.312" @ 21,78' 12. Stimulation or cement squeeze summary Intervals treated (measured) SEE ATTACHED SUMMARY Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A Subsequent to operation 1000 883 0 500 '700 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge (2~'"~ _~"-?!- ~ Signed 1~ ~-~7~, /~~J Form 10-404 Rev. 12-1-85 LISBURNE OP. COORD. 12/2/86 Title Date Submit in Duplicate L2-21 ACID TREATMENT WAHOO ZONE & PERFORATED INTERVAL 11,122'-11,170'MD Date Description Pre-Acid Flovback: Acid Breakdown Treatment: 06-23-86 1620-1815 Flowback Summary: 06-23-86 2111-2400 06-24-86 0000-0130 06-24-86 1200 06-24-86 1700 Well opened and did not flow. Pumped nitrified acid treatment thru-tubing into Wahoo Zone & perfs. Treatment included a preflush of 10 bbls diesel w/lO% Inflo-40, 51.2 bbls 15I HCL, and a final flush of 75 bbls 1001 diesel. The maximum flow rate vas 1.4 BPH at 2875 psis inlection pressure. The averase injection pressure was 3300 psis, Nitrogen was pumped at an averase rate of 750 scg/bbl. Total load of 136.2 bbls and an ISIP of 3200 psiS. Open veil to flow after 3 hrs. shut-in. Well produced back N2, diesel, and acid. Continuing to flow well to tanks. Tank strap indicates 190 bbls. Shut-in well. Total flowback of 200 bbls measured. ~-'.' ' ' a. SITP of 350 psis measured. B6119 g'Z 0060 lZ969 ~I 0~0 ~l~9l [I 0[I0 · £'0 0£00 9B-91-90 9B-£l-90 m s~p$~oltO uosa~Inq~$ wldm~$ ~mms :u~l~ai ~ ~uoz ooqvti Il-lq General Purpose Workshe~ tP=lae NO IlS AR3B-1473.D To: State of Ak John Boyle L~sburne Engineering From: Para Lambert ,,, o. Da~e: 9-2-86 -- Traasml~ed herewith are the folloving: . CH Finals for Lisburne Wells L2-3 Collar Log 7-24-86 Run 1 5" Camco L2-21 GR/CCL 7-27-86 Run 1 5" Camco L2-30 Diff. Temp'(Long String) 6-30-86 Run 1 5" GO Para Lamber~ ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmi~al No:O,.~/ ARCO Alaska Inc. State of Ak John Boyle o. l~'rom: Dace: Para Lamber _~ 8-1-86 Transmitted herewith are che following: OH Finals for Lisburne Well LGI 6 '"'~Dual Laterlog 6-26-86 Run 1 2"&5" Sch .... ~Natural GR Spectroscopy 6-26-86 Run 1 2"&5" Sch "~L~T/CNL Raw 6-27-86 Run 1 2"&5" Sch "'~LDT/CNL Poro 6-27~86 Run 1 2"&5" Sch ~'~E~T 6-27-86. Run 1 2"&5" Sch '"'~Cyberlook 6-27-86 Run 1 Sch ~ CET 6-27-86 Run 1 Sch 'x"~CNL in 9 5/8 casing 6-27-86 Run 1 2"&5" Sch F~nal £or L~sburne Well L2--21 :i Collar Log 4-~S-86 Run 1 DA / ReceipC Acknowledgement: ReCurn Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box i00360 Anchorage, Alaska 99510 TransmitCal No: ~~ & Gas Cons. Coamission Anchorage (' STATE OF ALASKA ~ ALASI~ b,t_ AND GAS CONSERVATION'u~,,,MISSlON WELL COMPLETION OR RI[COMPLETION REPORT AND LOO 1. Status of Well Classification of Service Well OIL~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-275 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21485 4. Location of well at surface 9. Unit or Lease Name 1726' FSL, 1058' FWL, Sec.18, T11N, R15E, UN LOCATION:~ Prudhoe Bay Unit/Lisburne VERIFIED At Top Producing Interval , , 10. Well Number 1218' FSL, 1357' FWL, Sec.13, T11N, R14E, UN I,~',- ' ~'' " L2-21 At Total Depth ~.bli ~j. 11. Field and Pool 1371' FSL, 774' FWL, Sec.13, T11N, R14E, UM .... Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Li sburne 0i 1 Pool 52' RKB ADL 28307 ALK 2317 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I15. Water Depth, ifoffshore 116. No. of CompIetions 11/12/85 11/28/85 04/1 7/86*I N/A feetMSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 11550 'MD ,9428 'TVD 11502 'MD ,9395 'TVD YES)(~ NO [][ 2178 feet MD 1900' (approx) 22. Type Electric or Other Logs Run LDT/CNL/NGT, LSS/Waveforms/GR, DLL/MSFL/GR, EPT/ML/GR, CET, GR/CCL, GCT 23. CASING, LINER AND CEMENTING RECORD '--- SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20~ 9i .5# ft-4, o 5ur'r 119' 30" 1810# Poleset 13-3/8" 68.0#/72.0~ K-55/L-8G' Surf 3687' 17-1/2" 2500 sx AS Ill & 600 sx Class G 9-5/8" 47.0# L-80 Surf 10630' 12-1/4" 1126 sx Class G & 300 s) AS I 7" 29.0# L-80 0423' 11540' 8-1/2" 450 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10,734' - 10,814' 2-7/8" 11,122' 10,342', 10,930'WLM, & 10,842' - 10,920' w/4 spf 11,090'WLM 11 ,122' 11 ,I70' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27.N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL:BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OILRATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED~1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10-407 * Drilled RR 12/3/85. Perforated & completed RR~4/17/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/033 Submit in duplicate 29. R~ 3O. GEOLOGIC MA ATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Wahoo Zone 7 TRUNCATED N/A Top Wahoo Zone 6 10,732' 8874' Top Wahoo Zone 5 10,838' 8946' Top Wahoo Zone 4 10,952' 9023' Top Wahoo Zone 3 11,226' 9208' Top Wahoo Zone 2 11,318' 9271' Top Wahoo Zone I 11,399' 9325' 31. LIST OF ATTACHMENTS Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~)v/)/~/~ ~/,,~.~L~/ Title ASSociate Engineer Date (~'~'~(~ '...,~....., INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in'situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiPle completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 2.7: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 To: ARCO Alaska Inc. Lisburne Engineering Stmtc cf A!z£ka fohn Rcy!c From: Date: Pam Lambert June 4, 1986 Transmit=ed herewith are the following: L2-21 GCT Directional Survey 1-8-86 Sch Receipt Acknowledgmen=: Return Receip= Co: AltCO Alaska Inc. Pam Lambert ATO 477 PO Box 100360 Anchorage, Alaska 99510 Transmi==al No: ~~-- A(,., STATE OF ALASKA I~, AL .,,-, .~IL AND GAS CONSERVATION CO ,,...,iON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~.' Stimulate ~ Plugging ~ Perforate ~ Pull tubing Alter Casing C Other E~ Comp].ete 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360 Anchorage_ AK gC)~lO 4. Location of well at surface 1726'FSL, 1058'FWL, Sec.18, T11N, R15E, UM At top of productive interval 1327' FSL, 1409'FWL, Sec.13, T11N, R14E, UM (approx.) At effective depth 1156'FSL, 885'FWL, $ec.13, T11N, R14E, UM (approx.) At total depth 1157'FSL, 853'FWL, Sec.13, T11N, R14E, UM (approx.) 5. Datum elevation (DF or KB) RKB 52 ' Feet 6. Unit or Property name 7. Well number 1.2-21 8. Approval number Permit #85-275 9. APl number 50-- 029-21485 10. Pool Lisburne Oil Pool 11. Present well condition summary Total depth: measured true vertical 11550 feet Plugs (measured) 9535 feet None Effective depth: measured true vertical 11502 9499 Casing Length Size Conductor 80' 20" Surface 3687' 13-3/8" Producti on 10593 ' 9-5/8" Liner 1117' 7" feet Junk (measured) feet None Cemented 1810# Poleset 2500 sx AS III & 600 sx Class G 1126 sx Class G & 300 sx AS I 450 sx Class G Measured depth Rue Verticaldepth 119'MD 119'TVD 3687'MD 3622'TVD 10630'MD 8847'TVD 10423'-11540'MD 8693'-9527'T Perforation dePth: measured 10,734'-11,170'MD true vertical 8925 ' -9251 ' TVD Tubing (size, grade and measured depth) 2-7/8", L-80, tbg w/tail ~ 11,122'HD Packers and SSSV (type and measured depth) HB pkr (~ 10,342' RECEIVED MAY 2 1 1986 Alaska 0il & Gas Cons. Commissb~~ A.~ch:~rage , lB pkr (~ 10,930'~LM & 11,090~WLM, & TRDP-1A SSSV ~ 2178~ 12..Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Title Associate Enqineer Date (DAM) SW0/027 Submitin Duplicate ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District JCounty. paris, or 13or@ugh JState Alaska North Slope Borough Alaska Field IL .... or Unit We,,~_. 21 Prudhoe Bay ADL #28307 - Title Completion Auth. or W,O. no, AFE 803553 Pool 102 AP1 50-029-21485 Operator JARCO W,I. ARCO Alaska, Inc. 50% Spudded or W.O. begun [Date IHour 1Prior status if a w.o. Complete 4/13/86 0300 Hrs. Date and depth es of 8:00 a.m. Complete record for each day reported 4/13/86 thru 4/14/86 4/15186 4/16/86 4/17/86 7" @ 11,54~' 11,502' PBTD, RIH w/2-7/8" tbg 9.4 ppg Brine Acce~t rig @ 0300 hfs, 4/13/86.. ND tree, NU & tst BOPE. Pull tbg hgt. RIH w/4" tbg conveyed guns, PU 2-7/8", 6.5# tbg & rabbit same. Fill btm.~ 333'5' w/9.4 ppg brine w/120Opsi cushion, · 7" @ 11,54 11,502' PBTD, POOH 9.5 ppg Brine RU DA, set pkr @ 10,711'. Press ann to.2100 psis monitor tbg press & allow to stabilize @ 625 ps,i. Bullhead 72 bbls dn tbg to kill well, pull pkr loose & rev circ, C&C, pull 500'; well flowing.. RIH 500', circ & raise mud wt to 9.5 ppg, POOH. 7" @ 11,54~' 11,502' PBTD, RIH w/compl string 9.5 ppg Brine POOH, LD gun. RU DA, make 8.3" gage ring/JB rn to TOL, POOH. Rn 5.8" gage ring/JB to 11,350', POOH. RU & rn btm pkr assy to 11,090' w/tail @ 11,122', POOH. R~ middle pkr assy & set @ 10,930' w/tail @ 10,951'. RD DA. RU & rn comp'l string. 7" @ 11,54~' 11,502' PBTD,~.Displ well to diesel Diesel Fin rm'g 339 ~ts, 2-7/8", 6.5#, L-80 EUE 8RD tbg w/SSSV @ 2178', HB Pkr @ 10,342', 1-B Pkr @ 10,930' WLM & 11,090' WLM, TT @ 11,122'. Instl SSSV, space out pkr & lnd tbg. Press tbg to 2500 psi to set pkr. Press ann to 1500 psi. Shear PBR, lnd tbg. Shear ball. Set BPV & ND BOPE. NU & tst tree to 5000 psi. Displ well w/diesel. The above is correct For form ~reparatlon end distribution, see Procedures Manual, Sect}on 10, Drilling, ~agos 88 and 87. Date J Title 5/01/86 Drilling Supervisor AtlanticRichfieldCompany Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Rel3ort' should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be usecl for rel3or~ing the entire operation if space is available. Accounting cost center code District County or Parish State Alaska North Slope Borough Alaska Field Lease or Unit I Well no. Prudhoe Bay ADL #28307 I L2-21 Auth. or W.O. no. T t e AFE 803553 Completion Pool 102 API 50-029-21485 Operator I A.R.Co. W.I. ARCO Alaska, Inc. I 50% Spudded or W.O. begun I Date Complete I 4/13/86 Date and depth Complete record for each day reported as of 8:00 a.m. Old TD Released rig 4118186 Classlfloatlons (o11, gaS; etc.) Oil I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O. I 0300 Hrs. 0 7" @ 11,54~' 11,502' PBTD, RR Diesel Fin displ'g well to diesel. SI well, bleed off ann, orifice vlv closed. Close SSSV. Set BPV. RR @ 1430 hfs, 4/17/86. R E C E D New TD PB Depth I Date I K nd of rig 1430 Hrs. I 4/17/86 I Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data Alastm 0il & Gas Cons. 11,502' Well no. Date Reservoir Producing Interval OII or gas Test time Production OII on test Gas per day Pump size, SPM X length Choke size I T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct 5/01/86 Drilling Supervisor \ For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. STATE OF ALASKA AL{ OIL AND GAS CONSERVATION CC~ SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing .~ Time extension ~ Change approved program ~ Plugging [] Stimulate ,~ Pull tubing F: Amend order .~ Perforate [] Other 2. Name of Operator ARCO AT,ASKA, [NC. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 11Z6' FSL, 1058' FWL, Sec. 18, TllN, R15E, UM At top of productive interval Gyro Not Available At effective depth Gyro ~ot Available At tota[~t~ FSL, 1320' FWL, Sec. 13, TllN, RI~E, UM 11. Present well condition summary Total depth: measured true vertical 5. Datum elevation (DF or KB) RKB 5 2 ' feet 6. Unit or Property name Prudhoe Bay Unit/Lisburne 7. Well number L2-21 8. Permit number 85-275 9. APluz~-/_rJ'14~be"t'l 485 50-- 10'L'P~s~urne 0il Pool 11550 feet Plugs (measured) N/A 9444 feet Effective depth: measured true vertical Casing Length Structural Conductor 80' Surface 3687' Intermediate Production 10630' Liner 1117' Perforation depth: measured true vertical 11502 feet Junk (measured) 9411 feet N/A Size Cemented Measured depth True Vertical depth 20" 1810 # Poleset 119' 13-3/8" 2500sx AS 11I~' & 600sx Cl~.~s G 3687' 119' 3515' 9-5/8" 1126 sz Clogs G 10630' 8809' 7" 450sx Cl_a~ G 10423~- 11540' 866~9437' 10,734' - 10,814'; 10,842 - 10,920' and 11,122' - 11,170 8880' - 8936~ 8955' - 9009" and 9149' - 9182' (a~ approx) Tubing (size, grade and measured depth) 2 7/8", L80, 11,000' Approximat~y Packers and SSSV (type and measured depth) 9 5/8" BOT (a 10,342', 7" BOT 0 10,930' (WiM) 2 7/8"S$SV @ 2178' 12.Attachments Description summary of proposal 'j~i~ Detailed operations program ~ ¢~Fsie~h~r~ 13. Estimated date for commencing operation June 3, 1986 14. If proposal was verbally approved Name of approver Alaska 011 & Gas Cons. Commission Date approvedAnchorage 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Form 10-403 Rev 12-1-85 0060/BTK Date Notify commission so representative may witness I Approv.aI.No._., [] Plug integrity [] BOP Test [] Location clearanceI //.,.~ ,5"'--~.~ _~/~ by order of .,_, ........ Oommi.ssio.r~e,r,,..,,_ the commission Date ~ Submit in triplicate ATTACHMENT 1 L2-21 ARCO Alaska, Inc. proposes to stimulate L2-21 perforations with 300 Bbls of 15% HC1. 50 bbls will be used to stimulate Wahoo Zone 4 perforations followed by isolation of the zone, 50 bbls will be used to stimulate Wahoo Zone 5 perforations followed by isolations of Zone 5 and 200 bbls will be used to stimulate Wahoo Zone 6 perforations. The acid will be pumped through tubing and the well will be flowed back for cleanup and rate establishment. RECEIVED MAY ? 1 1986 0060/BTK WELL: 1/09/86 1/13/86 ADDENDUM L2-21 Arctic Pak well w/300 sx AS I, followed by 126 bbls Arctic Pak. Instl a 2-7/8" tbg hgr, tbg head adapter & lower master vlv. BPV in place. Drill~i~g ~Super~ntendent z D~te ARCO Alaska Lisburne En$ineerin$ To: State of Alaska ~'rom: John Boyle Dace: 6-2.-86 Transm£==ed herewith are the following: Magnetic Tape for Lisburne Well L2-21 GCT LIS 1-8-86 Run 1 Tape Number 71498 Sch ~_.~.-/-- ~~ a ff 7~- s - ~..:~J -J-~-//~t~ Receipt AcknowledsemenC: ~ , · .-.:.;~0.~'.: Re~urn R~c~ip~ ~o: .~ · ~.m O.,, ~ . ..... PO Box i0~60 Anchorage, Mas~ 99510 ARCO Alaska Inc. Lisburne Engineering To: State of Alaska John Boyle From: Pam Lambert Da=e: 6-2-86 Transmitted herewith are the following: CH Final for Lisburne Wells ~'"~L2-21 CET 1-8-86 Run 2 5" Sch ~L2-25 CET 2-6-86 Run 1 5" Sch ~-L2-29 CET 1-21-86 Run 2 5" Sch "'--L3-23 CET 2-18-86 Run 1 5" Sch Receip~ Acknowledgement: Return Receipt to: ARCO Alaska Inc. Pam Lambert ATO 477 PO Box i00360 Anchorage, Alaska 99510 Transmittal No: qql0 Alaska Oil & Gas Cons. Comm~ss~o~ Anchorage ARCO Alaska, Inc. ~i"~ Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 10, 1986 Mr. C. V. Chatterton Commi s s i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: L2-21 Dear Mr. Chatterton: Enclosed is a copy of the L2-21 Well History to include with the Well Completion Report, dated 01/14/86. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L73 Enclosure cc: L2-21 Well File ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO 'CJI'and Gas Company Well History - Initial Report- Daily Inltructioltl: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily wort< prior to spudding should be summarized-on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no. AFE 803553 Rove= t*:t. - ' Operator.- - :A~C~'~aske:~'.~ Inc', ':- - .. "11/'15/85~. 11/16/85' thru, lCounty, parish or borough North Slope Borough ILaaseADL #28307 or Unit ITltle Drill State Alaska Well no. L2-21 AP1 50-029-21485 I Date~ .... · ~ 11/12/85,_. 1030 Hra-.~. for each day reporte(L :~ ...1, - ' ' . .., .... ~-.,,., 2~:~.: ~,,~._ 1[ 9 ~ / ~.'. ,,,~ "' ,~,~ ~...,~ ,~?.. ,j.. ~ . WE~:. 9~'4~ PF'~I~V YP 67,'~ PH 8.~'.'~'/Z~: S~:8~.'.~- ~ · Ac.cep~~' r~,~ ~' 060G~'hrs.~. Z1/12/~z~..~=:~ve=r~e=; [030 .h=e. t [/12/85.,~,. D=[.. 20, e [[9.,~: 3408', (~293~)'~'~='~ DD.." ' W~'.' 9.3~ PV [~.'.YP'31~ PH, Dr1' 17%" hole ~. 2450~~ KOP% 2450~, Ass~ed vertical 2566~. 5.7=. S70.3W, 2565.8[ ~.~,:~ 5~5.7.VS.'~.' [.94S, ~.43W 2967.~. [5.2~, S76..TW, 2959.56:.T~, 78.SZVS'~ ~2.33S, 77.83W 3278~ 2~.47~ S75.9W, 325~.6E~T~%..~ 175.36".VS~ 30.48S,,. 173.71W 4240~. (832~), W~pe. hole W~ 9.5, Pr. 24~ YP'~ 34,~ PH 8.9% ~' 25+~ Sol 9 D=i ~7~" hole ~.42407~ c~rc & w~pe hole. ~5 s=ds. 3433',~ 25°, S8~'~,9~"~:~ 3397.12 T~', 236'.23 VS~ 42.75S, 233.49W 3919'~,..38.8=, S7~:~:[3811.74 T~, 485.83 VS, 84.67S, 480.65W 4215', 4~.8=' S.79:',8~%~"~4039'.57 T~., 673.70 VS, 120.04S 666 24W 13-3/8" ~ 36877~?~':: . 5510', (1270'), Drlg Wt., 8.9+, PV 3, YP 4, PH 11.9, ~ 25+, Sol 4 CBU, POH. RU & rn 93 its,. 13-3/8", 72#, L-80 BTC csg. Stuck csg ~ 3687'. Att to wrk free. Circ. Cm~ 13-3/8" csg w/FS 3687', FC ~ 3602' w/2500 sx AS III, followed by 600 ax C1 "G'" w/2% CaCi~. CIP ~ 0200 Hfs, 11/16/85. ~ diverter sys. NU & tst BOPE.- RIH w/12k" B~, tag plugs ~ 3596', tmt csg to 3000 psi. DO FC & cmt to 3650', tst csg: to 3000 psi. Drl FS & cmo to 3697'. Conduct fo~ation ts~ to 11.5 ppg ~. Drl & surv 12k" hole to 5510'. 4485', 43.0=, S78.1W, 4238.95 T~ 854.24 VS, 154.93S, 844.91W 4976', 43.6~, S76.3W, 4596.29 T~, 1186.81 VS, 229.53S, 1173.27W 5285', 43.0~, S77.0W, 4821.17 T~, 1396.47 ~S, 278.46S, 1379.46W I^.co w.,. 50% Prior status if a W.O. The above la correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 1/27/86 ,ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Inmtructlons: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheetS when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field Alaska County or Parish [State North Slope Borough Alaska Lease or Unit IWell no. ADL #28307 I L2-21 Prudhoe Bay Date and depth as of 8:00 a.m. 11/19/85 11/2o/85 11'~21/85 11/22/85 11/23/85 thru 11/25/85 Complete record for each day while drilling or workover in progress 13-3/8" @ 3687' 6862', (1352'), Drlg Wt. 8.9, PV 3, Y? 6, PH 9.8, WL 21, Sol 4 Drl & surv 12¼" hole to 6862'. 5746', 41.4°, S77.7W, 5162.67 TVD, 1703.36 VS, 346.27S, 1681.59W 6296', 41.8°, S82.8W, 5575.47 TVD, 2065.94 VS, 407.04S, 2039.79W 6572', 42.1°, S84.0W, 5780.74 TVD, 2250.39 VS, 428.25S, 2223.07W 13-3/8" @ 3687' 7918', (1056'), Drlg Wt. 9.3, PV 7, YP 6, PH 9.0, WL 9.0, Sol 7 Drl & surv 12¼" hole to 7918'. 6818', 42.1°, S85.1W, 5963.25 TVD, 2415.31VS, 443.91S, 2387.24W 7155', 42.2°, S84.7W, 6213.10 TVD, 2641.44 VS, 464.01S, 2612.50W 7645', 41.7°, S84.4W, 6577.53 TVD, 2968.95 VS, 495.12S, 2938.57W 13-3/8" @ 3687' 8801', (883'), Pmp pill Wt. 9.6+, PV 9, YP 11, PH 12, WL 8.2, Sol 9.5 Drl & surv 12¼" hole to 8801', converted mud sys to low lime, raise wt to 9.6 ppg @ 8500'. Rtns gas cut to 8.6 ppg. 8013', 39.3°, S84.0W, 6857.34 TVD, 3207.86 VS, 519..28S, 3176.33W 8571', 38.7", S85.1W, 7291.99 TVD, 3557.76 VS, 549.76S, 3524.89W 13-3/8" @ 3687' 9225', (424'), Drlg Wt. 10, PV 7, YP 7, PH 12.3, WL 7.2, Sol 11.5 POH, tight f/8801'-7950'. Chg bits, RIH, rm 70' to btm, drl to 9225'. 8766', 38.0°, S85.1W, 7444.92 TVD, 3678.75 VS, 560.10S, 3645.44W 9064', 40.1°, S86.1W, 7676.33 TVD, 3866.46 VS, 574.50S, 3832.61W 13-3/8" @ 3687' 10,650', (1425'), Prep to rn 9-5/8" csg Wt. 10, PV 13, YP 11, PH 11.4, WL 5.2, Sol 11.7 Drl & surv 12¼" hole to 10,650', 25 std wiper trip, C&C, POH. Chg rams to 9-5/8". RU to rn 9-5/8" csg. 9,189', 40.9~, S89.0W, 7771.38 TVD, 3947.48VS, 577.97S, 3913.71W 9,515', 43.5°, N89.6W, 8013.38 TVD, 4164.97VS, 577.09S, 4132.12W 9,812', 44°, NS1.SW, 8227.92 TVD, 4365.18VS, 561.62S, 4336.76W 10,595', 46°, N78.SW, 8784.55 TVD, 4896.87VS, 470.37S, 4879.'73W The above is correct Signature For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 IDato 1/27/86 ]Tit,o ' Drilling Superintendent ~uapua~uta~dns 13;)J~O0 S? e^oql~ eq.L Ia~ 'Tsd 000g o~ deI auI ~ auI .£ =s~ ~,[£g~II ~ ~m~ Iap ',0~II o~ ~m~ O0 ~adaos ~s~ .[/~Tq .9/m HIM euIaq ID~N Hdd ~'6 · 08I'OI 03 3mo He3 'adaos Hso ,,8/g-6/a HIM 'gS/~/gI 'saq 099I ~ &I3 'sdmd HIa HuIsn IdsId '99-d %E' %gG/a .O. ID xs Og~/a 3mD ~ D&/a DIE 09-I '#68 '.~ '~ ux H,puoo ~Me~ ',O006-,gSg~OI/g 03 ?ND/a 3uoo '(sassed o3 HOE 'OaTO 'aoqs .8/§-6 o3 0I IoS 'g'0I ',Zg0'II 03 eloq ,,%8 Iad 'MI4M Hdd g'3I 03 383 uoI3eu~o[ 3onpuo9 · s~pIaoIqD muI '3a prim aeaoI 9 ~aI~ ',8~9'0I o3 asu + S~ 'Sm= 'D& Od 'Isd 00gG o3 Hs~ 383 ',£9~'0I ~ D~ o~ HIM ,6g9'0I ~ · 3mo OG 03 VI{E ,,%8/a HIM 'gS/gg/II 'saq OGEE %I' 9 ~uesa~dsIp g~-d %G' '009-d xs/Ie$ g'I/a ,,O. ID x$ 9ZII/a 3mD ',OG9'OI ~ S&/a Hso D&E 09-% '#£9 ',,8/g-6 '83~ 6gE uN g'II los VI~ ,,%8/a HIM '(,0) ',089'0I sseJ§oJd u! Je^o~fJO~ Jo §uHIPP ellq~ Asp qoee JOl pJooeJ elelduJO: · w'~ 00:9 lo ss u~,dep pue elsQ 'ou Ileal e~ISelV I qHnoao~ edols q3~oN e~selV · uoileldWOo I?lUn §upls I?O lo §U!lles §u!~OllOJ pue sJe^oNJo~ JOi AINee~ liuJqns 'les s! 5u!JlS I!o qoiq~ u? Nea~ eql 1o Aepseupe~ uo (~) JO 'sAep OS AJe^e ueqI ~[I),UenbeJI SSel lou lnq lno PelH) ueq~ sle;)qs ,.wiJeiUl,, l!wqns (L 'LuJo; ,.IIUpL. uO lSel e^iielueseJdeJ Jo le!O!iio IJodeld 'uo!leldU~OO laU!t I!iun sleeqs ,.wtJelUl,. uo pe~odeJ eq II}~ uo!loeS §u!onpoJd Aq pel,uJojJed ~JoN~. '$eJOO iie~o uo!3d!JOsep q3~11¥ 'Ail~!luenbes slsel ~uels II!JP lie JequJnN · pe~JJOjJed ~Jo~ I~u!q!Josep uj eLueu uo!leuJJoj ~oqs '§u!leJojJed JO '§u!Joo '§ullsel Jl 'suoNsJedO Je^O~JO~ Jo §U!ll!JP §u!Jnp pesn s! LuJOj $!q.L :luoNOlUilUl tupeluI--AJols!H lie/IA AlIeO Auedmoo sel3 pue I!O OOtiV ARCO Oil and Gas Company Daily Well History-Final RePOrt Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged. Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Filial Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District ICounty or Parish State Alaska [ North Slope Borough Alaska Prudhoe Bay ADL #28307 - Auth. or W.O. no. [Title AFE 803553 [ Drill Rowan #41 Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. hegun [Date Spudded 12/04/85 Date and depth as of 8:00 a.m. Complete record for each day reported 1/08/86 API 50-029-21485 W.I. ~otal number of wells (active or inactive) on this Icost center prior to plugging and 50~ [abandonment of this well I IHour I Prtor status if a W.O, 11/12/85 / 1030 Hrs. I / 7" @ 11,548' 11,502' PBTD, RR 9.4 ppg NaC1 brine w/diesel cap LD DP, leave 410' diesel cap. Fin LD DP, chg rams to'5". BOPE. NU & tst tree. RR @ 2400 hfs, 12/3/85. Arctic Pak'd well w/300 sx AS I. Old TD I New TD PB Depth · [ 11,550' Released rig ~Date Kind of rig 2400 hfs, I 12/03/85 Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Lisburne Potential test data ND 11,502' Rotary Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Signature Date ITItle For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Alaska, Inc. {. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 17, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: L2-21 Dear Mr. Chatterton' Enclosed is the Well Completion Report for L2-21. The bottomhole location, TVDs, geologic markers, and tubing details will be submitted when the gyroscopic survey is run and the well is completed. Also, I have not yet received the Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU13/L07 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ' STATE OF ALASKA ALASK{ . AND GAS CONSERVATION (~. /IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED I-~x ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-275 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21485 4. Location of well at surface 9. Unit or Lease Name 1726' FSL, 1058' FWL, Sec.18, T11N, R15E, UH Prudhoe Bay Unit/Lisburne At Top Producing Interval 10. Well Number To be submitted when gyro is run. L2-21 At Total Depth 11. Field and Pool To be submitted when gyro is run. Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool 52' RKB ADL 28307 ALK 2317 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore I 16. No. of Completions 11/1 2/85 11/28/85 1 2/03/85 N/A feet MSLI N/A 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 11550'MD 11502'ND YES [] NO []X N/A feet MD 1900' (approx) 22. Type Electric or Other Logs Run LDT/CNL/NGT, LSS/Waveforms/GR, DLL/MSFL/GR, EPT/ML/GR, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD :CASINGSlZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surf 119' 30" 1810# Poleset 13-3/8" 68.0#/72.(1# K-55/L-80 Surf 3687' 17-1/2" 2500 sx AS Ill & 600 s~ Class G 9-5/8" 47.0# L-80 Surf 10630' 12-1/4" 1126 sx Class G 7" 29.0# L-80 10423' 11540' 8-1/2" 450 sx Class G , . 24. Perforations open to Production ('MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) None N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas :lift, etc.) I Date of Test Hours Tested ,TEsTPRODUCTIONpERIOD II,FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing :Pressure !CALCULATED -'~1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneE C E'i ,V'EB , Alaska Oil & Form 10-407 TEMP3/WC42 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. ~ 30. GEOLOGIC MARKERS FORMATION TESTS · NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A N/A 31. LIST OF ATTACHMENTS Non~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~O ~ ~ Title Associate Engineer Date .INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 TEMP3/WC42a :AE! pe~namo::) e~/~/-~ :~8 p~D~o"l g6~Tt 'ON o:)uoJoj, oti clop uop, eOO'llPle!-.I etueN IleM ~,uedwoo SnOnNllNO~ ~oNYaln~ GCT- OIqECTI3NAL. SURVEY CUSTOMER LISTIN~ FOR ' ARC3 ALASKAp. 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N~N~N~ eeeeeeeeee eeeeeeeeee lee leeeeee NNNNNNNNNN MN~~mMN~ .eeeeee~e eeeloeel oeeloee,e .eleeeeoe ooooo°oo NNNNNNN~ NNNNNNN mmmmmmm · · · e · · e,e ~ ~0 0oo0000o~ 'TI zmr' ;l:zm x~ %~'~n -i1 ~. · ~r" ,-,ll.,l I- rn 'TI 0 0 Z ITl m m ti ,. Z'~l- ,=¢01~ r- m I-'HIM Ill I'll C m r m -.,I m ITt ti I I ~1, rtl o uJ O~ ~eeeeeeee oo~o~oo OJluJ tr~ o 0cl.-uJ i~. :~ r,, :]:: ..e SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL L I SBURNE L2-21 F I ELD PRUOHOE BAY/L I SBURNE COUNTRY USA RUN DATE LOOOEO 08 - JAN - 88 REFERENCE 0000?]498 O00Z 000! 0 000[- 0002- O00E- 000~- O00S- LS~M 0009- O00k- HLnOS O00E- 000~- 000[ - 000[ 0005 NOIJ. DH£O%{~ 'I~.~.NOZ IHOH 8~ I t0000 ~ ' N. II& ' 8I ' D.~S ' 'IM.~, 8SOI "IS.~, 9ELI IE-E~ : 'I'IHM 000¥ H~ 85. (SURFACE: 1726' FSL, 1058' FWL, SEC. 18,TllN,R15E,UM) VERTICAL PROJECTION PROJECTION ON VERTICAL PLANE 2B5. - 85. SCAL.£O IN V£RTICAI. O£PTHS HORIZ SCALE = 1/1000 IN/FT Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. · . OPERATOR, WELL NAME AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report y Well History Samples ,. Hud Log ,~ ........ ., , Core Chips ,.. .~4.~U/~ , , , ,,, , , , , , Registered Survey Plat Inel~nst~on Survey , . .~ Production Test ReportsI ~igiC~z~d Data ARCO Alaska, InC. B91 Post Office 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the December monthly reports for the following wells: 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 L2-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 L3-5 1A-14 2H-8 3A-15 3F-14 4-23 16-19 L3-!9 1H-4 2H-9 3A-16' 3F-15 4-24 16-20 1H-8 2X-8 3F-11 3J-10 4-27 :L2~21 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 ' Enclosures RECEIVED JAN 1 4 198G Alaska 0ti & Gas Co~s. Uommis~0~ ARCO Alaska. Inc. is a Subsidiery of AtlanlicRichfieldC, ompany STATE OF ALASKA ,¢, ALASKA O(_ AND GAS CONSERVATION COI~ .ISSION MONTHLY RE,OR1' OF DRILLING AND WORKOVER OI:IER&TIO#$ 1. Drilling well ~ Workover operation [] :2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-275 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21485 4. Location of Well at surface 1726' FSL, 1058' FWL, Sec.18, T11N, R15E, UM J 6. Lease Designation and Serial No. ADL 28307 ALK 2317 For the Month of December , 19 85 5. Elevation in feet (indicate KB, DF, etc.) 52 ' RKB 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L2-21 11. Field and Pool Prudhoe Bay Fi eld Lisburne Oil Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hrs, 11/12/85. Drld 17-1/2" hole to 4240'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,471'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,550'TD (11/28/85). Ran logs. Ran Cmtd, & tstd 7" csg. PBTD=11,502'. Secured well & RR ~ 2400 hrs, 12/03/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests ¢ 20", 91.5#/ft, H-40 weld conductor set ~ 119'. Installed w/1810# Poleset. 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe @ 3687'. Cmtd w/2500 sx AS Ill & 600 sx Class G. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe ~ 10,630'. Cmtd w/1126 sx Class G. "7", 29.0#/ft, L-80, BTC csg f/10,423' - 11,540'. Cmtd w/450 sx Class G. 14. Coring resume and brief description None 15. Logsrunanddepthwhererun LDT/CNL/NGT f/11,543' - 10,622', CNL to 3687' LSS/Waveforms/GR f/11530' - 10,622' DLL/MSFL/GR - depths not available EPT/ML/GR f/11,518' - 10,622' CET f/10,585' - 9000' 16. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED /~~ ~ TITLE Associate Engineer DATE. //~4~ '~ NOTE---Repo~/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEHP2/HR10 Rev. 7-1-80 Submit in duplicate ARCO A.l,a ska i'~ Lisburne Engineering TO ** Address: Para Lambert State of Alaska From: - i i ,, January 2, 1986 3001 Porcupine Dr. DaCe: C.V. Chatterton Anchorage, Alaska 99508 A~t~: Tranm~.cted herewith are the followin~: OH Magnetic Tape for Lisburne Well L2-21 OH LIS 11-30-85 Run 1 Tape Number 71045 Sch ~~ ~ ~'?o '~ .s ~ ~en-~ ~_~-g'~ -//--~/ Receipt Acknovledgenenc: Da=e: Return Rece~.pt to: Transmittal No.: Processed by: AIIICO Alltl~l. 18c. in · Sul)O,4Jlor¥ of Atllmtlcliilci~fioidComl0lnY ARCO Alaska Inc. Lisburne gngi~eering Attn: Pam Lambert ATO 477 P.O. Box 10036Q ~I.~ Anchorage, Alaska 99510 ARCO M. asica Lisburne En$ineerin$ TRANSMITTAL To: Address: State of Alaska 3001 Porcupine Dr. Anchorage Alaska 99508 DaKe: ! Ac:n: Tranea~Ltted herevith are the following: Para Lambert -- December 20, 1985 C.V. Chatterton OH Magnetic Tapes for Lisburne WEll L2-21 ~<aOH Lis (Unshifted) 11-30-85 Run 1 Tape Number 71045 Sch Receip~ Acknovledsemenc: Re~urn Receipt Co: ARCO Alaska Inc. Lisburne Engineering Aeon: Pam Lambert ATO 477 P.O. Box 100360 Anchorage, Alaska 99510 Trans~L==al No.: Processed by: ,,, ARCO Alaska Inc. Lisbu~ae Engineer~ng State of Alaska From: 3001 Porcupine Dr. Date: , , , Anchorage, Alaska 99508 Transmitted herewith are the following: Pam Lambert December 16, 1985 C. V'. Chatterton OH Final Logs for Lisburne Well L2-21 ~DLL/MSFL-GR 11-30-85 Run 1 2"&5" Sch ~EPT-GR 11-30-85 1 2"&5" Sch Mircolog-GR 11-30-85 1 2"&5" Sch LSS-GR 11'29-85 1 2"&5" Sch '"'-,L~SS/WF 11-29-85 1 5" Sch ~Natural GR Spectroscopy 11-29-85 Run 1 2"&5" Sch ~LDT/CNL (Raw) 11-29-85 Run 1 2"&5" Sch "-LDT/CNL (Poro) 11-29-85 Run 1 2"&5" Sch '~CET 11-30-85 Run 1 2'&5" Sch ~CNL in Casing 11-29-85 Run 1 2"&5" Sch Receipt Acknowledgement: Return Rece%pc to: ARCO Alaska Inc. Lisburne gngimeering Attn: Pam Lambert ATO 477 P.O. Box 10036Q Anchorage, Alaska 99510 Transm/ttal No.: Processed by: AItCO Alll#l. Inc. ti · Sul~l~clllry of AIIintlcllllchfleldComlllfly ARCO Alaska, Inc. Post Office Bo{~ 0360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 December 13, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the November monthly reports for the following wells: 2H-9 3A-11 3F-8 4-22 16-19 2H-10 3A-12 3F-9 4-29 L2-3 2H-11 3A-13 3F-10 16-7 L2-21 2H-12 3C-6 3J-9 16-15 L3-15 3A-10 3F-7 3J-10 16-18 WSP-12 WSP-20 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU12/L129 Enclosures £CEIVED 1 x Al,~sk~ 0~1 d, Gas Cons. Con~rnisslot~ Anchorage . ' ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfleldCompany. .. CONFIDENTIAL STATE OF ALASKA ALASKA~'~''._ AND GAS CONSERVATION COt.'.~'' ~ISSlON MONTHLY REI ORT OF DRILLING AND INORKOVER OI ER&TION$ · Drilling well ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-275 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21485 4. Location of Well at surface 1726' FSL, 1058' FWL, Sec.18, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 52 ' RKB 6. Lease Designation and Serial No. ^DL 28307 ALK 2317 9. Unit or Lease Name Prudhoe Bay Unit/Lisburne 10. Well No. L2-21 11. Field and Pool Prudhoe Bay Field Lisburne Oil Pool For the Month of November ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 1030 hrs, 11/12/85. Drld 17-1/2" hole to 4240'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,471'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 11,550'TD (11/28/85). Ran logs as of 11/30/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#/ft, H-40 weld conductor set ~ 119'. Installed w/1810# Poleset. 13-3/8", 68.0#/72.0#/ft, K-55/L-80, BTC csg w/shoe @ 3687'. Cmtd w/2500 sx AS Ill & 600 sx Class "G". 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe ~ 10,630'. Cmtd w/1126 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run LDT/CNL/NGT f/11,543' - 10,622', CNL to 3687' LS$/Waveforms/GR f/11530' - 10,622' DLL/MSFL/GR - depths not available EPT/ML/GR f/11,518' - 10,622' CET f/10,585' - 9000' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. A!aska, 0it & SIGNED ~/t'")_~~ .~~~ TITLE Associate Engineer DATE NOTE-~Report~/n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP2/MR64 Rev. 7-1-80 Submit in duplicate MEMORANOUM TO: THRU: State of Alaska ,., Lonnie C. Smith Commissioner FROM: Bobby D. Foster~~-,-- SUBJECT: Petroleum Inspector ALASKA~.~IL AIqD GAS CONSERVATION CO~IISSION C. V/~t~/~erton DATE: November 22,1985 Chai~M~fi-~ ,?., F.LENO: D.BDF. 122 TELEPHONE NO: BOPE Test ARCO P.B.U. L2-21 Permit No. 85-275 Lisburne Oil Pool Saturday and Sunday, November 16 and 17, 1985: The BOPE test began at 10:00 PM and was c0'nClUded-at"6:'0'0"-AH',"'November 17, 1985. As the attached BOPE test report shows, there were four failures. Three of the failures were corrected while I was on location. I was notified later in the day that the electric pump had been repaired and was operating properly. In summary, I witnessed the BOPE test on ARCO's L2-21. Attachment 02-00IA(Rev. 10/79) ~ ,'. O&G 1t4 5/84 ' STATE OF ALASKA ' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Location, General ~~ Well General Hous ekeepin~Rig Reserve Pit Mud Systems Visual Audio Trip Tank Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures ACCUMULATOR SYSTEM Full Charge Pressure ~~ psig Pressure After Closure /~~ psig Pump incr. clos. pres. 200 psig -- min~ sec. Full Charge Pressure Attained: ~ min./~ sec. Controls: Master Kelly and F.loor Safety Valves ' Upper Kelly / Lower KellX Ball Type / Inside BOP Choke Manif~l~~_~ Tes No. Valves No. flanges 3 ~ Adjustable Chokes Hydrauically operated choke Test Time ~ hrs. Test Pressure ~ Test Pressure ~'~ Test Pressure ~ Test Pressure ~'-~ t Pressure Repair or Replacement of failed equipment to be made within day~ and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc -'Operator cc - Supervisor Inspector ~__ ARCO Alaska, Inc ..... Post Office r~ i00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 6, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Co'nductor As-Built Location Plat - L2 Pad (Wells 3, 7, 17, 21, 25, 29, 33) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~]. Gruber Associate Engineer JG/tw GRU12/L77 Enclosure If RECEIVED A!aska Oil & Gas Cons. Ge~,~m!ssmn Anchor~,ge ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 360 035 34o 30o o~ o I~ W o 8;o ~o o'11 I0o o9 8o ~o 4o P Grid ' orfh Cond. ASP ZONE 4 ;5 Y = 5 96;5 094.70 X'- 69~. 870. 82 7 Y= 5 96;5 ;570. 88 X= 692 807. 0;5 17 Y = 5 96;5 50;5.78 X= 692 776. ;54 21 Y= 5 963 620..77 X= 692 749.45 2.5 Y= 5 96;5 7;57. 69 X= 692 722. 59 29 Y= 5 965 854. 62: X= 692 695.4;5 ;53 Y=596;5 97'1.60 X= 692:668.4.6 VICINITY MAP SECTION' 18 OFFSET WLO SLO LAT= 70018' 15.0931" !166 !197 LONG =148°26' 15.1425 ' LAT= 70° 18',15.8Z46: 1109 1475 ' LONG= 148°26 16. 7877 LAT= 70° 18' 17'. 1;591 '~ 1082 1609 LONG= 148°26'17. 5902 LAT= 70°18' 18.2962" !058 1726 LONG= 148°26°18.2866" LAT'- 70018' 19.4527" 10;554 184;5 LONG: 148°26'18 9879" LAT= 70°!81,20.6091" I010 1961 LONG = 148°2.6 19 6866" LAT= 70°18'21.7611" 986 2079 LONG = 14 8°26'19.802;5' LEGEND ~,.0- WEST U~ OFFSET SLD._-.SCU'D./ LINE OFFSET (:~) .- C~RS AS-BU/LT : ~r-- TH;S SURVEY. CERTIFICATE OF SURVEYOR ! HEREBY CERTIFY THAT I 'AM PROPERLY REGISTERED AND .'. LICENSED TO PRACTICE LAND SURVEYING IN THE STATE 0~.~ L! ALASKA AND THAT THIS PLAT REPRESENTS A LOC,AT'O~~' E CE i__ E D SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT:.i~DV~-,~ ~ 0 ~3~'~ ~!~P,~,, DAyE & Gas Cons. Co~.i Anchorage SURVEYOR NOTES I. COORDIN.4TES ARE "FLUOR" ASP ZONE 4 PER ER. EELL DWNG DRILL SITE L -- 2 , 9-21- 85 ARCO No. ARCO Alosko, Inc. AS- BUILT DRILL SITE L-2~ CONDUCTORS LOCATED IN PRO~ED SECTION 18, TilN~ RISE U.M. PREPARED BY '~'~OUNSBURY 8[ ASSOCIATES, INC. 723 W6fh AVE.~ ANCHORAGE,ALASKA DATE ! 10/~i9~,51 1SCALE.._I"= 300' I , CHKD. BY: GEL FLD. BK.: L.HD85-101 ixoaol '7 Sno~ 'a~ · iouo o/a uoT~ao.suoD ieJuo~uoxT~u~ ~o · IOUO o/~ uo~ooS ~q~H 'o~ ~ qsT~ ~o oq uosssTumao3 uoT~Aaosuos s~O pu~ 170 'e:~s~'IV ~o u~m:~!~q3 'adTd ao~onpuoo oq~ ~o oo~s og~ mOlOq ~u!ii!ap aao~aq ~u~so~ ssou~ ~m uo~ss~uauoD aq~ ~q~ os uo~ti~suT ~uomd~nbo ~uTouommoo o~ ao~d sanoq ~ a~o sTq~ X~T~ou osI~ oS~old 'poaInboa s! mo~sXs ~o~aaaIp ~ oxoRM 'POlI!aP s! ooqs oq Xmm uo!ss!~uoD oq~ ~o oA!~m~uoso=d~a w ~wq~ os ~uomd!nbo uo!~uoAoxd ~nomoiq oq~ $o uo!~mii~su! ~u!ouommoo o~ xo!xd sanoq ~g ooIg~o s!R~ X~!~ou oswoId 'Maom pIo!g ~u!Inpoqos u! sn p!w o% ItOm aq~ ~ suoi~'~modo ~u!ouotamoo o:~ aoIad so!ouo~ I~:~uomuxoAo~ aoq~o ~uo~.~ m~I Xq pox!nbo~ s:~.~mxod I~UO!~.pp~ u!~:~qo o~ poou olq~qoctd oq:~ moai~ no,{ ~{~!umopuT ~ou soop Ii!ap o~ ~-~maod · IlOm poouo~o~oa oaoq's aq~ II!:tp O~ ~!taaod :to~ uot~wo!Iddw poAomddm oq~ s! posolouM 09g0-0I~66 ~ts~tv 'o~aoqvuv 09g00I xo~t '0 'J 'ouI '~:ts~IV 0D2IV aoou!~u.~ 8uIilI~ ':tS uopooa~ 'M uoti 'x~ g96I '8 xoqmoAON ARCO Alaska, Inc. {[ Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 8, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Lisburne L2-21 Permit to Drill Dear Mr. Chatterton- Enclosed are' An application for Permit to Drill Lisburne L2-21, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore Diagrams showing the proximity to other wells in the area. There are two wells passing within 200' of L2-21, as discussed in the application. A diagram and description of the surface hole diverter system o A diagram and description of the BOP equipment ° A copy of the certified "As-Built" conductor survey We estimate spudding this well on November 11, 1985. If you have any questions, please call me 263-4963. Sincerely, D. E. Breeden Senior Drilling Engineer DEB/tw PD/L189 Enclosures RECEIVED Nov o Alaska OiJ & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AHanticRichfieldCompany L STATE OF ALASKA Oil',, ALASKA ,- AND GAS CONSERVATION C ,vllSSlON PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~]X lb. Type of well EXPLORATORY [] SERVICE [] STRATI~R/~51-~,I~7~"~ '" [] REDRILL [] DEVELOPMENT OIL i-~X SINGLE ZONE ~](X ~' DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ~ 2. Name of operator ARCO A1 aska 3. Address ~;',' P O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 1726' FSL, 1058' FWL, Sec.18, TllN, R15E, UM Prudhoe Bay Unit/Lisburne ~'~ At top of proposed producing interval 1327'FSL,1409'FWL, Sec.13,T11N,R14E,UM 10. Well number At Target ~ 8952'TVD:1320'FSL, 1320' FWL, Sec.13, T11N, R14E, UM L2-21 At total depth 11. Field and pool 1286' FSL, 897' FWL, Sec.13, T11N, R14E, UM Prudhoe Bay Field -- 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Li sburne 0i 1 Pool RKB 52' PAD 13'I ADL 28307 ALK 2317 , 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 7-1/2 mi. N of Deadhorse miles 1058' ~ surface feet L2-20wel1178' @ surface to 2385' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 114:34 ' MD, 9427 ' TVD feet 2560 11/11/85 - 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 3420 psig@'__b~__'Surface KICK OFF POINT 2450 feet. MAXIMUM HOLE ANGLE 42 o l (see 20 AAC 25.035 (c) (2) 4490 psig@ R9_~2 ft. TD (TVD) ./ 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT '-Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 30" 20" 91.5# H-40 Wel¢ 80' 39' I 3~- 11'9' II 119' 2000# Poleset 1~-1/2" 13-3/8" 68.0# K-55 BTC 70' 39' I I. 39' .1.09' I 109' 3000 sx AS Ill Lead & 17-1/2" 13-3/8" 72.0# L-80 BTC 4043' 109, ~ 109' 415'2' I 4000' 400 sx Class G Tail 12-1/4" 9-5/8" 47.0# L-80 BTC 10586' 37' II' 37' 10623' I 8822' 750"G"/300AS I&ArcPack 8-1/2" 7" 29.0# L-80 BTC 1011' 10423'. .. I~ 8673' 11434' II 9427' 300sx65%"G'"-35%Poz 22. D~scribe proposed program: ARCO Alaska, Inc., proposes to drill this Lisburne development well to approximately 11,434'MD (9427'TVD). It is planned as a Wahoo production well. A surface diverter will be installed and operationally tested prior to spud. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 13-3/8" surface pipe. It will be tested to 5000 psi (3000 psi for annular) upon installation and weekly thereafter. We plan to set 9-5/8" casing just above the Wahoo and a 7" liner across the Wahoo production interval. Selected intervals will be logged. A string of 2-7/8", 6.5#, L-80, EUE 8rd tubing, including provisions for subsurface safety equipment, will be run with the packer set above the Wahoo. Selected intervals in the Wahoo will be perforated and reported on subsequent reports. (see attached sheet) .23. Ihc. reby certify that the foregoing is true and correct to the best of my knowledge SIGNED TITLE Sr. Drilling Engineer DATE . . The space below for Commission use CONDITIONS OF APPROVAL Sarnplas required '- Mud log required Directional Survey required I APl number ~YES ~.NO I-lYES ~NO /~.y E S ~NO I 50-~ ~'7-~~ -h / ¥'rr~'- l-'e~mi't number /r ,- ,~ Approval date ~,j ~-?~ SEE COVER LETTER FOR OTHER REQUIREMENTS ............................... 5 , ?' //././//, [ .... i:::"*i::~:{;}~,EDBY.( ........ _// /'./~ /.~/..~,~ -~ ,COMMISSIONER DATE ~OVCm~e~' 8 IQR~ [ ~~ / ' ~_I, ' ~~~ by order of the Co m mission Fo:'rr: '10-401 (DEB) PD/PD18'~' Submit in triplicate i I...:: v. 7-1 -,80 PERMIT TO DRILL L2-21 (cont'd) Non-freezing fluid will be left in all uncemented annuli within the permafrost interval. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well prior to Arctic Pack operations (approx 130 bbls Arctic Pack on top of 300 sx Arctic Set I cement). That annulus will be left with a non-freezing fluid during any extended interruption in the disposal process. The maximum anticipated surface pressure of 3420 psig @ 40°F was calculated from the Wahoo datum pressure of 4490 psig ~ 8952'TVD and 183°F. It assumes a 300' oil column to 8652'TVD and a gas column from there to surface, gas temperature and compressibility effects considered. A similar calculation, assuming a full gas column and original reservoir pressure in the Sag River sand @ 8169'TVD, yields a maximum surface pressure of 3320 psig ~ 40~F. Such surface pressures could occur only if 9-5/8" casing had been set. With 13-3/8" casing set ~ 4000'TVD, the maximum anticipated surface pressure is 2440 psig, based on a 13.7 ppg EMW pump-in gradient at the shoe and a gas column to surface. Our formation leak-off test history, for surface pipe set at similar depth, shows a 11.5 to 13.7 ppg EMW pump-in gradient just below the casing shoe. Well L2-21 is within 200' of wells L2-20 and L2-24. Respectively, those wells are 178' and 197' from L2-21 at the surface. The wells run parallel to the various kick-off points. Wells L2-20 and L2-24 were drilled to the Northeast from kick-off points at 2385' and 4090', respectively. Well L2-21 will head nearly due West below its kick-off point at 2450'. There are no other wells within 200' of L2-21. RECEIVED IOV 0 8 AlasKa Oil & Gas Cons. Commission Anchorage 1000 2000 3000 4000 5000 6000 7000 80OO 9000 L2-21 o iooo (' ~.ooo ~ooo ~ooo i ,oo 6000 7000 0 .~ ....... I I 11111111 ............ I I I I i I I ..... I I I I i I I I t I I I i I I , , ~ , I ~ i Z0' CONDUCT')R TVD ' 119 ARCi3 AL. ,SKA, INC. :CALl= I IN = 1000 FI. SHL: 1726' =SL, IO§8'FVIL, 2.5 COP TVO - 2450 SEC.18, "11N, R15E, U VI 7.5 THL: 1320' FSL, 1320'F~fL, ~. 125 ~F~_13, "1!N, R14F~ ti ~ 17.5 2.5 37.5 ~1.8 E0.C .TVD ' 3978 MD - 4123 OEP ' 584 13-3/,~' SURFACE T'ID = 4000 MO = 4152 OEP ~ 003 K-16 TVD ~ 4820 MD -- i262 DEP -- 13'.17 S 86 DInG 22 MIN W 5034 F'~(TG TARGET) AVERA6E ANGLE K-10 TVD 6962 MD"8113 DEP '3241 K-6 TVD - 7[i52 MD - 8918 DEP -- 3782 LCU T'/D ' 8102 MD ' 9666 DEP ~ 4274 ~ ' ' SAG RIVER ~'VD~8169 ME ~9746 DEP, 4334 SADLEROCHll TVD ~ 8277 ~ID - 9891 DEB - 4430 KAVlK TVD ~ 8~'32 MD = 105C 2 DEP ~ 4838 9-5/8' C~SING TVD - 6822 MD - 106' ~3 OEP - 4918,6: VrAHOO TVD = 9862 MD =10 t63 DEP = 484 TD-7'CSG.PT ~'VD -- 9426 MI) - 11434 DEP ~ 5468 RECEIV[D Alask'~ Oi~ & Gas Cons. Anchorage I I I , , I I , , , I , I I I , I , , , I , , , , , I I I , , , , I I I I I I I , , , Ill II t , I I I ; I , I 10000 11000 0 -- 1000 2000 3OOO 4000 5000 6000 7000 8000 9000 10000 11000 1000 2000 301)0 4000 5000 6000 7000 VERTICAL SECTION -8000 ~. - W COORDINRTES -7000 -6000 -5000 -4000 -3000 -2000 - 1000 0 1000 0 0 w CD CD CD Z ! ! , ! i , , , , , , i , , , , , , , , ! ! , , i i i I i i i i i i ! i i ~1-11 17")R'1=~1 I(1RR'I rVVI I SEi :.18,,T11N, R1fE, IM ~ THI 1320'FSL, 1320'1:WL, ] SEI :.13, TllN, R14E, IM . - ~ FARGET ] rVD -- 8952' ' rMD -- 10797 )EP -- 5034' . . -8000 -7000 -6000 -5000 -4000 -3000 -2000 -1000 0 1000 E- N COOROINRTES R [ C [ ! V E D Alaska Oil & Gas Cons. Commissbl'~ Anchorag~ S.q£WNIOWO00 M - .~ 0001 0 0001 - 000~- 00 O ~.- 000~- O00S- 0009- O00Z- 000@- Illlll~* Illllllll Ill llll' Illllllll Illlllll' Illllllll IIIIIIIII IIIIII II Illllllll I I I ~ · I ,. I Z i I 000I 0 000I- 000~- 000£- O00k- 000~- 0009- O00Z- 000@- o £ - N COORDINBIES o-~OO -~oo -2o,~.' - oo o oo, ~,. 2o0 ~oo ~oo 0 ''''''''' ~~'''''' · IIII I IIIIIIIII ,,,,,i,~, ,i~ ,,,~ t,IIII I I ~ I I I I ' ~ ~ L2-2'~ ~510 739 ~2-20 z 389 ~:-21 I I I I i , , , , i i , , , , , , , , , , , i i i i , , , , i , , i i i , i , i , , , , , , , , i , ~ , , , i i i i i , * , , , , , , * , i i i i i i ~ , E - REC E Alaska Oil & Gas Cofis. O0t?llT~issiort Anchora..o;e £0~0109~0~ ]did 'poso[3 St J.O~UOAO,,l.d -!%~o%ne uodo sou!i 20%aoA!p uo SOA[~A OlgnVBOAH .0l~9 ---~ . I I, MO±N~3Bd BVg~NN~ c~ ISd O00Z ,,OZ M3SIB 9N199I 3N1-1~'94 · ~q£ON V3BV lid 3AB3§3B I I I ,, 331 ,, 3HV 3A 9~/A -Tg~IB ('9IV±30 3A'gVA '9'gVB 3BOB 993~ NOIHSnO ~ SNHfl£ °06 99V 'BdO 'OAH ,,01 33S) 3l~08 993~ 'BdO 'OAH ,,01 9IZVWMHOS '.ON I ~3±SAS VYlSV--IV 0 Okl'V' W31U3AI O 330H RNNUI..RR .PRE'V~NTOR P !gE RAILS BLIND RRI"IS DRILL[NS SPOOL PI'gE RRM$ 13-5/8" BOP S'TACK DLA(~4 Accumulator Capacity Test 1. C~ck and fill ac~lator reservofr to level ~th ~lic ~d. ~. ~s~e ~m ac~a~or p~s~e is 5000 psi ~h 1500 psi ~t~ of t~ re.la, or. 3. Obse~e t~, =~n close all ~=s s~t~ly ~ r~ord t~ t~ ~ pressure r~~g after all ~s a~ closed wi~ ~rg~ ~ o~. is 45 sec~ clos~g ~ ~ 1200 psi press~. 1. Fill BOP stack and manifold with a non-freezing liquid. , 2. Check that all hold down screws are fully retracted. Mark running joint with predetermined plug seating depth. Run test plug on drill pipe and seat in wellhead. Run in lock down screws. 3. Close amm~ar preventer and upstream valves.' 4. Ptmctionally test chokes. · 5. -In each o£ the following tests, first hold a 250 psi low pressure test for a ~ o£ 3 mimmes, then test at the high pressure. 6. [ncrease pressure to $000 psi and hold for a mimimum of 3 minutes. Bleed pressure to zero. ?. Open armmlar preventer and close top set o£ pipe rams. Increase pressure to 5000 psi and hold £or at least $ minutes. Bleed pressure to zero. 8. Close valves directly upstream of chokes and open chokes.. Increase pressure to 5000 psi and hold for at least $ minutes. Bleed pressure to zero. 9. Open top set of pipe rams then close bottom set pipe rams. Increase pressure to 5000 psi below the bottom set of pipe rams ar~ hole[ for at least 3 min- utes. 10. Test resmining untested manifold valves (if any) with 5000 psi upstream of valve armi zero pressure do~stream. 11. Bleed pressure ~o zero. Open bottom set of pipe Tams. 12. ~ack off running joint and pull out of hole. Close blinct rams anc[ test to 5000 psi £or at least minutes. 15. Bleed pressure off all equipment. Open blind rams. Make sure manifold and lines are full freezing liquid and all valves are set in drilling position. 14. Test standpipe valves to 5000 psi. 15. Test Kelly cocks and inside BOP to 5000 psi wir. h Koomey pump. 16. Check operation oE Degasser. 17. Record test information on blowout preventer test £orm. Sign and send to Drilling Supervisor. 18. Perform complete BOP£ test once a week and func- tionally operate BOPE daily. Revised 2/21/84 o31 ~.qOo o t~ ~$ o o ~ ~o o~ 4o ~ ~,o PRUDHOE BAY 13 ! _ = DRILL SITE L-2 PLANT NORTH Grid North ia 13°North D.S. No. II Cond. ASP ZONE 4 3 Y=5963094.70 X= 69E 870.8Z 7 Y= 5 963 370. 88 X= 692 807. 03 17 Y= 5 963 503.78 X= 692 776. 34 21 Y= 5 965 620,.77 X= 692 '/49.45 ~.5 Y= 5 963 737. 69 X= 692722.39 29 Y= 5 963 854. 6?. X= 692 695.43 ~;~ Y=5963 971.60 X= 692 668.46 TIIN VlClNITY MAP SECTION' I8 OFFSET WLO SLO LAT= 70°18' 13.0931" 1166 !197 LDNG =148°26' 15.14i~3 ' LA '= 70 18',,5.8 46". I10 LONG= 148°26 16. 7877 LAT= 70° 18~ I~ 1~91 ~ 1082 1609 LONG= 148°~6~1Z 5902 LAT= 70°18~,18.~962~ !058 17~6 LONG = 148°2618.~66 LAT= 70°18~ 19,45E7" 1034 1843 LONG = 148 26 19 6866 LAT= 70°18~21.7611" 986 2079 LONG = 148°~6'19.802~' NOTES !. COORDIN.I~TES ARE "FLUOR" ASP ZONE PER F.R. J~ELL DWNG DRILL SITE L- 9 -£1- 85 L~END WLO- WES~ L/NE OFFSET SLO.-SDU'D.f LINE OFFSET .... TH/$ CERTIFICATE OF SURVEYOR LICENSED TO P~I~ LAND SU~EYI~ IN THE ALASKA AND T~T THIS PLAT ~EPEESE~T~ ~ ~TION SURVEY MADE BY ME OR UNDEE MY DIRECT ~E~ISlON, ~ ,~ ?-~ ',~ ~'~ ~D ALL DIMENSIONS ~D OTHER DETAILS ~E l~Jaska Off & Gas Cons. Co~ D~¢[ SUEV[YOR ARCONo, I ARCO Alaska, Inc. AS- BUILT DRILL SITE L- ~ CONDUCTORS LOCATED IN PROTRACTED SECTION 18~TIIN, RISE U.M. -. l~SS~. PREPARED BY LOUNSBURY & ASSOCIATES, INC. 72~ W6th AVF-, ANCHORAGE,ALASKA DATE: 10/29/85 SCALE: !"=~3' ,., CHKD. BY= G E L FL 13. BI< .:. LHD..85- I01 IIO'9 [8/~I/~0 :~a~ : s~l:t~malt I~uoI3IPPV .. ............................................. sQuma~:tinb~:t I~UOIQTppv SZH ................................. aIq~qoad s~g ~o ~uas~ad oq~ sI '93 .................. 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'p~p-~Iou aeld ~zoqlloa sT pue poaeTnop oq oa Iloa si '9 .... Iood sIqa uT alqelIeAe o~eoxoe paaeaIpopun auoioI~ns si '"iii' i ..... auTI ~l~adoad moa; oouelsTp aodoad p~3eooI ilOm si ..................... Iood PouT;ap e uT p~3eooI oq o2 iiom si ......................................... poqo~33~ aaj 3Ttuaod oq3 sI 'I SMMVNM}t ON S~IX KuedmoD (9Z nzq~, (IZ naqa [I) (8¸ .__.~-~ / -// "-~k~ ao~ (z) ~a (t) M&V~ HAOMJJV NH&I S~IIqMMJ %]~a~ MMN M0t &SI% MD~HD Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically organize this category of information. ~ 'iH "iH ~ o trll OOOOOOOO0 ~ t~ :i~ ~ 0 i'm oooo~oooo ~ ' .,,, ~ 0 I H O0oOOOOOo IH ~ · . ,... 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